bluuebunny/crossref_metadata_2025_split huggingface dataset:
AI-Enabled, Automated Digital Dull Bit Analysis - Field Experience
Authors: Alalsayednassir Alawi , Berger Per Erik , Bergfloedt Charlotte , Schmitz Ronald , Schmitz Ryan , Emery Séan 
Published: February 2022

Background
Digitization and automation have been areas of increasing focus in the drilling industry in recent years. One critical area of drilling operations that has been largely overlooked in the drive to digitization is the assessment of drill bit wear and damage. The International Association of Drilling Contractors (IADC) drill bit dull grading standard is the current industry reference to document the condition of a dull drill bit. Since these protocols rely on human interaction and judgement, the resulting data is limited in terms of its accuracy, its consistency, and its comparability. As a result, the usefulness of this data in improving how bits are designed and operated is also limited.
This paper describes an experience of a new system, which involves scanning a drill bit, and digitally analysing the results, thereby overcoming the limitations of the current protocols. The implementation of the drill bit scanner and dull bit grading software services will contribute greatly to improve the inspection, and classification of drill bits. Furthermore, it will enable to monitor drill bit performance, and optimize drilling processes by utilizing the data provided by the system.
The system described incorporates the automated generation of a digital three-dimensional visualization of a dull bit, which is then analysed digitally to assess wear and damage, on an individual cutter basis, as well as on an overall bit basis. Since the process is automated and digital in nature, the uncertainties related to human interaction and judgement in the process typically used today are eliminated. This data can then be used to identify drilling dysfunctions, and modify drilling procedures accordingly to optimize performance, as well as to identify potential improvements in drill bit design.
Examples of digital dull bit analyses demonstrate that the bit wear data obtained from the system is much more detailed, more accurate, more consistent, and more comparable than the methods employed today. The resulting data is also much more suited to analytics, as well as other types of analyses, with a view to improving bit designs, identifying drilling dysfunctions causing bit damage, and optimizing drilling operating parameters to improve performance.
Synergistic Technique Enables Top-Drive Cement Head and Casing Running Tool Adapter to Improve Zonal Isolation with Safety and Efficiency in Colombia
Authors: Castro Fabian , Arroyave Juan Manuel , Roldan Sergio , Vela Jose David , Garcia Nelson Eduardo , Lopez Alexander , Fiaga Maria Anayibe 
Published: February 2022

Abstract
Casing rotation is a mechanical aid that improves fluids displacement efficiency and helps achieve zonal isolation. A Colombian oil company faced its biggest challenge to successfully place cement across zones with washouts, rate restrictions, and difficult mud removal.
This paper describes the deployment of a rotating cement head for cementing services on a land operation in Colombia, Ecopetrol S.A. has supported and leveraged the deployment of this technology since 2018. The Casing Running Tool (CRT) Adapter provided an enhanced system to reduce stuck pipe risks and decrease rig up time.
The main solution selected to enhance results was implementing casing rotation; nevertheless, execution had to be completed safely and efficiently.
Top-drive cement heads are commonly used in offshore operations. In Colombia, the use of a top-drive cement head was targeted as a safe solution to rotate intermediate and production casings in land operations. This method would allow for rig up, pressure test, and execution of the cement job (including rotation throughout the entirety of the job) without having to break connections or shutdown operations. The main component of the system is the cement head itself, but it was necessary to also incorporate a triple water bushing that serves to connect the cement head with casing and cementing plugs for the specified casing size. The system was enhanced by incorporating an adapter that allows connecting the assembly directly to CRT.
This configuration enabled us to complete cementing without any connection make-ups during job, which reduced personnel risk and saved any flat time.
During the installation process in prior operations, it was necessary to disconnect and rack back the casing running tool and then connect the cement head to the top drive. In some cases, the overall time to perform these actions was about 1 hour and 30 minutes. On certain wells this additional time could increase the risk of stuck pipe and prevent our ability to rotate the casing during cementing. The system has been improved by adding a CRT adapter that joins the cement head to the top drive without disconnecting the CRT.
This new system helps mitigate stuck pipe risks by reducing connection time to as little as 10 minutes while safely enabling casing rotation to improve cement isolation.
This configuration enables casing rotation during cementing in wells with high torque requirements and stuck pipe risks while improving annular cement placement. The system makes the operation safer and more efficient.
Creative Engineering Solutions Accelerating Delivery Across Onshore Horizontal Oil Producers Wells by 20% in the Middle East
Authors: Almuallim Mustafa , Silva Paul , Al Shaikh Jaffar 
Published: February 2022

Abstract
A study of detailed engineering solutions development and the analysis are described in this paper to optimize drilling and flat time operations across onshore Horizontal Oil Producers in the Middle East.
This approach discusses detailed engineering analysis conducted to enhance rate of penetration (ROP) and flat time operation. ROP of each section was increased by optimizing bit selection based on bit records and lithology analysis. Then, a road map was constructed based on dynamic analysis involving shocks and vibration, stick and slip and actual mechanical specific energy output at the bit. Flat time was minimized thru the implementation of creative initiatives including setting casing on bottom to decrease WOC time. Additionally, BHA components across vertical sections were standardized to minimize handling time. Finally, excessive time to picking up and lay down additional 5-in. pipes historically used to drill curved section and run liner was eliminated thru utilization of 4-in. DP across curved and lateral sections.
During the drilling campaign of over 30 wells, all engineering solutions described in this paper were successfully implemented and resulted in 20% optimization of overall well delivery time across onshore Horizontal Oil Producers in the Middle East. Conductor casing was set on bottom eliminating time to wait on cement (WOC), BHA configurations of drill collars, HWDPs, reamers and jar where standardized resulting in 25% optimization in flat time associated with BHA and pips handling at top vertical sections. Additionally, 5-in. pipes were eliminated through proper utilization of 5-in. HWDP to drill top holes and 4-in. pipe to drill curved and horizontal sections saving over 2 days of well time. Drilling performance was improved by over 20% after the implementation and follow up on road maps.
This study provides practical and creative solutions that can be easily replicated elsewhere to optimize well construction time. Also, this paper discusses novel solutions associated with buckling and TnD analysis for casing on bottom and drilling curved sections with 4-in DP.
Influence of Temperature Profile Modelling on the Accuracy of Hydraulic Parameters Estimation Effect of Temperature Profile Change Due to Continuous Drillstring Rotation
Authors: Zherelyev Alexandr , Molster Jon Bjorn 
Published: February 2022

Abstract
ERD wells are widely used by operators in the MENA region to maximize reservoir contact, lower cost per barrel accessed, and to be able to access far away drill targets from fewer drill centers (wellhead platforms, islands, drill pads). ERD wells and associated required technological well construction approaches by nature are typically non-standard. ERD well construction require very exact and detailed engineering analysis and methodologies to be applied in order to develop suitable and accurate drilling designs that closely matches to the actual conditions. During drilling of ERD wells, a ME operator observed that the static geothermal gradient and subsequent modelling of dynamic flow temperature did not match actual downhole temperatures, hence modifications were required to the temperature profile to match the simulation of OBM drilling fluid ECD (Equivalent Circulating Density) to actual ECD measurements from the ECD pressure sub in the BHA. This temperature effect arises from the several factors, mainly in the sub-surface environment. The resulting mud temperature is significantly higher than static temperature and this has a high impact on mud rheology, resulting pressure losses and hole cleaning. Failure to model correctly can result in mud losses or loss of horizontal section because the ECD gets above formation fracture gradient, to low flowrates for effective hole cleaning due to excessive standpipe pressures, and other problems. This paper presents how hydraulics were modelled to match actual data (rheology, ECD, SPP, BHA, Flowrate, ROP, RPM etc) in one of the longest ERD wells ever drilled.
In response to the challenges faced by a ME operator to improve the quality of hydraulic modelling and drilling design, a global Oil and Gas service company and a ME operator jointly explored the approaches for simulating Effective Temperature Profile on the giant offshore oil field, calibrated and verified it along hole with application for providing accurate estimation of hydraulic parameters. The workflow starts from analysis of actual temperature readings in upper sections of the well then uses it for simulating of Effective Temperature Profile in the reservoir section. Then simulated Effective Temperature Profile is imported to the simulation tool for proper drilling design.
Corporate Social Responsibility CSR and Citizenship Engagement
Authors: Dabbous Mohammed , Yateem Karam , Khanferi Mohammed 
Published: February 2022

Abstract
The main objective of the paper is to outline a well-established CSR program and covers a number of special social engagement events throughout the years covering diverse demographics in collaboration with multiple organizations and corporate entities of technical/professional societies and academia to effectively collaborate and conduct major activities such as:
Community awareness aiming to engage the local communities and promote the awareness of environmental conservation. Safety and environmental awareness for school students to learn tips about protecting the environment and home fire safety. Blood donation campaigns.
This paper associates the development and delivery of various programs toward serving the local content and emphasis upon the science, technology and engineering. The program is a series of hands-on workshops, 2 days per week in three tracks: science, electronics and robotics. It aims to attract more females participating in STEM fields (science, technology, engineering and math) by training teachers, engaging the students, and connecting them with female role models working in STEM fields.
The successful implementation of the subject programs has granted a top corporate performance of corporate social responsibilities. The program firmly believes in educating the local communities through workshops, campaigns, trips and awareness sessions. A number of sessions have been arranged with great participation and enthusiasm. Furthermore, professionals facilitated the delivery of petroleum engineering modules in participation of the government's gifted students’ program. This participation serves the role of attracting high achieving students to join the energy industry by showing them the exciting career opportunities the industry has to offer. Finally, blood donations have contributed to the health of the community as part of HSSE and CSR program.
The paper will also touch upon the initiation of the internal guidelines for handling the social program including the required themes, Health, Safety and Environment (HSE) and related topics, as well as the process of coordinating such endeavors.
Longest 9 5/8" Casing Cementing in ERD Well, A Worldwide-Record
Authors: Alzaki A. , S. Al-Shammari Nawaf , Masoud Zuleta Rodny , De la Cruz Sasso Alejandro 
Published: February 2022

Abstract
The efficient placement of cement as a verified barrier above a distinct permeable zone in any oil and gas well is a constant challenge faced by the industry. Absence of isolation behind the casing represents a deficiency to the required well integrity barriers. A compromised well barrier may result in casing corrosion, leaks, and eventually sustained casing pressure which might lead the loss of the asset and/or endanger the safety or workers and/or the environment.
Ultimately, a compromised barrier implies compromised well integrity. Fluid displacement in ERD wells is different from conventional wells and the job conditions pose additional challenges. To ensure adequate cement placement in this ultra-ERD well, several challenges had to be addressed. Hence, an optimized cement placement method that focused on ECD management to prevent induced loss circulation included maintaining fluids displacement regimes, fluid density, and hydraulic friction hierarchy. Moreover, casing centralization was imperative. Limiting casing string movement once the string deployed successfully to bottom equally added to the challenge.
A system's approach was utilized to achieve the level of optimization desired. Slurry rheology and fluid loss control were adjusted. A pumping schedulethat ensured that optimum displacement efficiencies were achieved in line with the designed rheology was used. The impact of pump rates on downhole ECD regimes were equally evaluated and confirmed to be fit-for-purpose. Mud conditioning prior to the cement displacement and spacer wettability were also of paramount importance. A centralizer spacing resulting in &gt;70% stand-off was utilized. These optimized practices represented the results of 3D modeling used to understand the fluid dynamics, and its distribution under the influence of a horizontal static pipe. This work also presented a comprehensive sensitivity analysis not only on the effects of thermal thinning on fluid rheology, but also on gravitational forces acting on the fluids in an ERD well. After execution, a combination of cement bond logs, ultrasonic measurements, and advanced interpretation techniques were used to evaluate the cement bond quality. The logs showed an improved cement bonding with minimal to no channeling, and excellent radial cement coverage.
As global hydrocarbon resources become harder to reach, ERD wells maybe required to access such subsurface targets. Adequate cementing well integrity is crucial to assuring the long-term integrity of such wells for the economic life of the assets. The practices implemented in this case history will contribute to expanding the tools and techniques available to engineers to achieving excellent barrier isolation in such wells.
Multi-Scale Karstic Reservoir Characterization: An Innovative Approach to Improve Reservoir Model Predictions and Decision Making
Authors: Haddad Antoine , Lathion Rodolphe , Courgeon Simon , Fabre Gilles , Martinuzzi Vincent , Pedraza Sergio , Hauvette Louis , Games Federico 
Published: February 2022

Abstract
This study consists of an innovative multi-disciplinary approach (combining borehole imagery, core data, 3D seismic and field production) which aims at better characterizing and representing karstic features in a dual porosity/permeability simulation model and improving the associated reservoir model predictions in the context of a carbonated reservoir characterization.
The applied methodology can be described as follow:
Identification and picking of karstification features on bore-hole imagery (GeologTM software) Deterministic picking of karstic features as geobodies on the 3D seismic (enhanced similarity volume (PaleoscanTM software) Integrated implementation of the karstification features into the geological model using advanced geostastical methods (Multi-Points Simulation, PetrelTM software) Implementation of the resulting enhanced reservoir properties during dynamic simulations and history matching (dual porosity/permeability medium, tNavigatorTM software).
After their deposition, carbonate reservoir series are affected by intense karstification during a prolonged period of subaerial exposure. They are consequently marked by widespread erosion; dissolution and collapsing features (e.g., solution cavities, solution-enhanced fractures and brecciated intervals) which were first recognized and picked on the borehole imagery. Typical elongated and dendritical karstic features were then identified through advanced 3D seismic attributes and then deterministically picked as geobodies. This picking was performed using advanced similarity seismic volume, at high resolution, to capture vertical heterogeneities in the karstified interval(s) of the reservoir. Then, Seismic extracted geobodies were implemented as key drivers for reservoir properties into the geological model. Since every brecciated zone on the borehole image could not be captured during the seismic picking (either due to resolution, and/or to low seismic quality zone), an advanced Multi-Points simulation was designed and implemented using the "geobody" property as a "training image" (primary constrain). This method reproduces the characteristics of geobodies, such as trends, orientation, shape, and dimensions. This method filled the resolution gap between seismic image and logs and transferred the multi-scale observations into the geocellular model.
The karst-related dynamic properties obtained through this advanced modelling workflow were then refined during history matching and considered as the main driver for variations in well productivity indexes. This tailor-made approach critically impacts redevelopment opportunities that will ultimately safeguard and increase hydrocarbon reserves.
Automatic Production Rate Estimation Workflow Considering the Reservoir Flow Regime - Kuwait Integrated Digital Oilfield
Authors: Al-Salali Yousef Zaid , Al-Awadhi Mansour , Hajjeyah Abrar , Al-Shuaib Muna , Al-Saleh Alaa , Useche Marcos , Vargas Carlos , Saxena Aditya , Idele Osaretin Greg 
Published: February 2022

AbstractThis paper presents an automated workflow that can estimate the oil and gas rates of a well, with the high frequency data, distinguishing the behavior of the reservoir under transient flow and pseudo steady state flow conditions.The new approach matches the wellhead pressure of a well model with the current value reported by a SCADA system, by adjusting the bottomhole pressure. For transient flow, it considers the response of the inflow performance relationship as a function of time. For pseudo steady state flow, it considers the declination of the reservoir pressure. The estimation of the production rate is carried out every 15 minutes, and the total daily produced volume is calculated based on the effective flowing time.To evaluate the accuracy of the new well rate estimation workflow, the output of the workflow is evaluated using two different criteria. Initially, the estimated oil and gas productions are compared with data from a real well test that is used as a quality control point. Secondly, considering that the fluid properties remain stable over time (water cut and gas-oil ratio), the critical flow through a choke valve defines a historical production trend that is used to quantify the deviation of the estimated values. As a result of the new workflow application, the difference between the estimated and measured rates decreased from 10% to 3%.The novelty of the new method is that it reduces the error of the estimated oil and gas production rates using the actual reservoir pressure behavior and provides more precise data for the different reservoir engineering analyzes.
Multiphase Pumping with Progressive Cavity Pumps
Authors: Hester Mike 
Published: February 2022

Abstract
Multiphase fluids are mixtures of oil, water, and gas. Roughly six out of every ten wells contain multiphase fluids with variations in the fluid makeup, rheology, and viscosity. They may also include small amounts of sand, paraffin, hydrates, and drilling cuttings. This necessitates local separation at the well site, which can require a significant footprint of process equipment infrastructure at or near each well site.
Ever since oil production began, produced fluids have been transferred from the well to the storage or processing facility using reservoir pressures. This means the bottom hole pressures needed to be sufficient to not only get the fluid to the surface but also move it some distance on the surface through flow lines. In cases where reservoirs are either low energy or are characterized by rapid pressure depletion curves as is common in a number of unconventional plays, this can be problematic.
In wells that are artificially produced with a down hole pump or other artificial lift equipment the pump must have sufficient pressure capability to bring the fluids to the surface and then move them some distance on the surface through a flow line. Additional pressure may also be required for the separation equipment at the end of the flow line.
Improved Clean Water Identification & Capturing in High Complex Environment
Authors: Alghanim Rayan , Fateh Ahmed , Mattar Tariq , Gonzalez-Gallardo Carlos 
Published: February 2022

Abstract
A methodology to determine water contamination levels prior sampling to guarantee the capture of representative water samples, as its highly crucial for understanding saturation profile, reservoir reserves & field development planning.
The presence of low salinity mud while trying to sample low salinity water adds further challenges in acquiring a clean sample. Especially, that the resistivity measurement sometimes won't have a resistivity contrast. Nevertheless, the conventional optical density measurement won't be able to differentiate the two water types.
Applying power law model and utilization of resistivity/conductivity and density measurements to quantify contamination levels as the fluid property in miscible filtrate & formation water will match such transition profile. Since both water base mud filtrate (WBMf) & formation water exhibit the same optical spectroscopy response, it will be quite challenging to differentiate between them. Hence, the above method is used to quantify accurate contamination. The pH measurement was also used to monitor rate of change & stabilization across pump out station whenever there's no contrast in salinities between WBMf & formation water.
The contamination calculations process can be divided into four steps: Firstly, exponent selection for the power law which depends on the inlet selection, either radial probe or single probe. Secondly, determination of filtrate properties (initial end point). Third, flow regime identification diagnostics after power law fitting. Fourth, end point extrapolation.
The resistivity/conductivity, density and pH measurements were utilized during down hole fluid analysis of water stations to evaluate the contamination levels using the power law model in a shallow carbonate environment. The model was tried for multiple inlets radial probe & single probe using different power law exponents. The results were consistent and determined the right timings to sample clean water bottles with minimum contamination levels to be analyzed at the lab. Hence, providing accurate geochemical analysis for the reservoir's field development planning and optimizing station time and avoiding unnecessary pump out in real time which saves time and cost.