bluuebunny/crossref_metadata_2025_split huggingface dataset:
Interpreting Downhole Esp Data for Predicting Production Performance by Use of Inversion-Based Methods in South Europe Field
Authors: Pignotti Eleonora , Spagnolo Salvatore , Pilone Salvatore , Baldassarri Gianni , Cappuccio Pasquale , Valente Alberto , Greco Pasquale , Gonzalez Zamora Mariangela 
Published: February 2022

Abstract
The objective of this paper is to demonstrate how a physics-based data driven model and inversion procedures can transform traditional ESP well monitoring into an indispensable tool for predicting multiphase flow rates in ESP production wells. Model and prediction techniques are evaluated by comparison with real field data, measured both live and retroactively from different ESP producing wells located in the South Europe producing field.
Operational data commonly gathered by ESP gauge, such as Pressures data, Motor Current and Operative Frequency can be used to predict flow through ESP components, without need for rental of expensive Well Testing equipment. The exploitation of a similar advantage is made possible by the application of artificial intelligence algorithm joined with physics based modelling, taking in as input ESP dynamic data and giving as output a simulation–with acceptable accuracy- of the continuous downhole flow and reservoir properties, allowing the oil operator to obtain key information to optimize well production based on the calculation of ESP operational point.
Such cost-effective metering technology is already suitable for online real-time systems implementation and has already been put in place in South Europe field, where it gives reliable results that will yield ongoing ESP run life improvement through its constant application. The improvement of several ESP KPIs, such as MTBF and MTTF, is strictly related to a more accurate follow up of the ESP operative point, hence of the ESP production. Higher ESP MTBF/MTTF might lead to a reduction of the number of necessary ESP replacement workover for year, thus causing the enhancement of hydrocarbon recovery and a reduction of the differed production.In addition to all of this, the possibility of virtual metering well production performance by means of a virtual model might provide a sensible reduction of the number of replacement systems provided from Service Companies, hence the overall optimization of production operation costs.
The increasing need for operational efficiency, cost reduction and improved equipment means that service life has driven the recent technological developments related to electrical submersible pump (ESP) well operation management. This paper well described the application and the benefits of such technology to be used as reference successful case by other key players in the O&G market.
Rigless Electrical Submersible Pump Deployment Power Cable Qualification Testing in High Flow Rate Oil Wells
Authors: Xiso Jinjiang , Ejim Chidirim , Banjar Hattan , Munif Eiman , Tulbah Faris , Sarian Serko 
Published: February 2022

Abstract

Objective / Scope
Conventional Electric Submersible Pumps (ESPs) are deployed using production tubing, service rigs and well killing services. In recent years load bearing Power Cable deployed ESP systems have been developed, eliminating the service rig and reducing ESP changeover time by more than 80%. More recently developed live well Cable Deployed ESP systems further eliminate the need for well killing services, and potential reservoir damage. The downside in both cases is for the power cable to remain inside the tubing and withstand long term production fluids.
A fit for purpose load bearing Power cable has been designed and qualified for reliable long term ESP operation in live sour oil wells.
This paper covers the abrasion testing and inspection results of the cable armor being exposed to long term high-rate and high-solid content production fluids.

Methods, Procedures Process
A prior finite element modeling (FEA) helped fine tuning the abrasion testing and inspection plans.
A section of cable prototype was enclosed inside a 20 ft long field production tubing and inserted into a 6000 barrels per day capacity flow-loop made of a fluid mixing tank, Triplex mud pumps and a 2″ flow choke and piping system. Two-phase accelerated testing was implemented using 130 bbls salt water @ 45,000 Mg/L NACL
In Phase 1, 4.3% by weight Limestone particles were added and pumped at 5,000 bbls/day
In Phase 2, solids content was increased to 6.5% by adding 1 metric ton (MT) Sandstone and 0.3 MT Limestone.

Results, Observations, Conclusions
Phase 1 and Phase 2 were 7 days each using 75% duty cycle pumping. Post-testing, the cable sample showed no visual deterioration. It was then sent to a specialized lab in the UK for microscopic inspection and yearly abrasion rates computation.
In Conclusion it was demonstrated that the cable design and selected armor alloys were adequate for the three re-deployment operational requirement (equivalent to 10 year continued operation in the well)

Novel/Additive Information
The Novel FEA analysis and accelerated solids abrasion testing process allowed for accurate real-well simulation and significant early de-risking of the project.
Review of Non-Metallic Pipelines in Oil & Gas Applications - Challenges & Way Forward
Authors: Bukhari Amer. O. , Bashar Mohammad , Aladawy Ahmed. S. , Goh Serena. L. M. , Sarmah Pranjal 
Published: February 2022

Abstract
Nonmetallic pipelines are gaining popularity across the Oil and Gas value chain from upstream to downstream applications. Among the top benefits are mitigation of corrosion hazards, lowering the total cost of ownership, and reducing carbon footprint. While nonmetallic pipes are increasingly deployed onshore and offshore, a focus on downhole tubular development and qualification is essential as these are lacking in literature. In this paper, the authors attempt to provide an overview of the technology status quo as well as highlighting implementation challenges on downhole applications and proposed a way forward to tackle such challenges.
A detailed literature review on current technological advancements and market trends of non-metallic pipes is carried out with a particular focus on downhole R&D potentials and application progression towards more severe well conditions, while meeting the future Oil and Gas demands. A comparison of current market offerings of non-metallic pipes for onshore, offshore, and downhole applications is conducted, based on their design construction, material compositions, pipe dimensions, and operating envelope. In light of such comparison, there is a market gap of the intended target specs for downhole applications. Pipe design, material selection, and product qualification are also described in the process to highlight the effort needed for industrial standards to qualify the downhole tubulars. Manufacturing of pipe and connectors are briefly discussed as part of the challenges.
A gap analysis is also conducted to address the downhole system and infrastructure challenges related to utilization of non-metallic components in drilling, completion, logging, intervention, and production conditions, as the existing qualification standards are not capable of adequately addressing the various possibility and combination of non-metallic pipe configurations and their components for the intended service conditions. This study identified the areas where R&D work is required for non-metallic pipes to be designed, tested, and qualified for application in demanding and aggressive well conditions (e.g., high temperature and pressure) in order to replace steel tubulars for improved properties.
Favorable Target Optimization for CO2 Flooding in Deep Block Sandstone Reservoir with Bottom Water: A Case Study of Northwest Oilfield M Reservoir
Authors: Xu Ting , Liao Haiying , He Yingfu , Nie Jun , Cui Maolei , Guo Yabing 
Published: February 2022

Abstract
Northwest oilfield M reservoir is deep block sandstone reservoir with strong aquifer, having thin layer, large water-oil volume ratio, high temperature and salinity, strong heterogeneity, being developed more than 20 years by depletion method, influenced by bottom water, reservoir comes into high water cut period, recovery degree is only 26%, requiring for further enhanced oil recovery technology. CO2 is easily miscible with oil, but whether CO2 is applicable for the reservoir with strong aquifer or not is still unclear. No foundation can be referred to in area optimization for CO2 flooding. It is necessary to conduct research on influencing factors of CO2 flooding in the sandstone reservoir with aquifer and set up the favorable target optimization technology.
Reservoir engineering method was applied to study M reservoir production pattern. Based on G&G, the geological-dynamic response law was established and productivity influencing factors were studied. Considering flowing differences between block reservoir and layered reservoir, the flowing field is affected by vertical sweep of bottom water, internal small faults have sealing effect on plane sweep, development unit division method was formed on the basis of vertical hydrodynamic characteristics. According to CO2 occurrence state and dynamic distribution in oil layer and strong aquifer, three types of favorable target have been classified, favorable target optimization technology is established for CO2 flooding in deep block sandstone reservoir with strong aquifer.
Research results show that the south and middle block are structurally high, edge water intrusion is weak, main layer is relatively thick and interlayer is developed, I and II type well are the main production well. While the north block is structurally low, reservoir quality is poorer, II and III type wells amount a lot. CO2 density is higher than the oil, in the interlayer undeveloped block, CO2 migrates vertically to the oil-water interface, then spreads laterally forced by bottom water, resulting in an increase in the oil-water interface tension and a decrease in the diffusion rate to the water. The more developed the interlayer is, the larger the sweep volume of CO2 is. In high structural position, fault sealing, interlayer developed and thick layer, the enrichment degree of remaining oil is still high, important to ensure CO2 lateral sweep. As results, favorable target for CO2 flooding is classified into I, II and III type.
CO2 flooding pilot test was carried out in type I favorable target. Till now, 18,000 tons of CO2 had been injected, oil exchange ratio in 1st year was 0.13. Research results lay the foundation for the efficient utilization of the remaining oil, so as to explore an effective development method for deep, ultra-deep sandstone reservoir to greatly enhanced oil recovery.
Advanced Multi-Physics Sensor Utilizing Molecular Fingerprinting for Production Logging Tool
Authors: Maity Sandip , Abrar Manzar Muhammad , Al-Shabibi Hussain , Jindan Jana , Larbi Zeghlache Mohamed 
Published: February 2022

Abstract
Knowledge of fluid density along with phase measurement are extremely important for reducing the variance in estimating the flow profile from the production logging tool (PLT). When both oil and water are produced simultaneously, induced reflectance measurement derived from the optical refractive index is not effective. This is mainly due to phase persistence behaviour of the optical sensor caused by the coating of the previous phases. The most effective way to characterize such flow is to measure the fluid's fluorescence along with refractive index and density. In this paper, a novel solution is presented using a piezo helm resonator sensor with simultaneous and congruent measurements of fluid mass density, viscosity and sound speed.
Pore Geometry Effect on Si, Trapping and Sor in Tight Carbonate Reservoirs
Authors: Kayali Anas , Koronfol Safouh , Gnozalez David 
Published: February 2022

Abstract
Spontaneous imbibition is one of the key production mechanisms in fractured oil reservoirs. It is also an important process in tight gas formations, which has significant effects on the gas production after hydraulic fracturing. The objective of this research is to investigate the effects of pore throat sizes and connectivity on spontaneous imbibition behavior in tight carbonate rocks. Many plug samples were selected from various wells in the Middle East. The samples were characterized using X-ray CT imaging, thin-section photomicrographs, Helium porosity and gas permeability. High pressure Mercury injection experiments (MICP) were performed in the primary drainage mode to obtain the pore throat size distributions, followed by Mercury withdrawal tests to investigate the spontaneous imbibition curve and fluid trapping. The degree of pore connectivity was studied in the samples from thin-section photomicrographs and from primary drainage capillary pressure curves and were found in good relationship with the Mercury withdrawal behavior and residual fluid saturations. Higher permeability samples were characterized by lower entry pressures that showed higher tendency towards lower fluid (Mercury) trapping.
These results show important link between the rock nature and spontaneous imbibition and fluid trapping that can be deduced from Mercury withdraw testing. Accurate prediction of spontaneous imbibition is crucial in many hydrocarbon reservoirs and such analyses help understand production mechanisms in different carbonate rock types.
Study and Implement of the Large Amount Data Divided Time Transmission System Utilizing Microchip-Storage-Ball Release While Drilling
Authors: Li Sanguo , Gao Ruixiang , Li Jibo , Zhu Zuyang , Wang Zhifa , Gramajo Silva Eduardo Davio 
Published: February 2022

Abstract
The more downhole information measured by LWD tools, the more measurement data they produces. The conventional LWD tools can hardly transfer all the large amount of data of LWD tools to the surface, which greatly limits its advantages in while-drilling production. If retrieved after drilling, certain LWD tools would lose their advantages entirely in while-drilling production. This paper proposes a novel method that employs the basic concept of a "flash drive" downloading and exchanging data among computers. A system is developed to achieve data transmission in a time-division manner using releasable microchip storage. The system includes a plurality of microchip storages, a plurality of sealed chambers each for containing a microchip storage, a release power device, and a circuit. The release signal is sent by time setting or pressure signal triggering. In drilling, the data measured by the LWD tools can be downloaded into the microchip storage. A release signal could be sent on time, or the release signal can be triggered and sent by the pump pressure pulse, when the LWD data is needed. Upon receiving the release signal, the circuit sends a release command to control the power device to release the microchip storage from the drill collar into the drilling fluid in the annular. The microchip storage can be carried to the surface by drilling fluid and can be recovered. The data in the microchip storage can then be retrieved. In this system, there are four contacts on the microchip storage to connect with the circuit, through which power supply and data connection are established. The data access to the LWD data complies with the RS485 data protocol. The system adopts a push technology. The data capacity of single microchip storage is 1 Mbit, and the size of which is 12mm (D)×12.5mm (H). One drill collar system can carry up to 24 microchip storages. Thus it makes a single collar system have a large data storage capacity. It can improve the efficiency of data transmission.
Newly Designed High Expansion Through-Tubing Bridge Plug Service to Reduce Operational Costs and Increase Reliability
Authors: Eyuboglu Sami , Heaney Frank , Chamarthy Pramod , Powell Bryan , Gullett Chris 
Published: February 2022

Abstract
Through-tubing bridge plug (TTBP) service is a common e-line well intervention service for isolating lower non-productive zones for improved production or plug and abandonment. Traditionally, this service was only run on e-line, as it requires a unique electro-mechanical extended stroke setting tool, to set these types of barriers. This paper discusses the challenges of developing a new design of the TTBP, deployed on Digital Slickline (DSL) to help optimize service costs.
System-level analysis was adopted to analyze the current e-line TTBP service and identify challenges to DSL deployment. In general, these plugs have extremely high-expansion ratios (2x to 4x) compared to other wireline set barriers as they have to pass through tight downhole restrictions in the completion before passing into the casing. As a result, these plugs have an exceptionally long setting stroke, requiring a specific setting tool with high power demands. The high expansion ratio of the TTBP limits pressure rating and this type of barrier demands a cement cap on the plug to complete the intervention. DSL cannot send power from the surface; therefore, it has electrical power budget limitations. The right balance needs to be found between the stroke length and the available power to achieve a successful plug.
The elastomer stack and the backup petal assembly were significantly redesigned to achieve an acceptable expansion ratio while minimizing stroke length. This feature allowed for the development of a battery-powered setting tool with a shorter stroke length. Running the service on DSL lets the operator confirm depth correlation before setting the plug and real-time feedback from downhole sensors to ensure an in-situ quality plug set. Moreover, digital slickline provides accurate bottom-hole temperature, which is critical in achieving a suitable cement plug. The paper will present results from field trials showing the cost savings of running these plugs on DSL compared to e-line.
Analytical and Experimental Study of Oil/water Emulsion in Multi Stage Electric Submersible Pump
Authors: Ridlah Muhammad Rasyid , Zhu Haiwen , Zhang Hong-Quan 
Published: February 2022

Abstract
The non-Newtonian behavior of oil/water emulsion in the ESP stage is still not well understood. The industry relies on existing empirical correlations, which only valid for production pipelines without considering the effect of shear force acting on the system. This paper will present the analytical modeling of emulsion rheology in the ESP stage and its effect on ESP boosting pressure. An extensive experimental data set validates the analytical model accuracy.
The Brinkman empirical correlation is the baseline of the analytical model development. Emulsion rheology in the ESP stage depends on many factors. Dimensionless analysis by the Buckingham-Phi theorem indicates that at least three parameters play an essential role in the emulsion rheology at the pump stage. Those parameters are concatenated and applied as the modified function of Brinkman empirical correlation. In addition, the pump boosting pressure performance observed experimentally to study the emulsion rheology effect at the ESP. More than a thousand experiment data points employed to test the proposed model, and its comparison is studied statistically.
The dimensional analysis prevails that the turbulence effect at the stage condition reflected by the Reynolds number, the droplet size effect represented by the Weber number and the Strouhal numbers relates to the shearing effect due to impeller rotation. The analytical model and experiment perform with two different oil viscosity, 45 cp and 70 cp. The results reveal that the higher oil viscosity reaches the inversion point at a lower water fraction since the turbulence decreases with higher oil viscosity. The emulsion rheology from the experiment result shows a significant increase of emulsion viscosity at water fraction close to the inversion point since the increase of hydrodynamic forces due to a higher number of water droplets. The emulsion rheology model aligns with the experiment results for the inversion point at around 35% and 32% water-fraction, respectively. The emulsion rheology model shows a good agreement with the experimental data with a 15% standard deviation of relative error. Increasing water fraction up to the inversion point deteriorates pump boosting pressure since the high friction loss occurs due to higher emulsion viscosity. Nevertheless, as the water fraction passes theinversion point, the boosting pressure starts to rebound as the water turns into the continuous phase. The formation of oil/water emulsion in the ESP is inevitable during production operation and consequently affects the pump boosting pressure. The inversion point phenomena occur at a different range of water fractions for different oil viscosity. A better understanding of emulsion rheology at the pump stage will lead to an accurate artificial lift design and eventually avoid operation failure during production well operation.
Design and Optimization of Autonomous Inflow Control Device in Water-Bearing Sour Gas Reservoirs
Authors: Zhou Chao , Zhao Xu , Chen Yashu , Wang Zhifa , Gramajo Eduardo , Rached Rached , Hu Changpeng 
Published: February 2022

Abstract
Autonomous inflow control device (AICD) completion has been applied in many conventional oil and gas reservoirs and has effectively controlled the water invasion. However, the method for designing and optimizing of AICD in sour gas reservoirs is still lacking. The objective of the proposed paper is to establish a numerical simulation and optimization method to evaluate and optimize the performance of AICD completion in water-bearing sour gas reservoirs. Firstly, a sulfur deposition saturation model is established considering non-darcy flow and stress sensitivity in sour gas reservoirs, meanwhile, time-varying skin factor is introduced to represent the influence of sulfur deposition on permeability. Secondly, a new type of AICD is designed, which has large flow channels and vortex chamber to satisfy the need of restraining water invasion and sulfur plugging in sour gas reservoirs. Finally, a reservoir-wellbore simulation method is established, which considers the sulfur deposition in the reservoir and the new AICDs in the wellbore, then the key parameters of AICD is optimized by orthogonal test and range analysis. The results of the numerical simulation show that the simulation and optimization method can effectively optimized the key parameters of AICD and the optimized AICD completion has good water invasion restriction capacity in water-bearing sour gas reservoirs. The optimized AICD completion causes little additional pressure drop compared to perforation completion in sour gas reservoirs, and the maximum additional pressure drop is less than 0.67 MPa, which means the optimized AICD completion is able to control water invasion as well as maintain normal gas production of sour gas wells. Besides, the optimized AICD completion decreases both the daily water production and the cumulative water production compared to perforation completion in sour gas reservoirs. In the last stage of the tenth year prediction period, the cumulative water production with AICD completion decreases by about 22.7% compared to that with perforation completion. In conclusion, the simulation and optimization method can be used for guiding the rational application of AICD completion in water-bearing sour gas reservoirs.
Novel Promising Metal-Organic Framework for the Decarbonization of Oil and Gas Utilities Sector
Authors: Alahmed Ammar , Younes Mourad , Jamal Aqil 
Published: February 2022

Abstract
The global demand for energy is on the rise and in order to eliminate the associated emissions, carbon capture utilization and storage is deemed as one of solutions to achieve this target.1 Furthermore, the development of renewable energy alternatives including: solar, wind, geothermal, etc., is one of the potential long-term options to eliminate additional emissions.2 Although electricity generation from renewable sources is on the rise, it is going to be a long journey for renewables to take over the traditional power generation routes.2