bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovative Solution to Minimize Oil-Based Mud Formation Damage in Jurassic Depleted Reservoirs
Authors: Anood Al-Dhafiri , Yousef Al-Otaibi , Taha Bloushi , Majdi Al-Mutawa , Moudi Al-Ajmi , Mamoun Abdelbagi , Martinez Sebastian Sierra , Mohammed Abdel-Basset 
Published: October 2023

Abstract
This document describes how the use of filter cake breaking fluid pills in non-cemented completions across North Kuwait Jurassic reservoirs increased the well's likelihood to be stimulated and produced. It describes the process to test this innovative solution before a well trial, the wells and environment in which they have been used, and their impact in the well's ability to communicate the borehole with the reservoir. The initial step was to identify which type of mud breaking pills could be used and available in the industry and use the current OBM dispersant pills as found in cement job spacers to enhance cement-reservoir contact. A target well screening was done to wells with possible non-cemented reservoir completions. The detailed operational procedure was then designed to consider the breaker volumes, the composition of the interface's spacer high viscosity pill, and the weight of the displacement fluid to account for the hydrostatic loss in the solids-free breaker volume into each of the wells’ geometries. Finally, these wells were stimulated and tested to identify if the new approach had enabled the wells to be productive and minimize the OBM's damage.
The solution has been applied in three barefoot and one multi-stage completion wells. The first well's 380 ft 3-7/8" carbonate reservoir took 18 days to drill using 12.1 ppg OBM. Several calibration trips were done and on the final trip the 30 bbl mud breaking pill was displaced to replace the OBM within the open hole section. Post injectivity tests and an acid treatment, the well's initial production was 3 times the field average with a stabilization above field average gas production. In the second well, the 460 ft 3-7/8" section took 7 days to drill using 11.6 ppg OBM. This fluid was left in the hole to perform the acid treatment without achieving any injectivity. The entire reservoir section was then displaced with the mud breaking solution, for which injectivity and successful acid treatment and N2 activation achieved a final production rate comparable to the offset wells. In the third well, the 684 ft 3-7/8" reservoir took 3 days to drill with a 11.5 ppg OBM, which was displaced with the mud breaking pill using the drilling BHA before pulling it out of the hole. The well achieved immediate injectivity and higher than field average production. The fourth well was the first successful pilot in a multi-stage completion well, in which the OBM weight was initially lowered from 12 to 8.8 ppg, and then displaced by the breaker fluid prior to set the hanger and activate the packers.
The use of filter cake breaking pills in barefoot wells achieved the purpose of facilitating the communication between the wellbore and the reservoir, requiring lower stimulation pressures, and minimizing formation damages that positively impacted the wells’ productivity.
Estimating Continuous Production Well Flow Rates Using Ensemble Machine Learning and Deep Learning Algorithms
Authors: Martinez V. 
Published: October 2023

Abstract
This study proposes a novel approach that combines machine learning algorithms with deep learning algorithms to improve the performance of predictive models while estimating the continuous well production flow rate using daily operational conditions. This approach is a hybrid or stacked model where predictions of several base models are combined using bagging as ensemble method. The models are trained and evaluated using dataset of operational data, including well pressure, temperature, water cut, water-oil ratio, etc., collected over a period of several years. Results demonstrate that the ensemble machine learning approach achieves high accuracy. The findings suggest that the proposed approach can provide a reliable and efficient solution for estimating well production flow rates in the oil and gas industry when well flow rate measurements are not performed continuously.
Curing Packer Leak Riglessly Using Bismuth Alloy: Results of the Field Pilot
Authors: Ahmad Bilal , Yugay Andrey , Akhtar Mohamed Masud , Hijjawi Mohammad Rajai Baker , Vorozhikhin Sergei , Almuharrami Abdulla , Nadeem Amir , Varshney Mayank , Arif Ehsan , Al Harmoodi Eisa 
Published: October 2023

Abstract
Wells with positive pressure at surface must comply with double barrier policy. Packer is part of primary barrier envelope, its failure causes well non-compliance to the policy, leaving it with single barrier only. Standard practice is to perform a rig intervention to replace the packer. This paper describes the outcome of the 2nd phase (5 wells) field testing of the new technology available on the market that is designed to cure packer leak riglessly. Packer is the element of the primary barrier envelope that seals off the annulus between the tubing and the casing ("A" annulus).
The new technology consists of dropping of bismuth alloy beads from the wellhead into the tubing casing annulus aimed to descending by gravity and settling on top of the leaking packer. Once beads were in place in the annulus "A", a thermite heater was run inside the tubing on electric line and placed on depth across the beads. Upon activation the thermite heater produced an exothermic reaction melting the beads resulting in molten bismuth alloy but keeping the tubing integral. As the alloys cool and solidify, they expand to provide a seamless gas tight seal.
Pilot project was divided into two phases. The 1st phase of the pilot (3 wells) completed in 2021 (Yugay et al, 2022). The 2nd phase (5 wells) execution completed in Mar-2023. The wells are under monitoring for evaluation at the time of Abstract submission, 2 wells are showing success. Already some interesting findings and lessons learned have been obtained, that would add value for those who might think of implementing the same in their fields. Step by step execution process including verification and validation will guide you through the whole exercise and will help to design the program in a most effective and efficient way.
Positive business impact of this technology consists not only from the direct cost savings due to cancelled rig intervention (around USD2.5MM plus additional "hidden" costs associated with the well and location preparation for the rig entry), but also saved rig slot that can be utilized for the acceleration of other projects. Avoidance of the several months of the deferred production also makes this technology very attractive.
Utilizing Near-Field Hydrophones for Near-Surface Imaging Over Shallow Salt Structure Offshore Abu Dhabi
Authors: Babkina S. , Khakimov O. , Anthoine S. , Al Kaabi A. , Waqas M. , Aljaberi F. , Cambois G. , Mahgoub M. 
Published: October 2023

Abstract
The subsurface of offshore Abu Dhabi is characterized by shallow waters followed by a complex near-surface and shallow salt diapirs with associated faulting. We focus on the objective of imaging the near-surface above a salt structure in order to reduce drilling hazards and to assess if the faults reach the surface. Before acquiring a new high-resolution seismic site survey, an analysis of existing data focused on the near-field hydrophones (NFHs) from a recent ocean-bottom node (OBN) survey.
Legacy data, which included an old marine streamer survey and a recent OBN survey, were not designed to image the near-surface and could not be used for shallow imaging. NFH data were acquired as part of the OBN survey, chiefly to QC the performance of the airgun source arrays. These data included near-surface reflections, and since the source grid for the OBN survey was dense enough (25 × 50 m), we considered their use for a high-resolution 3D image of the near-surface. One challenge was strong near-field source energy that overwhelmed the recorded seismic signals.
We focus on a 100 km2 area located in the overlap zone of two zippers. Shot coverage overlap, combined with off-end shooting geometry, meant that the area was covered four times by the source carpet, which helped improve the signal-to-noise ratio. Aggressive noise attenuation was still required to attenuate the high-energy near-field source direct arrival in the active NFHs, which could only be used for the very shallow imaging. For the deeper image, we relied on the passive NFH recordings. Since NFHs are zero-offset (the hydrophones are located just above the guns), the velocity field had to be built using available wells. In the end, we obtained a high-resolution 3D image that met our objectives and helped confirm that the faults were not reaching the surface. This allowed us to forego the planned high-resolution site survey. Since the overlapping sources were shot four months apart, we also assessed the repeatability of these NFH surveys.
The resulting 3D high-resolution images were better than those from 2D high-resolution site surveys and at a fraction of the cost since no new acquisition was needed.
Leveraging Natural Language Processing for Benchmarking and Enhancing Maintenance and Reliability in the Energy Industry
Authors: Abdullah Muhammad , Rahnama Ramin , Stewart Kevin 
Published: October 2023

Abstract

Objectives/Scope
Wood aims to introduce a novel approach for rapidly and effectively benchmarking maintenance and reliability in the upstream and midstream oil and gas sectors. The proposed method will provide valuable insights at both macro (overall build) and micro (individual maintenance items) levels, with the goal of improving asset performance management and setting new industry standards. This approach promotes collaboration among industry peers and sharing of best practices, driving overall industry progress.

Methods, Procedures, Process
Our approach uses advanced Natural Language Processing (NLP) algorithms to match short text descriptions from multiple maintenance builds, utilizing techniques ranging from Jaccard similarity to state-of-the-art language model embeddings. In-house developed denoising algorithms remove unnecessary information to clarify the text, addressing potential issues of data quality and consistency. This process allows for the identification of similar tasks, which then serve as key columns to match the entire build, facilitating effective benchmarking and enabling more accurate comparisons.

Results, Observations, Conclusions
The proposed method enables swift benchmarking among maintenance builds and allows for frequent comparison at both micro and macro levels. This overcomes the limitations of traditional manual matching processes, which are time-consuming, costly, and error prone. By determining the optimal frequency of maintenance intervention to minimize cost and carbon footprint while maximizing reliability, our approach highlights the power of data- driven decisions to enhance asset reliability and streamline maintenance processes. The method fosters a culture of collaboration among industry peers, promoting the sharing of best practices and driving overall industry progress. Moreover, it has been shown to provide valuable insights that can be leveraged for continuous improvement and to address common challenges in asset performance management and maintenance practices.

Novel/Additive Information
In contrast to traditional methods that rely on Failure modes, effects, and criticality analysis (FMECA) tables, subjective understanding, or manual matching, our approach revolutionizes benchmarking using natural language processing and data-driven methodologies. This ground-breaking contribution takes away manual time and expense, improving efficiency and ensuring that the changes implemented are data-backed. These leads to continuous improvement in maintenance and reliability practices within the energy industry, ultimately enhancing asset performance management and reliability standards.
A Novel Approach to Improve Whipstock Setting and Milling Operations with Existing Downhole Measurement and Logging Technology in an Offshore Field, Norway
Authors: Elkasaby Sayed , Parker Tim , Munoz David , Slettebo Endre 
Published: October 2023

Abstract
A unique downhole measurement and logging configuration combined with a single-trip whipstock assembly was designed to significantly reduce rig time by eliminating a wireline run. The sensors that were incorporated into the whipstock assembly were configured to detect casing collars in real time to ensure the precise setting depth and orientation of the whipstock. Once the whipstock was set, downhole measurements of torque, weight, bending moment, and vibration facilitated the efficient window-milling operation without exceeding the mechanical limits of the system. Additionally, the assembly was configured to operate across a wide range of mud weights and flow rates to help manage different operational requirements.
The first objective was to locate the casing joints and centralizers in real time to ensure an optimum setting depth, which would facilitate a smooth window-milling operation. The identification of casing collars and centralizers was achieved by applying a modified calibration file to the density sensor, allowing it to identify casing collars due the localized steel mass increase. Once the setting depth was identified, the whipstock orientation was set with conventional means followed by an efficient milling operation guided by downhole measurements, which helped to optimize the operation and aid a quality window exit.
Due to the multiple operational objectives to be achieved in one run, and the requirement to operate in different mud systems and flow ranges, a detailed workflow plan with risk assessment was prepared by all parties and executed successfully. The unique downhole assembly successfully logged the casing joints and identified a discrepancy with the casing tally. As a result of this real-time information, the setting depth was changed to avoid casing collars that could have negatively impacted the efficiency of the milling operation. After the whipstock was set, the casing was displaced from brine to oil-based mud, followed by a smooth window-milling operation where the use of downhole weight, torque, bending moment, and 3-axis drillstring vibration measurements allowed the drilling parameters to be constantly optimized without compromising the integrity of the downhole tools. The positive-pulse telemetry system that was configured for a wide range of downhole flow and mud-weight conditions performed flawlessly across the complex operation with almost 100% data detection efficiency. The benchmark of window quality was defined on the following run where a heavily stabilized assembly was run over the window without any indications of the bottomhole assembly hanging up or any mechanical engagement.
Maximizing Efficacy and Efficiency in a De-Flaring Project: Integrated Gas Processing Solutions for Associated Gas Recovery
Authors: Lucherini Franco , Bildesheim Jochen , Gattinoni Federico , Bergamini Lorenzo , Ricci Alessio 
Published: October 2023

Abstract
This paper describes the solution developed by Baker Hughes to maximize efficiency in a de-flaring project by applying a Dry Gas, Liquified Petroleum Gas, and Condensate recovery system to a mid-size associated gas source. The target of the solution is to combat climate change and generate value for the industry by providing an effective approach to address the major environmental challenge of associated gas flaring (The World Bank Group, 2023). The methodology used to provide a detailed description of the recovery system is constituted by outlining the key components and their functions. The main process parameters are also presented, including temperature, pressure, and flow rate, as well as the by-product deliverables of the plant. To provide a practical example, a typical flare gas stream is used as a reference case study, representing 100MMSCFD of raw gas and equivalent to 338 CO2t/hour calculated emission. Field validated models, regularly employed by Baker Hughes in project executions, are adopted as the method to simulate process and rotating equipment performances. The fractionation of raw gas, which involves separating the different hydrocarbons present in the gas stream, is a highly effective method of reducing associated gas flaring emissions. In combination with other measures, such as improved flare management and process optimization, it can reduce emissions by up to 95%. Moreover, the recovered gases can be used to produce export products, with a recovery efficiency of over 98% for propane and heavier hydrocarbons, depending on feed gas composition. By implementing this solution, the yearly revenues generation is expected to be up to $0.2 billion (U.S. Energy Information Administration, 2022), while also helping to combat climate change. This approach represents a significant step forward for the oil and gas industry, offering a way to turn waste into value and improve sustainability. This paper presents an innovative solution to combat routine gas flaring by describing an integrated gas processing solution for associated gas recovery. The paper provides valuable insights for researchers, engineers, and stakeholders interested in addressing climate change and maximizing the efficiency and efficacy of de-flaring projects.
Techno-Economic Analysis of GTL, LNG, CNG and GTW for Monetizing Marginal Remote Gas Field: A Case Study
Authors: Gupta M. K. , Joshi N. B. , Singh V. K. 
Published: October 2023

Abstract
Monetization of marginal gas field is often a challenging task, wherein quantum of gas available is very small. In remote field unavailability of gas consumers, lack of infrastructure, long gestation period makes it an unattractive investment. In this paper, a comparative analysis of available technology helped to take a wise decision among available technology to monetizing marginal fields
For early monetization options such as power generation, utilize it as compressed natural gas (CNG), Gas to Liquid (GTL), Liquefied natural Gas (LNG) and Gas to wire (GTW) was explored. A detailed techno-economic analysis of these have been carried out which enabled us to take a concrete decision. Scenarios such as variation of production performance, tweaking the production profile for optimum return on investment, option of utilization of diesel for internal or sale to oil marketing company (OMC). Sensitive analysis has been carried out to draw conclusion to achieve the best possible return in investment.
CNG is one of the way to monetize gas by compressing it up to 250 kg/cm2g and then transporting it into a cascade mounted truck. In a remote location, where consumers are not available nearby, transportation of CNG is a difficult task and would require multiple stages of transportation & cascade storage. LNG is basically natural gas converted in liquid form by cooling it to –260° F (–162° C). Changing it from a gas into a liquid that is 1/600th of its original volume and thereby transportation will become easier. In GTW, gas is used to generate power. In GTL, gas is catalytically converted into useful product such as synthetic crude, diesel, kerosene etc. Earlier, conversion of gas into diesel was not only cost intensive but also requires high space and hence, generally not accepted for small volume of gas. A detailed techno-economic analysis depicts that conversion of gas into diesel is attractive in investment but has an issue with Indian standard quality required for IC engine. CNG or LNG which was once non-viable are viable with reference to current open market scenario
This approach will open a plethora of opportunity and will open a flood gate to monetize the marginal gas field which time and again remains stranded. Apart from marginal gas field, the said approach is also useful for minimization of flare gas and will contribute significantly in energy transition.
Abandonment of a Well Located in a High Torrent River: Under-River Project using an HWO Unit in Colombia.
Authors: Eladio Guerrero , Jinna Palacios , Roberto Saumeth , Jose Jaramillo , Dario Padilla Luis , Valentin Quintero , Diego Castellanos , Oscar Galindo 
Published: October 2023

Abstract
This paper describes the planning and execution of an integrated Plug and Abandonment (P&A) operation on a well located in the middle of the remote Magdalena River in Colombia. This project was executed using a combination of specialized technologies from multiple service lines, including well control services, Hydraulic Workover (HWO), wireline, cementing, fluids services, and completion tools. An engineering study and river support barges were also a requirement, along with the design, build, and installation of specialist equipment, such as a support structure for the high fluctuations in water levels. The planning and execution of this particular abandonment made this a unique operation, believed to be the first of its kind in the world.
This project was performed in a very complex environment where river conditions and water depths allowed only a limited operational window. Since the well had been shut in for 40 years and was located in the middle of the Magdalena River, well integrity was another key concern. Other challenges included designing and implementing a customized structure suitable for supporting HWO operations in a shallow-water environment, developing a complex readiness process that included civil works (structure design and construction), a social approach, local content development, and environmental permits and licenses.
Despite the many environmental and well integrity challenges, comprehensive planning and preparation activities were key in successfully executing this under-river P&A project. All phases (including well intervention, mobilization, and demobilization) were accomplished with no recorded HSE or service quality issues. All the activities were executed without impacting the river, fauna, and the environment. This project was also delivered 6% ahead of schedule, 35 days in total and in full compliance with contract requirements and local regulations.
This highly complex project represents an achievement for the well operator and service company as it is believed to be the first of its kind in Colombia and worldwide.
This success story is a reference for future abandonment operations under similar conditions expected to be required in the Magdalena River in Colombia.