bluuebunny/crossref_metadata_2025_split huggingface dataset:
Managing Wellbore Instability in Geologically Complex Field of Indian Offshore
Authors: Yahiya N. P. , Pandey V. K. , Desai A. B. 
Published: May 2024

Abstract
This paper addresses the challenges encountered during the drilling of horizontal and multilateral wells in the geologically complex Western offshore field of India. The Operator has been actively engaged in drilling such wells since the late 1980s. The primary objective is to effectively manage wellbore instability issues, specifically those arising at inclination exceeding 50 degrees, which have resulted in recurrent severe tripping issues leading pack-off, stuck pipe events and lost-in-hole incidents. The scope of this study encompasses a comprehensive analysis of the causes of wellbore instability.
The general casing policy in this field involves using a Synthetic oil-based mud system (SOBM) to cover Carbonate and Shale formations. However, drilling challenges arise when inter-bedded formations are exposed at high angles, significantly complicating the wellbore. Through a detailed analysis of stuck pipe incidents, down hole conditions, BHA details, and well profile, identified the high risk for wellbore instability. Innovative solutions were implemented, using high-tech Image logs to identify geo-mechanically stressed high risk drilling direction, the establishment of an optimal mud weight window, and the introduction of an Under reamer to mitigate tight hole conditions.
The implementation of these measures proved highly effective in handling the geo-mechanically unstable formation. Adjustments to the casing seat were made to cover potential loss areas in the upper section of the Carbonate formation. Improved Drilling Practices through Real time Monitoring were instituted to mitigate frequent back reaming and potential complications. As a result, non-productive time (NPT) and down hole complications were significantly reduced, culminating in zero cases of lost-in-hole incidents in the 2023-24 drilling season. These outcomes are pivotal for overall well cost control and contribute to the successful targeting of zones, showcasing the practical significance of the proposed solutions. This paper introduces innovative approaches to address wellbore instability, notably the utilization of high-tech Image logs and the application of an Under reamer to overcome the geo-mechanical stress issues. The emphasis on detailed analysis, data-driven decision-making, and the integration of casing adjustments, mud weight optimization, and drilling practice improvements offers a comprehensive and novel strategy for mitigating wellbore instability in a geologically complex field. The presented insights contribute valuable additions to industry best practices, demonstrating the adaptability and efficacy of tailored solutions in addressing specific drilling challenges.
Pioneering the First Stack Cased Hole Gravel Pack Completion in Turkmenistan
Authors: Gurbanov Seymur , Jafarov Ramin , Mollaniyazov Eldar , Kontarev Roman , Rovshenov Gadam , Atabayev Dovletgeldi , Mollanyyazov Hallygurban , Ushmekov Hoshgeldi , Yazmuhammedov Saparmyrat , Allakuliyev Begench , Tin Sai Aung Thu Win 
Published: May 2024

Abstract
The Dzheitune (LAM) Field, situated within the Cheleken Contract area on the eastern coast of the Caspian Sea, offshore Turkmenistan, has witnessed the execution of seven Cased Hole Gravel Packs (CH GP) operations to date. All these wells concentrated within the A-sand formation spanning a 100-meter gross interval. Traditional CH GP techniques proved suitable for the initial wells, meeting the demands of high drawdown and narrow frac window constrain. However, as exploration extended into a new reservoir characterized by a thicker pay zone, the need for enhanced technical solutions became apparent. Following detailed equipment evaluations and hydraulic modelling, it was determined that stack CH GP represented the optimal technology to unlock the full potential of the new reservoir within a short timeframe, taking into consideration the available equipment resources.
The implementation of Stack CH GP involves a two-stage process, effectively dividing the productive interval into two zones. The lower zone GP is executed using conventional methods, while the upper zone demands special considerations. In response to this, several crucial technical enhancements have been integrated into the completion design. Upper zone cleanout program has been introduced to clean the perforation debris from top of packer before/PBR stabbing into the lower zone. To ensure circulation packing efficiency added ceramic disks, which providing temporary isolation between zones during pumping operation. Importantly, this isolation could be easily disabled after the installation of the production string. To eliminate the potential risks associated with flapper disk parts, during intervention operations including ceramic disk breaking, LBFV was purposefully removed from the Gravel Pack (GP) extension.
To date, two Stack CH GP jobs successfully executed. Improved approach enabled to cover a total gross interval of 416 meters, with 210 meters for well A and 206 meters for well B. This advancement has resulted in a substantial increase in production per well unit.
This paper promises to offer significant practical insights into Stack CH GP, enriching the existing knowledge repository in related technologies. The outlined approach introduces a streamlined design for Stack CH GP, incorporating the use of a non-viscous carrier fluid. This innovative approach creates fresh opportunities for formations where costly Alternative Path systems (APS) are financially unsustainable.
An Innovative Well Design that Eliminated One Complete Hole Section, Resulting in 6-Day Savings Per Well
Authors: Agarwal Rohit , Bansal Sarvodaya , Alismail Ahmed , Paz Daniel , Levario Jesus , Corona Mauricio , Almuallim Mustafa 
Published: May 2024

Abstract
The conventional pre-set well design involves landing the well at high inclination (50 – 60 degree) on top of the reservoir using six casing policy followed by drilling of multi-laterals across the reservoir using under-balance coiled tubing drilling (UBCTD). A novel well design is presented in this paper which eliminates one complete casing string without compromising the well's objectives.
The 8-3/8-in. hole section is drilled across a highly charged formation and secured with a 7-in. Liner. Consequently, a 5-7/8-in. section is then drilled and landed on top of reservoir. The well is later completed using 4-1/2-in. cemented liner, which is mandatory as per well requirement. In this paper, the critical design criteria are explored while combining these two sections, considering well control requirements, and cementing methodologies to ensure proper separation of highly charged layers from the reservoir.
This optimization has resulted in a time saving of 6 days which enabled the well under study to set a record as the fastest well delivered in this category. This concept has been adopted in consecutive wells and is emerging as a new standard for the specific type of well.
By combining the last two sections in a single hole size, the time for running the 7-in. liner, 5-7/8-in. cleanout trip and drilling the short 5-7/8-in. hole is saved which results in a direct time savings for the operation. The paper details how the last section was drilled as an 8-3/8-in. hole and cased off with 7-in. X 4-1/2-in. liner tapered string using fit for purpose centralizers. Furthermore, to ensure the integrity of this solution, a clean-out BHA combined with inflow test assembly was run in hole and the shoe track was drilled till 20 ft above shoe simultaneously. The integrity of cement job and liner top packer was validated by performing inflow test. The well is then completed with upper completions, production tree installed and well is temporary abandoned where the CTD rig will come later in future to drill the remaining cement in shoe track and reservoir.
The optimized well design explores the design criteria for combining of two sections and presents a novel solution to explore such possibilities in other well designs.
Integrated Approach for the Characterization of Low Resistivity and Low Contrast Pays – A Case Study from Mahanadi Offshore, India
Authors: Zhunussova Gulzira Z , Panchakarla Anjana , Jha Bhawesh , Vardhan Harsh , V Rajesekar 
Published: May 2024

Abstract
The deep water formations from Mahanadi Offshore is one of the major focus for hydrocarbon exploration in India. The reservoirs in this field primarily have low resistivity and low contrast character due to presence of thinly laminated shale-sand laminae with overlying shales. Conventional logs do not sufficiently distinguish between the overlying shales against the laminated reservoir intervals- owing to poor vertical resolution of the tools to characterize the thin beds properties.
The operating company followed the standard acquisition of conventional logging data along with tensor resistivity measurement for a laminated-shaly sand analysis (LSSA) followed by formation testing. While multiple new pay sands were discovered through this method, the sand-shale-fluid model of LSSA is insufficient to provide fluid typing. Furthermore, fluid sampling using formation testers in these formations are risky due to unconsolidated nature of the formation, Plugging & SOBM invasion etc. Thus, the delineation of the formation fluid using methods other than just the formation testing is critical. The acquisition of magnetic resonance data and an integrated interpretation involving conventional logging, tensor resistivity and NMR data helped overcome these challenges, prior to formation testing. The electrical anisotropy and borehole image data helped identify thin beds. LSSA outputs based on conventional and tensor resistivity data indicated hydrocarbon bearing intervals. A continuous magnetic resonance measurement acquiring the longitudinal relaxation (T1), transverse relaxation (T2) and the diffusion coefficient (D), helped derive a lithology independent fluid typing in these wells to provide insights before formation testing.
Hydrocarbon bearing sands were identified as per the results of the integrated analysis, and the formation testing confirmed the same. Conventional resistivity inversion, LSSA saturation and flushed zone saturation from magnetic resonance provided an understanding of the invasion. The hydrocarbon bearing intervals delineated from integrated formation evaluation using LSSA and 2D NMR analysis were successfully tested and proven using formation testing and sampling. Mineralogy information helped in accurate formation evaluation. Subsequently, the exploratory well logging programs have been modified to include the magnetic resonance log in future wells. This paper provides a framework for integrated data interpretation using multi-component induction, magnetic resonance, acoustics, mineralogy data and resistivity imager logs to quantify reservoir fluids and subsequently confirmation from the formation testing and provides a workflow for exploratory wells for Mahanadi Offshore, India.
The Synergy of AI and Human Insight: Redefining Human Resource Practices
Authors: Haque S. Ul 
Published: May 2024

Organizations around the world are on a verge of embracing a major technological shift. The increasing use of artificially intelligent (AI) driven tools and solutions by organizations to bring improvements in existing HR processes and willingness to even replace traditional HR processes is undeniable (Bersin & Litai, 2020; Deloitte, 2023). We can see the traditional methods struggling to keep pace with the ever-evolving needs of the diverse workforce, technological advancement, and the progressively competitive global talent pool (McKinsey Global Institute, 2021).
During this transition, Artificial Intelligence seems to emerge as probable solution that has a potential to reshape how organizations across the globe attract, manage, and develop their talent. However, attention needs to be paid when synergizing collaboration of Artificial Intelligence (AI) with human insight as it remains the cornerstone of effective HR while AI's true potential lies in its ability to supplement, not replace, human decision-making.
This synergy between AI and HR also comes with a set of challenges to be dealt with. One of the key concerns surrounding utilization and incorporation of AI in human resources practices is ensuring ethical and unbiased use of AI. Due to the use of algorithms involved in the AI processes, there seems to be a possible risk of reinforcing existing biases in the data to be used by AI models, potentially leading to discriminatory outcomes in HR processes. Therefore, it is imperative for the HR professionals to navigate these ethical considerations and ensure responsible usage of AI in the workplace (Tian, 2021).
Importance of Wellbore Clearance on Plug & Perf Safe and Efficient Operations Execution
Authors: Alabdulmuhsin A. H. , Yilmaz K. , Mahfouz K. 
Published: May 2024

Abstract
The aim of this abstract is to present examples whereby a decrease in the bypass area between the frac plug and the casing wall caused the wireline BHA to be unintentionally pumped off from the wireline weak point during plug and perf (P&P) operations. This abstract helps engineers involved in P&P operations better understand the dynamics, forces, and details connected with pump down operations.
In any cased hole wireline bottom hole assembly (BHA), the plug will have the largest outside diameter (OD). Plugs are typically being pumped down with less than 0.25 in clearance on each side of the plug. Considering the dynamics of the fluid velocity around the plug, they can experience some extreme forces. Most plug providers provide guidance on the balance of pump rate and line rate, their goal is to manage the flow bypassing the plug. Because the bypass around the plug is so much smaller than that of the casing, the velocity of the fluid around the plug is going to accelerate. When calculating the speed of the fluid passing the plug during pump down, it must be taken into consideration, the velocity of the plug, the pump rate and the casing and plug OD.
In the first example, a section of deformed casing was suspected to cause a decrease in fluid bypass area across the plug during pump down. The decrease in fluid bypass area increased the fluid bypass velocity which created a low pressure around the plug. With lower pressures around the OD of the plug, the rubber element responded to the lower pressure causing it to swell. This swelling of the element can cause it to contact the casing and cause an instantaneous spike in line tension which triggered the BHA pump off.
In the second example, continuous hard tagging of the plug against a restriction caused the plug OD to expand due to mechanical deformation, thus decreasing the fluid bypass area between the plug and casing ID. This did not allow the plug to pass through an up-hole restriction when it was decided to POOH. A suspected surface valve manipulation caused downhole fluid movement into the well which acted on the increased plug OD which caused the BHA pump off.
These findings help in better understanding of the P&A operations. This is achieved through the in depth understanding of the variables that contribute to the mathematical equations which calculate the fluid velocity across the plug and understanding its limitations. Whenever there are signs of casing deformation, downhole anomaly or restriction, poor cement behind casing or vacuum in the well, these are all warning signs of a potential issue that could affect the fluid bypass velocity across the plug. Running procedures in future well designs will be performed to mitigate those risks when there is a possibility of a critical decrease in fluid bypass area across the plug.
Pseudo-Isotherm: A Revised Concept of Desorption Phenomena of Coal Bed Gas Reservoirs Integrating Isotherm, Material Balance, and Pressure for Optimized Field Development
Authors: Parida B. P. , Sinharay R. , Dixit M. , Upadhyay R. , Chand J. C. , Fife D. 
Published: May 2024

Abstract
Gas in the coal is found largely in the form of the adsorbed methane on the surface of micropores. Methane desorbs and diffuses from micropores to cleat systems; then cleat network delivers the gas to the wellbore. This phenomenon is empirically explained by Langmuir isotherm which is a plot between pressure and adsorbed gas content. The isotherm is generated in a laboratory, and it indicates how a particular reservoir will desorb the gas from the coal surface with a reduction in pressure throughout the production stage from startup to abandonment. This study aims to validate the laboratory-derived isotherm after a few years of field production which will have a major impact on the revised development plan with infill wells.
Assuming that the initially established isotherm is correct, the difference of the initial and current adsorbed gas volume should match closely with the produced gas volume. However, production analysis after five years indicates that the calculated produced gas volume is significantly higher than the observed, thus invalidating the fundamental material balance equation. This triggers the question - what is wrong with using initially established adsorption isotherm in recovery calculations of depleted coal reservoirs and how to correct it?
This necessitates revision/review of isotherms to match both current pressure and current GC/GIP. (Gas in Place = Area* Current GC*Thickness* density). As explained before, for CBM reservoirs; Gas content, cumulative gas prod and current reservoir pressure are direct measurements and require a very strong logic to change the parameters. On the other hand, Langmuir isotherm is a laboratory derived from a representative sample of coal which has inherent uncertainties starting from sampling to measurement. Hence, the isotherm shape is modified based on production data analysis and associated material balance results.
Taking all these empirical calculations into account, the lab isotherm is revised such that it satisfies both initial and current reservoir conditions. This solution is validated with hard field data in the form of new core holes which were drilled after three years of production. The pressure and gas content measured in those core holes were plotted which matched with the pseudo-isotherm validating the new concept.
Instead of using the laboratory-derived isotherm throughout the field life, it is modified w.r.t. production data analysis and material balance. A new name is coined in the coal bed gas or coal bed methane (CBG or CBM) industry as ‘Pseudo-isotherm’ to differentiate it from lab-derived isotherm. This method can be used in other reservoirs to optimize field development through infill wells during the production stage and unlock the full potential of coal gas reservoirs.
The Challenge of Digitizing the Integrity of Thousands of Wells
Authors: Felipe Javier Alejandro 
Published: May 2024

Abstract
At the beginning of 2019, the Reliability and Integrity team of the Upstream vice presidency at YPF embarked on the development and implementation of the methodology to manage well integrity (WIM). For months, manuals, procedures, templates, and matrices were created to identify and calculate risk in critical wells. The methodology covered the measurement of variables, impacting formulas adapted to the context of each well.
YPF, with a base of more than thirty thousand wells, half active and five thousand highly critical, sought to simplify the management of records and variables. Digitalization became YPF's bet during one of the biggest pandemics in our recent history.
But what does the computerization of well integrity management really entail?
Introducing the Power of Augmented Reality Revolutionizes Subsea Installation in Gulf of Suez. Case History: - First Time in Egypt
Authors: Ismail A. , Abdelrazik. M. , Salama A. , Abouelmaati L. , Saloma M. , Medany M. 
Published: May 2024

Abstract
Offshore drilling in the Gulf of Suez (GOS) poses major challenges when subsea structure insulation is required especially when high water depths and rough weather are encountered. A big-bore mud-line well was drilled, in the preparation to drill the second appraisal well from the same surface location, a subsea structure is required to be installed at the mud line level achieving a certain heading using smart vision Camera.
To overcome the safety and operation challenges, a pre-well planning meetings were done to survey all new technologies that can help to achieve optimum performance and cost effective solutions to run and orient subsea structure safely to the desired direction. Hence, a team form multiple discipline was performed to utilize an innovative smart camera technology benefits the power of augmented reality for the first time in Egypt to land and orient the platform template at the desired heading. The smart camera attached to a remotely operated vehicle used to determine the heading and attitude while landing the subsea structure.
Historically, conventional survey sensors are typically attached to subsea structures along with diving operations were used to run and orient substructure during installation process, which have a lot of limitation in addition to multiple safety and operational risks as
Risks associated with vessel and Rig approach due to tight space along with template latch and unlatch operation to grantee mechanism functionality Rough weather conditions in GOS during summer time which require significant wait on weather time to have the required operational weather window. Water depth of 55 meter that leads to use a costly saturation diving operations.
To mitigate the above mentioned risks with lower project cost the team decided to utilize the innovative smart camera technology that successfully determined the heading and attitude of the platform template and precisely landed the subsea structure to the desired direction within the desired accuracy. This eliminates the requirement to pre-install a sensor package on the structure, and retrieve it once installation is complete, which reduces the time and costs associated with a dive support vessel.
The paper provides a detailed description of the safety and operational challenges in this application.
Pragmatic Approach to Capture System Age for Realistic Reliability Analysis
Authors: Kar Supriyo B. , Sengupta Subhadip 
Published: May 2024

The temporal dimension of age is a universal truth. Since time immemorial, individuals from all walks of life have glorified age and the process of getting older from an abstract perspective. "The best tunes are played on the oldest fiddles!" - Ralph Waldo Emerson, "The longer I live, the more beautiful life becomes." - Frank Lloyd Wright are some of the examples where aging and maturing into a better version have been projected as synonymous.
However, in the physical world of plants and machinery, age is generally looked down upon as a harbinger of reduced ability in terms of performance, dependability, efficiency etc. This is best resonated in the words of William Shakespeare – "Where Youth is full of sport, age's breath is short; Youth is nimble, age is lame; Youth is hot and bold, age is weak and cold; Youth is wild, and age is tame."
In a typical Oil & Gas environment, all the three primary reliability indices i.e. Reliability, Availability, Maintainability of equipment/system get adversely affected by age for many of the equipment type/family. Wear and tear, Degradation in strength, Fatigue, Creep, Corrosion, Deterioration of mechanical, electrical, chemical and hydraulic nature, Poor service (Maintenance, Repair, Replacement) e.g. replacement of failed parts by partially aged ones, incorrect fitment, imperfect repair etc. are all reasons of aging and sources of age-related failure. This necessitates that during Reliability Analysis of equipment and systems, age is effectively captured and factored in the calculation process. Capturing age becomes even more important when predictions and forecasts are to be made over a substantially long duration of operation and inability to do so widens the gap between analysis outcome and reality.