bluuebunny/crossref_metadata_2025_split huggingface dataset:
Universal Drilling Language For Improved Safety and Efficiency in Rig Operations
Authors: Vincent Taylor , Teodoriu Catalin 
Published: September 2022

Abstract
What and how we communicate on the rigand around field operations needs some serious improvement. While there is already adrilling "vocabulary," it is inconsistent and informal. Without standardization, the current language is only moderately effective and existson a continuum somewhere between absent to incomplete. Other high-risk industries have benefited from implementing an architecture to their language,and this paper argues the energy sector would, too. The proposed Universal Drilling Language is based on the need to communicate commands, requests, affirmations, and more with precision and accuracy. Concise language considers what is necessary, excludes the extraneous, and transmits it clearly – leaving no room for misinterpretation. Creating an architecture to rig communications is essential for the next generation of engineers and operators to work safer and more efficiently.
The process for streamlining and arriving at an improved language architecture is iterative and can be accomplished by fusing human factors principles into simulation-based training. The "Driller’s Roadmap" (DRM) language experiment described herein allows pairs of traineesto use anindustry-standard drilling simulator totest and improve their communication skills. The pairs attempt rudimentary drilling tasks in three distinct phases of varying communication styles, and task performance is compared across scenarios. The communication phases tested include using "natural" intuitive words and phrases, scripted "imperfect" phrases, and scripted "perfect" phrases. Results show that exposing trainees of different backgrounds and experience levels to this simulation-based communication training can simultaneously improve their human factors skills and task performance. Furthermore, the DRMleverages drilling simulator technology tocreatea"human-in-the-loop" training methodology for the petroleumindustry. This research and itsresulting language will shorten the industry’s learning curve for future verbal-computer interactions and machine-based task interpretations. More importantly, the standardization of a drilling language can improve safety and efficiency for all future rig operations worldwide.
Investigation of Matrix Damage and Remediation Methods of Preformed Particle Gel Conformance Control Treatments in Carbonate Reservoirs
Authors: A. Almakimi Abdulaziz , Liu Junchen , Bai Baojun , A. Hussein Ibnelwaleed A 
Published: September 2022

Abstract
Preformed Particle Gels (PPGs) have been widely applied to control excessive water production in mature oil fields with fractures or fracture-like features, especially in sandstones, but with limited attention to carbonates. However, a vital concern arises regarding the potential damage of PPGs on the adjacent matrix that might promote negative results. This paper comprehensively evaluates PPGs’ potential damage to the carbonate matrix and seeks design optimization solutions. Filtration tests were applied to compare PPGs’ penetration into matrix under different sets of conditions. The filtration regimes were defined by filtration curves and the gel damage on matrix was determined by permeability measurement results. Experiments were conducted to investigate the efficiency of an oxidizer as a remediation method to remove the damage. The qualitative description of gel particles’ invasion and plugging behavior in the carbonate matrix was presented based on the analysis of filtration test results and permeability measurements.
Results show that the swollen gel filtration curves can be divided into three regions: prior-filter-cake, filter-cake-building, and stable stages according to the gel particles’ response to the injection pressure and effluent flow rates. PPGs can form cakes on the rock surface to prevent particles’ further penetration into carbonate matrix, and the penetration was only limited to less than a few millimeters. The smallest gel particles (50–70 US mesh size) were more likely to form external and internal filter cakes at higher pressure values (700 psi) and result in more damage to the matrix. To restore the matrix permeability after filtration tests, oxidizer soaking was proved to be a reliable solution. In all, the results indicated that unintentional matrix permeability damage induced by gel injection is generally unavoidable, but conditionally treatable.
Evaluation of Various Designs for Scale Inhibition Squeeze Treatments in Carbonate Reservoirs
Authors: Alissa Faisal , Altowairqi Rashed , Alhamed Khalid , Alsubaie Abdulaziz 
Published: September 2022

Abstract
Scale is considered as one of the major concerns in the oilfield industry. Usually, scale formation causes several issues such as: reduced production, formation damage, jeopardizing well integrity, and causing damage to assets such as artificial lift equipment. Therefore, a scale inhibition operation has to be conducted to sustain oil and gas production by assuring the flowing conditions of the reservoir and production assets. Scale inhibition in oilfield industry is carried out in one of four ways: 1- squeezing the inhibitor inside the formation, 2- continuously injecting the inhibitor through a capillary tubing, 3- apply an encapsulated inhibitor in the rat hole, 4- applying batch treatments. In this study, we are evaluating various treatment designs for the scale inhibition through the squeezing technique in terms of efficiency and lifetime. The efficiency of scale inhibition squeeze treatments is bound to a certain lifetime which depends on the interaction between the inhibitor and the reservoir rock. The inhibitor interacts with the rock in an adsorption fashion, then it desorbs to maintain a certain concentration in the aqueous portion of the produced fluids; thus, inhibiting scale deposition. When squeezing the scale inhibitor deep inside the reservoir, the inhibitor has a greater surface area to adsorb onto; therefore, less of it will be retained when flowing the well after the operation. The drawback of the squeeze technique is the duration, and the inhibitor loss right after the operation, the greater the inhibitor production the shorter the treatment lifetime. Squeezing the treatment deep inside the formation has reduced the inhibitor concentration; thus, increased the treatment estimated lifetime by almost 5 folds.
Pressure Transient Analysis of Fractured Horizontal Wells in Multiple-Well Pads With Complex Fractures Using a New Numerical Model
Authors: Chen Zhiming , Zhou Biao , Liao Xinwei , Wang Bin 
Published: September 2022

Abstract
The technology of multi-stage, multi-well pad fracturing is an effective way to increase the stimulated volume and recoverable reserves in shale reservoirs. During the fracturing treatments, there are common phenomena of well interferences from the multi-well pad. However, there still lacks an understanding on the transient behaviors of well interferences, which is harm for applications of well testing to analyze the parent-child interactions and to evaluate the fracture parameters quantificationally. To narrow this gap, pressure transient behaviors of fractured horizontal wells with secondary fractures and well interferences are studied by a numerical pad-well model, based on a discrete fracture model (DFM) and unstructured PEBI grid system.
First, the pressure transient solutions of fractured horizontal wells with secondary fractures and well interferences have been demonstrated by model verifications. The results show that the flow regime of interference effects caused by parent-child interactions are more obvious, with a larger child-well production, a smaller well spacing, and a larger hydraulic-fracture angle. The well interferences are also stronger when the child well has more secondary fractures, longer secondary fractures, and higher fracture conductivity, as the pressure drop caused by child well will propagate more quickly. Once the complex fracture networks have developed within the multi-well pad, the interactions between parent and child well will be weaker with the increase in area and conductivity of fracture networks. By comparison, the pressure transient behaviors of Parent well are remarkably affected by Child-well production rate, well spacing as well as connectivity degree. However, the angle, length, number, and conductivity of secondary fracture have weaker impacts on the pressure transient behaviors of Parent well. This work provides a meaningful way to understand the pressure transient behaviors and to evaluate the fracture parameters of multi-stage, multi-well pads.
Reformatting Petroleum Industry Communications for the Educational System and the Public
Authors: Ershaghi Iraj , Paul Donald 
Published: September 2022

Abstract
The Energy Transition is creating a new operational and strategic framework for the oil and gas industry. One specific dimension of this new framework is the management of "reputational risk" and "the social license to operate." Despite the clear and demonstrable contributions of the petroleum industry to our modern industrial society, the reputation of the industry in the United States is often seen as generally negative, and improving it remains a challenge. This poor characterization is negatively affecting the flow of new investment capital and recruiting of young talents to the industry. The power of negative publicity can also unnecessarily limit the development of needed oil and gas resources and infrastructures, with long-term economic consequences for the economic health and standard of living of the society. In this paper, we propose that the new societal expectations developing as part of the Energy Transition will require a "reformatting" of the industry's communication processes for both the educational system and the public at large to correctly position the industry as a positive and vital contributor.
A Review of the Digital Twin Technology Application in Energy Industry for Performance Improvement
Authors: Ahmad Shatiry M Sahir , Harun Firdaus , Azman M Muaz , M Amin Ahmad Helmi , Husni Zul Hazran , Abu Akbal 
Published: September 2022

Abstract
The paper investigated the use of digital twin (DT) technologies in the energy industry. It analyzed the available digital twin technology used in the energy industry using the SWOT method. The DT serves as the real-time presentation of the actual process or physical object with the Internet of Things (IoT). Typically, fabrication work productivity depends on the process flow and the human behaviours that contribute to delay or non-productive time—digital technology to learn the overall process, human behaviour, and machinery uptime. Visual learning was established to monitor the operation activity as well as the construction work and to capture the general behaviours of the human such as welding, resting, taking a break or even non-productive work such as break outside break hour, smoking, wrong sequence of the working process and other external interruptions. This study will explore all the available DT technology in the market and its function and capabilities and then identify five (5) DT technology applications that can improve performance in the energy industry. After that, to determine and summarize the strength, weakness, opportunity, and threat of all five (5) applications of DT technologies already used in the energy industry using SWOT methodology. The SWOT analysis found that the benefit in terms of Strength and Opportunity is more significant than the threat and weakness of the Digital Twin technology. Then, it is clearly indicated that the DT technology is capable of utilising in many other areas of business in objective to understanding the overall system efficiency and capable of providing information for accurate and precise decision making for the company.
Machine and Process Automation are Improving Personnel Safety and Drilling Performance
Authors: Whatley Michael , Ayanambakkam Arima , Patterson Derek , Farrow Blakley , Feng Le , Hewitt Parker 
Published: September 2022

Abstract
The industries’ number one priority is ensuring everyone goes back home in the same condition they came to work. With that guiding principal in mind, how could a drilling contractor work to substantially reduce our crews health, safety, and environment (HSE) exposure? Engineer solutions that take them off the most dangerous place on a drilling rig. Traditional drilling processes require personnel to manually handle tubulars while making connections, building stands, or racking back pipe. This requires personnel to perform strenuous tasks in dangerous areas. These areas often require personnel to work near moving machinery. Manual operations often lead to high degrees of variability in performance based on rig crew experience and familiarity of the operations.
Development of a fully automated rig required overcoming many challenges to process tubulars from the ground to well center. New machines were designed to meet the automation requirements. The ground handling system was designed to clean, dope, and measure pipe. The robotic pipe handler was designed to handle retrieving tubulars from the ground handling system, deliver to well center and spin in the connection. The automated floor wrench is responsible for making up connections. The rack and pinion hoisting system was designed to handle the drill string with precision and eliminate the need to slip and cut drill line.
To achieve the desired automated tripping and drilling process automation, a rig operating system with sequencing functionality, tubular management, and zone management was required. The rig operating system integrates the different machines and manages the necessary protections at the machine layer. The sequencing layer is responsible for coordinating the process automation at the appropriate set points for rotary drilling, slide drilling, tripping, and casing connections.
The robotic rig has currently completed 9 wells and has continuously improved since the start of drilling in August. The drilling connection times have improved by 28% and the rig became the third fastest across the fleet. Additionally, the rig has improved its casing running performance by approximately 43% and is now within a few joints of other top performing rigs in the fleet. Fully automated control of these processes guarantees consistent and repeatable performance across the wells drilled. This is all being done without the need to have personnel handling tubulars in the mast or on the rig floor.
The success of this first of its kind robotic rig can be attributed to partnerships with the operator, the drilling operations team, the rig engineering team and the controls and automation team. The teams collaborate to identify areas for improvement to continuously drive better, safer, and faster drilling.
Degradable Thermoset Composite Frac Ball for Offshore Well Stimulation
Authors: Kovalchuk Anton , Garza Ramon , Stone Matthew , Sadana Anil 
Published: September 2022

Abstract
Degradable frac balls are used widely in unconventional stimulation operations for sleeve activation. The objective of this work was to develop a new degradable frac ball product for challenging offshore multistage fracturing systems where conventional degradable metal frac balls have challenges due to high hydrostatic pressure or lack of suitable degradation fluid. The scope of work included creating a new blend of material and accompanying test methods to meet application requirements. These requirements were that the degradable frac balls i) exhibit no degradation in the ball launcher during stimulation operations, ii) are able to degrade at high pressures (up to 15000 psi) in the presence of oil below the ball and iii) create by-products that do not plug or adversely affect the completion/production.
In this paper, we report the development and testing of thermoset polymer composite balls designed primarily for offshore well stimulation applications. This polymer consisted of a cyanate ester thermoset composite that exhibited excellent mechanical properties (compressive strength 37 ksi; tensile strength 14 ksi and tensile modulus 2 Msi).
Frac balls with sizes ranging from 1.30″ to 3.18″ were compression molded and pressure tested to ensure a pressure differential rating of 5,000 psi across a ball seat with approximately 0.16 % engagement at 150°F. This material was found to degrade in fresh water and various brines when exposed for two or more days at temperature&gt;250°F, making it applicable to deep-water completions. The residual products of the degraded composite balls were tested for production screen plugging and demonstrated no risk of plugging to the test equipment.
These results demonstrate the feasibility of this new material to be used for deepwater hydraulic fracturing operations.
Modeling Heat Pump Technology for Economically Attractive Decarbonized Oil Production Systems
Authors: Keihany Julian , Baaren Sander 
Published: September 2022

Abstract
Many operators with large stakes in unconventional shale oil plays have published targets to drastically reduce emissions with some considering carbon emission tax for economic evaluations of future projects. This creates the need for finding electrically powered alternatives to replace equipment that currently consumes fuel gas, such as fired heaters. Production facility designs for unconventional shale must be simple, robust and require relatively low CAPEX and OPEX to be economically viable. This poses a challenge for electrically powered alternatives because fuel gas is freely available at production systems, whilst electricity comes at a cost. To address this challenge, novel fully electric production system designs have been developed based on heat pump technology. The practical and economic feasibility for these designs are evaluated and demonstrated so that these can be considered as realistic solutions for future projects.
The major reasons why crude oil must be heated at upstream production facilities are to break potential emulsions of oil and water and to stabilize the oil. Stabilizing the oil means that volatile components are removed from the crude, so that it can be transported and stored in tanks without emission and safety concerns. The novel production systems achieve this by pairing a single stage electrically driven heat pump with heat integration. The novel production system designs are analyzed using steady state and dynamic simulations employing industry accepted process simulation software. The steady state simulations generate metrics such as energy consumption, estimated emissions and hydrocarbon recovery which are used in conjunction with emission factors and other economic factors to compare the performance to standard production facilities. The dynamic simulations are used to demonstrate the feasibility for starting-up and controlling the facility for this novel technology application.
The simulation results demonstrate that the heat pump based designs consume around 70% less electrical power compared to direct electrical heating. Further benefits are that the temperatures can be controlled at various stages in the process to substantially increase the facility's oil recovery. This also results in leaner gas, which is particularly attractive for facilities that include gas compression and dehydration. The increased oil recovery results in substantially higher revenue which leads to an economically more attractive design compared to a traditional facility, even without taking carbon emission tax into consideration. These comparisons are provided for different types of facilities during different production scenarios during varying weather conditions.
Next Generation Acid System — Deep-Penetrating Non-Corrosive Fluid for High Temperature Sandstone Stimulation
Authors: Zakaria Ahmed , Hudson Harold 
Published: September 2022

Abstract
In high-temperature sandstone reservoirs especially at temperatures above 450°F, the rapid reaction of the acid treatment fluid and the secondary/tertiary reactions with the clays lead to formation damage. Moreover, at these high temperatures, the HCl/HF based acid systems are extremely corrosive to the wellbore tubers and downhole equipment's. This paper presents the next generation acid system that utilizes non-corrosive fluids to generate HF acid for high temperature sandstone stimulation.
The non-corrosive deep-penetrating acid is a neutral, non-reactive treatment fluid at the surface and only when it is injected in the formation, it generates HF at a controlled rate in situ under temperature and time. The in-situ generated HF at a controlled rate allows for deep penetration of the acid in the formation. A series of solubility testing in HPHT reactor was first conducted to understand the chemical reactions that generate the acid as a function of temperature, concentration of acid generating components, and time, and to identify the optimum composition that maximize the dissolving of quartz and minimize the potential precipitation from reaction with clay minerals. Coreflow testing was then conducted at 475°F using 1.5″ in diameter and 6″ in length Berea sandstone cores to evaluate the performance of the new acid system for sandstone stimulation.
Solubility testing showed that the new acid system has high dissolving power for calcite and silica and potential to minimize precipitations when reacted with clays. In Coreflow testing, the non-corrosive deep penetrating acid is effective to stimulate sandstone and provides remarkable permeability improvement by at least 60% at 475°F. Because of the in-situ controlled generation of HF, it penetrates deeper in the formation and minimizes the potential for precipitations.
The non-corrosive deep-penetrating fluid system provides the industry with an effective solution to deeply stimulate sandstone reservoirs unlocking the full potential especially at temperatures above 450°F, and a safe non-corrosive fluid for wellbore tubulars and equipment. Moreover, the new fluid technology would eliminate the need for acid tanks on site, reduce transportation difficulties, and eliminates HSE concerns and acid exposure to personnel in the field.