bluuebunny/crossref_metadata_2025_split huggingface dataset:
Re-Defining Successful Use of Multiple Stage Fracturing Technology in Tight Gas Wells
Authors: Arshad Waheed , Hassan Zuhair 
Published: March 2023

Abstract
Horizontal drilling and completion advances in tight gas and shales have allowed access to significant new resources both in existing fields and new plays. Open hole multi-stage fracturing (MSF) technologies using ball operated sleeves and openhole packers have generally been effective in delivering high productivity wells, worldwide. Successful case histories treating tight shale gas with MSF completions abound in current literature, however, it is important to note that a majority of these case histories deal with reservoirs with high pressures. Often tight gas reservoirs are initially found to be over-pressured (higher than water gradient), but as with all depletion drive systems, the reservoir pressure depletes with the removal of fluids. Pressure depletion brings along with it its own set of challenges. The wells cease to have the ability to flow naturally to surface, liquid loading, and artificial lift are issues that come to the forefront. Conventional multi-stage stimulation that was seemingly fast and efficient in high pressure environment loses its appeal in sub-hydrostatic pressure wells. The time spent between each stimulation stage to the onset of well flowback becomes long and detrimental to the recovery of the well. The fracturing fluid lost to the formation can negatively alter the relative permeability of gas in the reservoir and the longer the time spent to recover the fluids the damage tends to get irreversible. Quick and efficient clean-up of fracturing fluid is indispensable to maintain a well's productivity in tight, low pressure gas reservoirs.
A new generation of multi-stage completion systems is discussed in this paper. These multiple stage tools are operated by a single ball that opens several of the treating sleeves in one run thus allowing a large section of the reservoir to be treated simultaneously. The stimulation fluid placement is enhanced by pumping through limited entry ports of the stimulation sleeves at optimum injection rates supported by modern particulate diverting agents, and energized fluids. The operation time between the first stimulation (acid) stage hitting the formation to the well being flowed back can be cut down to a matter of few hours from an otherwise operation of a few days.
The results from this step change in completion and stimulation design have been spectacular providing several folds of productivity improvement. This application provides a fundamentally sound solution for treating low pressure, tight reservoirs.
Integrated Workflow of Acid Stimulation Evaluation and Selection for Productivity Enhancement in Carbonate Rocks
Authors: Sarsekov Arlen , Abed Abdalla , El Gohari Mohamed , Ryan Abraham , Kamaletdinov Bulat , Mahmoud Wael , Arali Vaishak , Enkababian Philippe 
Published: March 2023

Abstract
Most oil fields worldwide are stored in carbonate rocks, which vary in rock and fluid properties. Heterogeneity, thickness, and depth play vital roles in the selection of specific acid stimulation to improve the productivity and injectivity of the wells from near-wellbore damaged formation resulting from overbalance drilling. This paper describes the integrated workflow that guides petroleum engineers in the selection of optimum acid stimulation techniques and technologies for a specific field.
Specifically, this work discusses the stimulation strategies in the form of a stimulation workflow that considers various aspects to achieve the stimulation objectives. The stimulation objectives are also streamlined for the well objectives, which mainly consider the well completion approach. Considering the well completion and well objective, the stimulation strategies highlight the conveyance selections, fluid selections, and the methodologies. Guidelines are provided as examples for fluid specification. Some comparisons of the stimulation fluids are also shown to consider the advantages and disadvantages of each application. Example simulation and case studies show various applications in UAE.
Numerous new technologies and different acid types have been tested worldwide on different carbonate rocks whereas very limited information exists on a tailored acid stimulation workflow that can be fit to the needs of a specific field. The developed workflow is an integrated holistic guidance based on worldwide best practice of acid stimulation and can facilitate and guide technical expertise for production and cost optimization in different oil and gas fields. The latest stimulation technologies are highlighted for the reference on the case studies.
A Hybrid H2S Removal Solution. Using Liquid vs. Fixed Bed H2S Scavengers in Harmony
Authors: Crawshaw Michael , Brundick William , Juncker Michael , Barbuto Kristina , Jenkins Alyn , Lim Sooi Kim 
Published: March 2023

Hydrogen Sulfide (H2S) is an organic compound created naturally during the decaying process. In crude oil and natural gas H2S is generated when Sulfur is removed from petroleum products. This phenomenon occurs at various stages during exploration, production and refining. In addition to the naturally occurring H2S, sulfate reducing bacteria or SRB produce Hydrogen Sulfide (H2S) souring the reservoir production. SRB’s are living organisms that require a specific set of circumstances to grow; they need organic carbon, a sulfur source, water and the correct temperature to produce H2S.
Some facilities may not have a desulfurization plan especially when the reservoir was initially identified as a ‘sweet well’. In this case desulfurization treatment was not considered in their operations and maintenance strategies. However, over recent years the enquiries for desulfurization on brown field operations have increased indicating that ‘sweet wells’ may or have turned sour, possibly due to introduction of SRB from the surface via water injection.
Exploration of Novel Sacrificial Fluids for Asphaltene Adsorption Remediation
Authors: Mohammed Isah , AlShehri Dhafer , Mohamed Mahmoud , Mohammed Kamal Shahzad , Olalekan Saheed Alade , Abdullah Sultan , Patil Shirish 
Published: March 2023

Abstract
One of the most extensively studied flow assurance issues in the petroleum industry is the precipitation and deposition of asphaltene. This is in part because of the molecular structure's intricacy and the interconnected elements that influence and regulate its activity. The injection of inhibitors and dispersants, which affect the economics of crude oil production, is now the most successful tactic used. Anywhere throughout the crude oil supply chain, from the reservoir through the tubing and refinery systems, there is an asphaltene concern. However, the area closest to the wellbore, where the greatest pressure decrease is seen, is the most prone to asphaltene adsorption and deposition. Thus, the goal of this study is to investigate how new sacrificial fluids might be used to reduce asphaltene adsorption and deposition around the wellbore. To prevent asphaltene from interacting with the rock surface and shifting the asphaltene problem into the tubing where its impact on wettability is low, the sacrificial fluid/rock ion-specific interactions are investigated.
This is a groundbreaking attempt to relocate the asphaltene issue from the wellbore into the tubing, where it does not affect the reservoir's wettability. The performance test (adsorption inhibitive capacity), binding energy analysis, adsorption experiments (adsorption affinity, configuration, and mechanism), and fluid characterization (salinity tolerance, surface energy, interfacial tension) of the chosen novel fluids for asphaltene adsorption mitigation are presented. The investigation of ion-specific rock-fluid interactions offers great potential in the search for an effective answer to the asphaltene problem, according to the results. This is proven by the fluids’ levels of binding energy to carbonate rock samples and their capacity to prevent interactions between asphaltene molecules and the rock surface. These studies’ findings open a fresh perspective into the creation of an economical strategy to deal with asphaltene issues and their effects. This study is the first to investigate a long-term fix for wettability changes brought on by asphaltene adsorption on the mineral rock. This entails looking for a fluid that, when used as a remediation fluid in cases of asphaltene deposition, has a stronger affinity for the rock than asphaltene and has the potential to remove asphaltene. Additionally, for the first time in the state of the art of remediation fluid design, realistic environmental conditions are considered in the search for this fluid.
Selection and Optimization of Demulsifier Based on Physio-Chemical Characteristics of Emulsion
Authors: Altowilib Ali , Gajbhiye Rahul , Mahmoud Mohamed , Solling Theis 
Published: March 2023

Abstract
The presence of crude oil/water emulsions is a burden in the petroleum industry. It leads to several operational and economic issues related to crude production, transportation, and refining processes. The stability of the emulsified oil is affected by water content, presence of organic/inorganic materials, formation brine salinity, and temperature. In reservoir fluid studies, applying chemical demulsifiers on emulsion samples is common to break the emulsion and reduce the water content to an acceptable level (less than 1 wt. %) to generate representative fluid composition results. However, this process depends heavily on the crude and the water compositions and the type of demulsifier used. An incompatible choice of demulsifier could strengthen the emulsion's stability or alter the fluid composition. This introduces the need to understand specific physiochemical properties to identify the root causes of demulsifier ineffectiveness.
In this study, two demulsifiers containing different functional groups (Type 1 and Type 2) were evaluated for their emulsion breakage ability. Nine oil samples from various fields were mixed with formation water in the first round and seawater in the second. The water-oil ratio of 80:20 was achieved using a blender for 1.5 minutes at 300 RPM. Saturates, Aromatics, Resins, and Asphaltene (SARA), viscosity, density, and sulfur content were determined for all oil samples. Furthermore, chemical analysis was conducted on all water samples to determine Total Dissolved Solids (TDS). After applying both demulsifiers at the same concentration (1% of total volume), separated water volumes were measured at 5, 10, 15, and 20 minutes and used to calculate the emulsion separation index (ESI). Results of this work showed that Type 1 demulsifier performed better than Type 2 in the formation water and seawater and while using different oils due to the resistance of the non-ionic surfactant to salinity, polarity, and water hardness. This study shows a methodology for effectively determining the optimum chemical demulsifier type to break emulsions by adequately understanding the chemistry of the oil, brine, resulting emulsions, and demulsifiers used.
New Generation Downhole Sand Detection Technology Leading to Confident Reservoir Sand Management and Cost-Effective Remedial Opportunities
Authors: Kurma Ravi , Al-Fadhli Wuroud M Kh , Ayyad Hazim , Mehraj Majid , Alajmi Abdulaziz 
Published: March 2023

Abstract
It has always been a challenge to accurately detect downhole sand producing zones. Older generation acoustic based sand detecting technologies were subject to error due to background noise related to the fluid production. Due to the common false detections with the legacy measurements, remedial workover plans were compromised (Adil, 2020)
A new technology that can differentiate between sand production and background fluid related noise has been developed. This technology can quantify the sand grain count through a piezo-electric sensor.
In this paper, a unique comprehensive study was conducted across a sector of the Greater Burgan field to better understand the variables contributing to sand production through integrating the static model along with the dynamic production profile which included the new, state-of-art downhole sand detection technology.
Based on the results, a guideline was formulated to predict the future sand producing wells. This helps to proactively anticipate and therefore, better manage the sand production challenges.
This paper covers the results of nine wells logged across the same reservoir units. The main objective was to identify and quantify the sand producing intervals. The secondary objective was to determine the water producing zones. Wireline production log were combined with this new technology in all the wells to obtain the fluid production intervals along with the sand producing zones at the same conditions in the same run. Along with the spinner, water hold up probes pinpointed the water entries. The sand impact detection tool provided the fourth phase, sand, with excellent repeatability. Multiple rates were conducted in some of the wells to determine the critical drawdown pressure at which sand production occurs.
Demulsification of Heavy Crude Oil Emulsion Driven by Natural Materials
Authors: Adewunmi Ahmad A. , Kamal Muhammad Shahzad , Gbadamosi Afeez , Patil Shirish 
Published: March 2023

Abstract
This study investigated the effectiveness of fly ash (FA) and extracted silica (SC) from sand as natural demulsifiers for breaking stable crude oil emulsions and spiltting oil-water into phases. A series of stable emulsion was formulated and the oil-water ratio was 4:6. Various concentrations of either FA or SC ranging from 0.25 – 1% were added into vials containing the prepared emulsions and demulsification test was conducted inside the oven at 70 °C. Rheology and interfacial tension characterizations were used to illustrate the demulsification mechanism of FA and SC demulsifiers. According to the experimental outcomes, the demulsification from the bottle test showed that water removal increased with the increasing FA concentration. The demulsification efficiency (DE) of 0.25, 0.5, 0.75, and 1% FA was 35.33%, 81.99%, 92.67% and 93.77%, respectively; within 150 minutes of demulsification duration while all the tested SC concentrations (0.25, 0.5, 0.75 and 1%) achived 90.11%, 93.87%, 95.89%, and 95.89%, respectively; under the same demulsification period. The reference sample (blank) only achieved DE of 14.76%. Rheological characterization showed that the incorporation of either FA or SC caused the reduction of emulsion viscosity which indicated the breaking of emulsion and separation of oil and water. The results from the interfacial tension measurments revealed that FA and SC could migrate and adsorb at oil-water interface. The addition of either FA or SC in the oil-water system led to a more drastic reduction in the interfacial tension as compared to the interfacial tension of oil-water system devoided of the FA and SC. The interfacial tensions of oil/water system in the presence of 0.25% and 1% FA were 18.91 mN/m and 14.85 mN/m, respectively, and that of 0.25% and 1% SC were 16.44 mN/m and 14.80 mN/m, respectively, after 200 seconds and that of blank sample was recorded to be 18.1 mN/m in the same duration.
Hydraulic Casing Reamer Shoe Lands Casing in Problematic Wellbores
Authors: Pearson Allan , Luchak Mark , Curle Robert 
Published: March 2023

Abstract
Using a hydraulic casing reamer shoe (HSRT: Hi-Speed Reaming Tool) in place of a standard casing float shoe provides the ability to ream through formation tight spots on demand. With the casing string static or in dynamic motion (reciprocating up and down) the high RPM jetting action of the hydraulic reamer shoe removes obstacles such as swelling shales, dynamic salt formation movement, under gauged hole in medium to soft formations and micro doglegs. The tool also assists with navigating high angle entry points in horizontal / directional kick off points / multi-lateral completion entries, thus protecting any deformation of casing accessories such as centralizers and liner hangers from accidentally setting.
This is achieved by circulating through the casing via circulating head (or top drive equipped with a casing running tool) to activate the HSRT internal drive to provide additional circulation velocity with the speed created by the rotating HSRT. Turbulent flow cleans out the accumulated cuttings in the wellbore that can cause mechanical sticking and/or increased drag forces in the horizontal section if cuttings and solids are not effectively reaching the surface.
Although a wiper trip with a bit is still a common industry practice prior to running casing to condition the wellbore, there can be drawbacks such as formation exposure time to drilling fluids. These can be problematic and lead to added time and additional project costs. New casing running technologies such as the HSRT can save hours to days of rig time by removal of the previous noted instances.
The HSRT hydraulic casing reamer shoe was conceived to assist with landing casing and liners through problematic formations that would not allow casing to pass using conventional methods, while at the same time being cost-effective and reducing rig time during deployment. The reaming shoe must also be adaptable to all casing completion configurations, casing connections and casing sizes available in the market upwards of 13-5/8″. Since the HSRT becomes part of the wellbore construction it is compatible with other casing tools and accessories such as float collars, liner hangers and today's standard down hole equipment. In addition, some casing tools such as liner hangers do have pressure limitations, so the use of a burst disk can be added for safety during deployment to further ensure a successful deployment.
This paper will outline the development of this technology and include international and domestic case histories outlining the tools’ use.
Switched Reluctance Motor Operation Using Three Conductor Electric Submersible Pump Cable
Authors: Adams Robert , Xiao Jinjiang , Harrist Jonathan , Deffenbaugh Max 
Published: March 2023

Abstract
Switched reluctance motors have advantages over traditional three phase induction motors for downhole electric submersible pump systems. Controlling an switched reluctance motor systems requires precisely timed waveforms issued from the surface motor controller to the downhole electric motor, which are distorted by the long cabling required between the surface controller and the downhole motor. Additionally, the motor architecture needs to be capable of operation using the existing three-conductor infrastructure available for elecic submersible pumps. A novel surface controller and switched reluctance motor architecture capable of controlling a downhole motor system over long three-conductor cable lengths is developed and demonstrated.
Delaying Multiphase Pump Gas-Lock in High-GVF Flows Using High-Speed Operation
Authors: Ejim Chidirim , Xiao Jinjiang , Lee Woon , Zabala Wilson 
Published: March 2023

Abstract
Many pumping systems tend to lose pressure boosting capability at high intake gas volume fractions (GVF) resulting in gas-lock. Delaying occurrence of gas-lock is beneficial to extending the operating envelope of these pumping systems. This study presents the results of operating a multiphase pump at speeds higher than typical, conventional field applications, in addition to incorporating a flow-conditioning device at pump inlet. These attributes delayed occurrence of multiphase gas-lock to intake GVFs up to 98%.
The multiphase pump tested had a 5.38-inch housing outer diameter and shaft rotational speed of 6000 revolutions per minute (RPM). A nozzle was installed at the pump inlet to facilitate homogenization. The range of total volume flow rate of air and water at pump intake was between about 4900 to 7600 barrels per day (BPD), with intake pressures approximately 50 psig. The total intake volume flow rates were varied and the pump pressure boost was measured until the pump gas-locked.
The results showed that for the total volume flow rates tested, the multiphase pump was able to provide pressure boost of about 55psi at an intake GVF of 91%. For other flow conditions when the intake GVF was increased to 98%, the multiphase pump provided a 10 psi pressure boost. An observation during the test was the gas-liquid mixture flow through a nozzle resulted in a very fine spray mist. With the nozzle installed at the pump intake, a more stable pump operation was achieved throughout the tests. In conclusion, operating the pump at speeds of 6000 RPM facilitated extension of the operating condition when gas-lock occurred in the multiphase pump. Installing a nozzle device was beneficial in conditioning the flow at entry to the pump to ensure stable operating conditions. These findings are being incorporated in a field prototype version of the pump to handle higher volumes of gas and liquid in the field.
This study mainly highlights the method used to delay gas-lock in a multiphase pump. Operating the pump at higher than conventional speeds and installing components at the pump inlet to condition the flow are beneficial to ensure the pump continues to deliver pressure boost for intake GVFs up to 98%. Extending multiphase pump operating envelope is desirable for field operators to produce more continuously and economically from wells with very high gas content.
The Effect of Graphite on the Properties of Class G Oil Well Cement
Authors: Pratama Muhammad Andiva , Mahmoud Ahmed Abdulhamid , Elkatatny Salaheldin 
Published: March 2023

Abstract
Cementing process is one of the most crucial parts in drilling operation that could determine the durability and stability of the oil or gas well. Many additives had been introduced into the formula of the oil well cement to reach certain qualities to support the well. This study intends to analyze the effect of graphite on the properties of the hardened cement samples as a function of curing time, and compare the change in the properties with that for the samples prepared without graphite. The alteration in properties of the cement compressive strength, Poisson's ratio, Young's modulus, and permeability were studied with curing time. The results showed that the graphite successfully increased the compressive strength, and Poisson's ratio while Young's modulus was reduced which indicates an enhancement in cement strength and elasticity. The cement sheath permeability was also decreased indicating formation of more tight cement sheath with incorporation of graphite into the cement slurry.