bluuebunny/crossref_metadata_2025_split huggingface dataset:
Full-Scale Reuse Treatment of Wastewater Produced by Oxidation-Absorption Technology of Tail Gas from Natural Gas Purification Plant
Authors: Tang Quanwu , Li Jing , Lin Dong , Chen Tianxin , Wang Yue , Zhao Liang , Jiang Guobin 
Published: October 2023

Abstract

Summary
Tail gas oxidation-absorption technology which has been applied in natural gas purification plants of the southwest oil & gas field company can get super low SO2 emissions that is better than the discharge standard (GB39728-2020) in china, but it produces huge wastewater. In this paper, the oxidation-absorption technology of natural gas purification plants was described, and wastewater-producing regularity and pollution characteristics were studied in detail. A full-scale reuse treatment strategy of the produced wastewater which was based on the sequential combination of disc-tube reverse osmosis and evaporative desalination at low temperature & low-pressures was proposed, afterward water quality of the wastewater before and after the reuse treatment was investigated. In addition, produced salts were explored by Fourier transform infrared spectroscopy (FT-IR), scanning electron microscopy (SEM) and energy dispersive spectroscopy (EDS). With our proposed reuse treatment system, the chroma disappeared, and COD, BOD5, TOC, TN and SS decreased. Meanwhile, salts were produced after the evaporative desalination. They were characterized by FT-IR, SEM and EDS, and the results indicated that the salts were consisted of Na2SO4 but mixed with organic amines (i.e., amine-based SO2 absorbents). As a result, the produced water was reused by the current treatment system in a full-scale, and water quality can meet the national reuse standard (GB/T 18920-2020) in China, which is helpful for extending tail gas oxidation-absorption technology and reducing SO2 emissions in the world.
Maximizing the Value of Gas Lift for Efficient Field Development Plan Optimization Through Smart Gas Lift Optimization in a Giant Onshore Carbonate Oilfield
Authors: Su S. J. , Ismail A. M. , Al Daghar K. , El-Jundi O. , Mustapha H. 
Published: October 2023

Abstract
Conventional gas lift optimization methods in reservoir simulation prioritize naturally flowing wells over wells requiring gas lift to meet production mandates. However, maximizing the value of gas lift wells may unlock significant untapped reserves. This paper presents the application of a Smart Gas Lift Optimization (SGLO) workflow on a complex giant onshore carbonate oilfield to maximize production and recovery through an efficient gas lift optimization method.
The Smart Gas Lift Optimization consists in restructuring the well group hierarchy to define parallel structures for naturally flowing wells and gas lift wells to enable existing wells with gas lift to be produced with a higher priority, hence maximizing their production potential using gas lift optimization. Wells meeting certain conditions defined on production, gas-oil ratio, water cut, or pressure would be automatically assigned to the different entities of the gas lift group structure to maximize their production and enable the gas lift optimization mechanism to obtain the most optimal gas lift rate under the constraints specified.
The workflow was applied on a giant onshore carbonate oilfield with a complex structure and a very high well count through an automated tool that was developed for setting up the full SGLO workflow by automatically parsing reservoir simulation model input files and define the required group structure, along with all necessary settings for gas lift optimization and SGLO. Results between the non SGLO case and the SGLO case were compared to assess the difference in production between these two scenarios. The SGLO case provided a substantial boost to the total oil production compared to the non SGLO case and the duration of the production plateau target was extended further. The gas lift optimization allocation is effectively allocating gas lift even if the production plateau is already reached and proposing a gas lift rate allocation that maintains the existing gas lift wells alive and improves the total reservoir recovery while reducing by-passed oil in place. The allocation prioritized to gas lift wells significantly increases the value of the existing gas lift wells that are pushed to their largest potential, reducing requirements for infill drilling.
Although the Smart Gas Lift Optimization uses all the principles of regular gas lift optimization combined to an additional logic that triggers the gas lift wells to produce with an optimum gas lift rate based on an economic gradient defined. The tool was fully automated to apply the SGLO workflow in a matter of minutes even for a highly complex reservoir model.
Water Shutoff and Conformance Improvement for Lamadian Oilfield in Daqing Using a Novel Polymer System: Experimental Study, Simulation, and Pilot Tests
Authors: Lu Meng , Singh Harpreet , Li Jianshen , Huang Qiushi , Ma Chi , Shan Gaojun , Du Qinglong , Cai Meng , Wang Haitao , Liu Xiangbin , Qiao Yan , Chen Huan , Chen Zhao , Nie Cong 
Published: October 2023

Abstract
Primary recovery and extensive waterflooding lead to preferential pathway for the water between injectors and producers, resulting in low sweep efficiency and lower oil recovery. The Lamadian Oilfield in Daqing has been waterflooded for 50 years, where various methods have been tried to reduce the high water-cut. This paper presents a novel water conformance control system that has been successfully applied to reduce water-cut and increase the oil production from Lamadian Oilfield.
The polymer system containing swelling particles and delayed polymer gelling agents to form plugs and block high permeability channels was tested in the laboratory through sandpack and coreflood experiments at reservoir temperature using injection brine from the Lamadian Oilfield. With injection concentration of polymer ranging between 1200-4500 ppm and crosslinker between 1200-1600 ppm, the experimental tests showed formation of strong plugs in-situ with delayed time of 4-18 days. This system also had low polymer/crosslinker's retention.
The lab-measured parameters for rock-fluid interaction were used as input in a history-matched numerical reservoir simulator. Several scenarios with different injection schemes were simulated to investigate the volume of plugs formed, maximum distance travelled by the gelling agents from the injectors before forming plug, and their impact on the surrounding production wells. Simulation results showed that the formation of the plug was the most robust at the front of the crosslinker-polymer system, and the region between the injectors and the front showed formation of secondary plugs by the particles. An optimal scenario was selected for pilot tests.
Field tests for 2 well groups with a total of 16 wells started in December 2021 that were successfully completed by April 2022. Field test results show the targeted high-perm channels were blocked, resulting in a significant increase in oil production (up to 15%) in the majority (71%) of the surrounding producers and a drop in water-cut (1-3%). The oil production rates of the surrounding producers maintained a stable increasing trend, indicating the long-lasting effect of the plugs on the displacement of the remaining oil.
This work presents a novel polymer conformance control system with low injection viscosity, long and tunable gelation time, good plugging strength, and long-term stability under reservoir conditions to effectively shutoff high permeability channels/zones for robust in-depth conformance control.
A Dual Petroleum System in the Eastern Onshore Abu Dhabi
Authors: Zushi Takahiro , Tokuoka Shin , Shimomura Takahiro , Yamanaka Motoyoshi , Franco Bernardo J. , Al Shamsi Jawaher 
Published: October 2023

Abstract
This study focuses on new exploration opportunities in the northeastern onshore area of the Emirate of Abu Dhabi where few commercial hydrocarbon discoveries are reported until recently.
An exploration well newly drilled within the studied area has confirmed a total of five formations with oil and gas accumulations. A comprehensive geochemical analysis was conducted to identify potential source rocks and to correlate hydrocarbon with source rock. Furthermore, the effective kitchen and hydrocarbon migration/charging process were investigated by a simple 1D basin modeling approach. The key findings are:Rock-Eval pyrolysis suggests that at least three potential source rock formations are present in the (Cretaceous) Aptian, Cenomanian and Campanian. Any source rocks in and below the Jurassic are not fully understood in the studied area.Biomarker fingerprints indicate a possibility that oil in the Upper Cretaceous reservoirs and oil in the Lower Cretaceous reservoirs have been delivered from a different source rock and migration process.Oil in the Upper Cretaceous tends to exhibit a lower API gravity with no or trace associated H2S, suggesting an earlier-generated oil.Oil in Lower Cretaceous has a light to very light API gravity with minor to fair H2S content. This implies a mixed sourcing from a matured / gas source rock and post matured deep kitchen.
The findings tell that two independent petroleum systems are simultaneously effective in the area. An Upper and Mid System is shallower, providing an early oil matured system that creates mostly oil accumulations in Upper Cretaceous. The system is situated in a foreland basin associated with obduction tectonism in the Late Cretaceous to Tertiary. The older system is a deeper late/gas matured system that creates both oil and gas accumulations in the Lower Cretaceous. The system is associated with the thermal subsidence of a thick passive margin basin which ranges from the Permian to Middle Cretaceous.
The multiple petroleum systems in the eastern onshore Abu Dhabi region have been implied by a lot of evidence but have been less explicitly discussed. This study organizes the outline of these systems and delineates the potentialities for exploration and appraisal for the study area.
Comparison of an All-Electric Intelligent Completion System Versus an Electro-Hydraulic System, Under Similar Conditions to Determine the Best Well Completion Technology for an Intelligent Mature Injection Field
Authors: Sánchez W. , Ahmedt D. , Camargo D. , Guarin L. , Solorzano P. , Polania M. P. , Molina N. , Garcia M. , Rojas C. , Jimenez A. , Castro C. , Meneses G. , Clavijo O. , Leal J. , Herrera L. 
Published: October 2023

Abstract
This paper will present a performance comparison of two intelligent completion technologies installed in six existing water injection wells. The first technology is an intelligent completion system with electric valves and the second is a hydraulic valve system with an electro-hydraulic control system. For comparison, a total of six wells were installed, three with all-electric and three with electro-hydraulic, in existing wells with similar reservoir and injection conditions. Both systems included permanent fiber optics to calculate the injected flow in each zone in real-time. The main objective of the technology test was to define the best technology to develop an intelligent mature onshore field.
A total of six wells were selected: four in the Chichimene field and two in the Castilla field, both located in the Llanos Heavy Oil Basin in Colombia. In the first field, two wells used electrical technology and two wells used electro-hydraulic technology (one of the wells was installed inside 5-½" liner). In the other field, one electric and one electro-hydraulic well were installed. This distribution was made with the purpose of obtaining performance data for each technology in each field.
The six wells were successfully installed in a period of six months without cost and time deviations or HSE incidents. In general, the electrical system was more flexible during calibrations and installation, requiring less preparation and installation time. On the other hand, the electro-hydraulic system was adequate for wells with small diameters (5-½"), since electrical technology has not been developed for this diameter. When precision of choke position and fast speed of actuation was required, the electric valve offered the best performance.
The document will include details about technology selection, planning and installation process and the performance analysis obtained from each option during detailed planning, workshop and well-site preparation, downhole and surface equipment installation, and fiber optics calibration before injection start-up. The benefits and restrictions of each of the technologies will also be shown.
State-Of-The-Art Technologies and Engineering Approach to Production Logging of Penta Lateral Electrical Submersible Pump Driven Offshore Wells
Authors: Abdulghani A. J. , Muailu H. A. , Shurafa M. N. 
Published: October 2023

Abstract
As the number of multi-lateral complex wells and advanced completions deployment rises, the demand for advanced and reliable Coiled Tubing (CT) intervention and logging solutions is also increasing. Well complexity is associated with the number of laterals, extended-reach open-hole, complex well trajectories, and the use of advanced completions such as Electrical Submersible Pumps (ESP), Inflow Control Valves (ICV), Inflow Control Devices (ICD), and other completion accessories. This paper provides a comprehensive engineering approach for logging multi-lateral wells with slim ESP completions.
Technologies play a major role in enabling CT logging in complex wells. The state-of-the-art electrical CT multi-lateral re-entry tool is a key enabler to locate and access the laterals, and specialized logs are utilized to verify the location of the intended laterals. Another enabler in multi-lateral logging is the retractable logging tool, which provides flexibility to navigate across the open-hole junctions and windows, minimizing the risk of damaging the logging tools. The level of complexity increases when these multi-lateral wells are completed with ESP, especially in an offshore environment. Special tools must be used to pass through the ESP slim completion, and the CT Bottom Hole Assembly (BHA) must be compact to comply with the offshore environment space limitation.
The engineering approach, through proper per-job simulation and risk assessment evaluation, besides selecting the right BHA tools, was an essential factor in completing complex logging operations safely and successfully. Moreover, a decision-making tree with live engineering support to guide the operational team to the right action played a role in a successful operation. Additionally, the synergy between engineering and operation is another aspect of success, to make timely decisions during the operation.
The presented state-of-the-art technologies and engineering approaches were proven effective in logging multi-lateral slim ESP completions successfully verified on a Penta lateral ESP-driven well.
Investigating Relationship Between Capillary Pressure, Phase Saturation, and Interfacial Area in a Three-Phase Flow Water-Wet System
Authors: Aljaberi Faisal , Alhosani Abdullah , Belhaj Hadi , Blunt Martin J. 
Published: October 2023

Abstract
Immiscible fluid displacement in porous media is encountered in many applications, including waterflooding in oil reservoirs, carbon capture and storage, groundwater remediation, and underground hydrogen storage. Displacement is controlled by capillary forces which is typically assumed to be a function of saturation (S), although the relationship is known to be hysteretic, in that the capillary pressure (Pc) is different for displacement where the saturation is increasing or decreasing for the same rock sample. A thermodynamically based theory predicts capillary pressure is a function of both saturation and specific fluid-fluid interfacial area (a). Recent advances in X-ray micro-computed tomography (micro-CT) allow for the saturation, capillary pressure, and the fluid-fluid interfacial area to be measured directly in situ on three-dimensional images of the rock sample and fluids. In this study, we investigated the relationship Pc-S-a in a steady-state experiment conducted on a water-wet Bentheimer sandstone. In our three-phase system water was the most wetting phase, oil was intermediate wet, and gas was the non-wetting phase. We examine the effect of introducing the gas to the water-oil fluid pair and the theory for water-oil and oil-gas fluid pairs. The main findings were as follows. (1) Introducing gas will push the oil to intermediate-sized pores while the oil also forms spreading layers, which results in no oil trapping; hence Pc-S hysteresis is not observed for the water-oil fluid pair compared to two-phase flow. Trapping has a significant effect on hysteresis. (2) The Pc-S-a relationship eliminated hysteresis and produced a unique three-dimensional surface, for both fluid pairs for steady-state conditions.
Quantitative Stratigraphy of the Early Jurassic Middle Marrat Formation in Kuwait: A Revival of the Epeiric Island Model
Authors: Poppelreiter Michael C. , Claps Michele , Rankey Eugene 
Published: October 2023

Abstract
Kuwait has some hydrocarbon producing intervals in dolomite and limestone reservoirs. Several of these formations were deposited in a dolomitized carbonate ramp environment. The Jurassic Middle Marrat Formation in Kuwait is one example of many found in the Middle East. A sweetspot study was initiated by KOC to increase gas production. Sweet spots are dolomite beds and lime-grainstone in places. Dolomite mineralisation in this formation is only present within bioturbated and microbial beds deposited that occur in backshoal and shelf depositional sub-environments and form stratigraphically in short transgressive pulses during overall regression. The 3D geometry of these dolomite layers is poorly understood, as individual beds are well below the resolution of the seismic data and commonly less than 1-2 m thick and thus at the limit of standard openhole logs. A world-class digital core data set provided a means to delineate dolomite bodies as part of an exercise to map out environments of deposition (EoD) for the first time within a high-resolution sequence stratigraphic framework. Results reveal that the geometry of EoD's, as well as the dolomite layers mimic the shape of subtle structural highs and lows of the basement. These patterns of deposition and early diagenesis are interpreted to reflect ‘epeiric islands’. The architecture may be a common type of reservoir architecture in epeiric sequences in the Middle East. Structurally constrained EoD mapping is suggested to be an effective way of predicting the geometry of these potential reservoir layers.
Combining DAS and DTS Measurements for Oil-Water Two-Phase Flow Profiling in Sucker Rod Pump Wells
Authors: Song Jiayi , Sui Weibo , He Jinbao , Li Junwei , Yang Yanming , Guo Huan , Wen Changyun 
Published: October 2023

Abstract
Distributed temperature and acoustic sensing techniques (DTS and DAS) have been widely used in oil and gas wells of higher rates for flow profiling. However, current interpretation models usually cannot be directly applied to sucker rod pump (SRP) wells. Due to the existence of the sucker rod, the contact mode between the optical fiber and wellbore fluids is different from the pumpless wells. Furthermore, high water cut and pump noises also greatly increase the difficulty of DAS data analysis. This paper presented an improved theoretical model and interpretation method for oil-water two-phase profiling in SRP wells and a field case was used for illustration.
The DTS data analysis was mainly based on a well-established numerical wellbore-reservoir coupled flow/thermal model that considers transient temperature behavior during production tests. Considering the different contact modes between optical fiber and wellbore fluids in SRP wells, a segmented function was adopted to describe the variation of heat transfer flux in different well sections. The DAS data were prefiltered to eliminate the pump noises based on the on-site test results. The possibility of determining the volume proportions of the oil and water phase in the mixed fluid through the utilization of the f-k plot was explored. The strength and energy of DAS data were used for preliminary flow profiling. The DAS flow profiles were used as the initial guess and the final interpretation results were inversed by combining DTS and DAS data. Levenberg-Marquardt algorithm was applied for the inverse procedure.
Compared with pumpless wells, the wellbore temperature in the upper section of SRP wells was closer to the formation temperature, which was successfully characterized by this improved thermal model. The water-cut variation has a limited impact on temperature and it might be further obscured by the oscillation of temperature data to some extent. The flow profile calculated from DAS data served as the initial guesses in the DTS inverse modeling part, which greatly reduced the uncertainty of DTS data analysis and computation cost. The presented model and interpretation method have been applied to an SRP well in Liaohe oil field, China. The interpreted flow profiling by combining DTS and DAS data showed consistent results with that measured by production logging tools. Furthermore, the major oil-production zones were identified, and they are interestingly not the major liquid-production zones.
An improved model and interpretation method to interpret the oil and water allocation in SRP wells was presented. The combining DAS and DTS measurements resulted in more accurate interpretation of oil and water allocation than using the DAS alone. In addition, this method may provide guidance for water plugging treatment in commingled wells.