bluuebunny/crossref_metadata_2025_split huggingface dataset:
Technology & Knowledge – Support for Learning Curve Implementation. An Experience in Off-Shore Oil Developme
Authors: Marchetti Pier Zaverio , Ezzaroug Adel , Fabro Gabriele , Parziale Sabino 
Published: November 2018

Abstract
The scope of this paper is to highlight, through the analysis of the technologies used and the specific knowledge of the operational team, that the combination of technologies and know-how of the operative people are the key factors for success in well operations.
Description of the different technologies applied during the development of an off-shore field in conventional water as adjustable well head, temporary P&A with mechanical bridge plug, LWD strategy and implementation of the design and procedure developed by the operative team during the activities, based on the real feedback, as light vs high casing profile, 21 ¼″ instead of 29 ½″ diverter using CP 20″ vs 30″, 4 ½″ mono-bore completion for horizontal wells, CT mill motor 2 7/8″, Plug&Perf® methodology, fracture operations material and methodology.
Application of these technologies and knowledge of the integrated team gave a sensible reduction of operative time (40% for vertical wells and 50% horizontal wells in comparison to the initial development well drilled) and relevant cost. The paper will analyze the evolution of the drilling and completion programs and the technologies applied in order to improve efficiency in operating time with reduction in drilling and completion cost. The main topics that will be presented are: ➢Light casing profile (13 3/8″ – 9 5/8″ – 7″ – 4 ½″) vs Heavy (20″- 13 3/8″ – 9 5/8″- 7″- 4 ½″)○20″ CP drilled vs 30″ CP hammered○9 5/8″ casing middle alt depth vs 9 5/8″ below bottom salt➢Optimized LWD strategy - wire line only as back-up➢CP hammering (WHP4) - off line hammering in parallel with other operation with JU➢CP 20″ vs 30″ - smaller hole and material stock optimization (WHP3)➢21 ¼″ instead of 29 ½″ diverter (WHP3)➢OBS II adjustable well head for 9 5/8″ casing (WHP3)➢P&A with Bridge Plug (Archer plug) instead of cement plug (WHP3) for temporary abandonment➢Use 4 ½″ mono-bore completion for horizontal wells➢Bigger CT mill motor 2 7/8″ on 1 ¾″ coil tubing.➢Plug&Perf® methodology used for selective fracture operations.
The paper gives a real experience on how a combination of technology and human experience of the integrated team gives excellent results on learning curve with good impact on Operating Time and relevant cost associated.
What Happened During Normalization?
Authors: Ramachandran Karthik Nataraj , Al Hammadi Ayesha , Al Hosani Khalil 
Published: November 2018

Abstract
Building a performance driving culture is often analyzed from the viewed from the perspective of standardization of the performance appraisal process. What is often ignored is the assessment of the behavioral change required to ensure that all the employees are aligned to the desired culture. The organization under review has introduced the concept of "Normalization" to bring fairness, transparency and alignment of the required culture. Using the concept of sensegiving and sensemaking, this paper explores if the Normalization process has achieved the desired objective of reducing the gaps between the desired and actual culture orientation. This is done though the analysis of the feedback on the employee's performance by the line manager and the normalization committee. This textual analysis is then compared against the desired scheme of the rating descriptors to analyze the gaps in the culture building process. According to the authors this may be the first time observational and textural analysis is used for this kind of research.
Optimizing the Completion Design of a Maximum Reservoir Contact Well for Enhanced Deliverability, Monitoring and Accessibility
Authors: Gharbawi Shihabeldin , Saqib Talha , Kaouche Salim , Sabri Abdul Moez , AL-Mehairi Omar , Mutairi Ali Al 
Published: November 2018

Abstract
The Maximum Reservoir Contact (MRC) concept was developed to improve well productivity and sustainability by maximizing the contact area with target reservoirs. MRC is a proven technology for the development of tight/non-economical reservoirs. Completion design for MRC wells plays a vital role in enhancing well deliverability, monitoring and accessibility.
MRC technology was put into application to appraise a tight and thin heterogeneous carbonate reservoir in a giant offshore field in Abu Dhabi. Different completion scenarios were simulated to select the best suited completion to achieve enhanced well deliverability, monitoring and accessibility.
Heavy casing design with liner and tie-back system was finalized to maximize accessibility and achieve proper isolation behind casing. A special pre-perforated liner was also designed to eliminate the pressure drop across the wellbore. The MRC drain was divided mainly into two sections, blank pipe and pre-perforated liner equipped with swell packers for isolation. Pre-perforated liner was subdivided into compartments for proper flow distribution, accessibility and monitoring.
The blank pipe was utilized to isolate the potential gas zone. Fractures and faults presented a major challenge in achieving the well objective. Special logging requirements were also considered for proper characterization of the suspected faults/fractures as well as to confirm and locate the source of gas risk for compartmentalization.
For proper accessibility, monitoring, stimulation and sustainable production, tapered upper completion was designed and equipped with permanent downhole gauge for continuous monitoring.
The well was successfully drilled and completed with production performance exceeding expectation which will indeed pave the way to apply MRC technology to unlock the all-out potential from undeveloped tight heterogeneous reservoirs within the field.
Application of Underbalanced Coiled Tubing Drilling Technology to Enhance Gas Production in Deep Carbonate Reservoirs
Authors: Guizada Pablo , Rahim Zillur , Aliraani Bodour 
Published: November 2018

Abstract
Heterogeneus deep carbonate reservoirs require enhanced development strategies to maximize reservoir contact and ultimately to increase the recovery factor. In some complex carbonate reservoirs, conventional strategies for reservoir development are not always the best choice and new technologies have to be applied to optimize the reservoir development. In such cases, underbalanced coiled tubing drilling (UBCTD) has proven to be a suitable approach to exploit more complex reservoir areas, where conventional drilling and stimulation techniques no always meet well productivity expectations.
The UBCTD technology consists of drilling a well with a drilling fluid pressure lower than the reservoir pressure, which tends to minimize the formation damage. Due to the underbalanced condition imposed in the wellbore, the well is allowed to flow naturally during drilling, while its productivity is measured. Another technique that accompanies this strategy is called bio-steering, in which cuttings are inspected while drilling to detect micro-fossils from the reservoir. Based on the real-time well productivity and the micro-fossils appearance, the well trajectory can be adjusted and corrected during drilling to chase the good wellbore productivity layers.
A number of wells has been drilled using this strategy with encouraging results so far, which opens a great window to continue exploiting the reservoirs under development. With this technology, multilateral placement is possible with a high degree of accuracy across thin reservoir layers, which maximize the reservoir contact and increases the well productivity. This work presents a general description of this technology as well as present a successful field case including all stages from well planning to well execution and testing.
Drilling Optimization in Action - Delivering 125 Field Records in 6 Quarters
Authors: El Hawy Ahmed , Al Busaidi Adil , Vasquez Bautista Ramiro Oswaldo , Awadallah Muhannad , R. Heidari Mohammad , Saidi Khaled , Escamilla Barton , Al Abri Zahran , deBoehmler Guy , Al Harthi Said , Haeser Patrick , Al Riyami Khaleel , Picha Mahesh 
Published: November 2018

Abstract
As one of the worst oil & gas business downturns struck, the need for a revolutionary approach of drilling was needed. Optimization was the key word during that period, it was about time to look back at drilling fundamentals, review and learn from previous failures and lessons while establishing new foundation for a transformed yet successful process that ensured an all-time historical success.
While many trials of drilling optimization initiatives were executed over the years, inconsistent drilling performance delivery and repetitive failures continued to raise a red flag each time for variety of reasons. Drilling optimization in action was then introduced with its’ comprehensive drilling optimization package, where all historical norms, failures, lessons, and designs were analyzed thoroughly. New objectives and revised designs were proposed accompanied with a whole new process that ensured success.
From challenges achieving required performance levels and dog legs in the top sections with increased risks of axial and lateral vibrations, to the difficulties faced in the landing section drilling through unconsolidated and reactive shales in the north, and through fragile weak formations in the south to the difficulties transferring weight to the bit at deeper depths in the horizontal laterals drilling highly porous zones of sticky limestones.
Drilling optimization in action project was successfully introduced and executed with a renovated set of drilling parameters envelopes, revised trajectory designs, re-engineered BHA designs, right choice of fit for purpose bits models, adequate technology utilization and effective real-time performance reporting and monitoring.
While cost optimization was the trend during the downturn, there was no better option to achieve desired financial results for both operator and service provider than the inclusion of the drilling optimization in action initiative into every well drilling program, it was proven to be an ultimate win-win technical and business solution.
Multistage Fracturing Completion in Vertical Wells - Is it Applicable? Yes
Authors: Ibrahim Ehab , Sayapov Ernest , Hinai Rashid , Qarni Sulaiman , Kristanto Royke 
Published: November 2018

Abstract
In low-permeability formations such as tight gas reservoirs, a well would be economic only if an effective hydraulic fracturing technique is selected. In central part of Sultanate of Oman a deep tight gas field is developed with hydraulic fracture stimulation. Normally, between 7 and 13 frac stages are done per well. Majority of wells are vertical with pay zones separated with shale layers that prevent fracture growth. Plug & perf is a common technique used in this field, therefore there are multiple well interventions during Hydraulic Fracture operations that consume time and delay the well delivery. By deploying multistage frac completion with the objective of producing, enhancing and cost/time savings, the effectiveness of the fracturing operations was expected to increase. Equipment selection, design and development was performed based on well conditions, casing design, operational parameters and production gas composition.
Multistage frac completion allows the frac operation to be continuously performed without the need to conduct intervention activities such as running/setting frac plugs, perforating, milling and clean-out between intervals. The intervention activities can be conducted at the end of the frac operation in single-trip deployment if desired. The success in North America in horizontal tight gas wells has opened a door for implementation of this system in vertical wells in Sultanate of Oman. The main challenge in deployment of this system in vertical wells is the accurate positioning of the sleeves. The shale layers between the pay zones could be as narrow as 5 m or less and a small pay zone might be easily missed. Besides, deployment and cementing operations are equally essential as proper zonal isolation is a must with water zones embedded in between.
This paper is discussing the lessons learned from utilization of multistage frac completion in vertical deep wells (around 5000 m) covering the completion and Hydraulic fracturing stimulation operations. This technique has proven significant cost & time reduction and production increase as well as reduced HSE exposure contributing to better gas recovery, improvement in operator's performance and energy delivery to the country.
Use Metaheuristics to Improve the Quality of Drilling Real-Time Data for Advance Artificial Intelligent and Machine Learning Modeling. Case Study: Cleanse Hook-Load Real-Time Data
Authors: Al Gharbi Salem , Ahmed Moataz , ElKatatny SalahEldin 
Published: November 2018

Abstract
The drilling engineers are overmild with huge amount of data-points, argue the need to develop Artificial Intelligent (AI) and Machine Learning (ML) models to crunch these huge amount of data generating decision-like information. There are a lot of challenges developing such approach, varying from computational power, lack of subject matter experts, and develop the optimum algorithm. But the main bottleneck is the quality of the data. Regardless of how advance AI/ML model, if the data is bad, the model will generate bad result; garbage-in garbage-out. The scope of this paper is to use metaheuristics models to improve the data quality. The process start by extracting Hook-Load drilling real-time data. And explore the raw data quality using visualization and statistical methods. Then apply several Metaheuristics models to generate functional approximation equation that identify/ follow the trend of the good-quality data. This will be by employ multiple scenarios with different degree of randomness that lead to the highest matching which generate the high quality level. The process will cover different technique including Greedy, Hill-Climbing, Random Search, and Simulated Annealing. During this process hundreds of thousands of scenarios will be conducted to simulate the Hook-Load data, to identify the optimum functional approximation equation that match the best data quality. Which can then safely integrated into the advance Artificial Intelligent and Machine Learning models. Running such process require an expensive computational cost, since it includes huge amount of real-time data need to be process under complex advance models. Moreover it require a deep understanding of the internal process of each models to ensure finest manipulating them to get the optimum data quality result. Running these scenarios, lead successfully to functional approximation that spill the data behavior, with Mean Absolute Error (MAE) equal to 10.5. It is worth height that functional approximation is very expensive in term of time and complexity, but it generate the highest quality result, leading to better AI/ML model. Moreover it is the most dynamic approach allowing it to be applied in other drilling real-time parameters as well. Utilizing Metaheuristics approach to improve the data quality is new to the upstream domain in general, with almost no application in drilling in specific. The novelty is to introduce this advance technique into the drilling real-time data domain, it will sharply improve the data quality leading to higher Artificial Intelligent and Machine Learning prediction/ analytical models. It worth mentioning that such approach will run all those simulation/ scenarios and adjust itself automatically with almost no manual interference. Leading to self-data-driven data-quality model.
Operationalization of a New Systematic Work Process at PETRONAS Carigali Sdn Bhd
Authors: Choudhuri Amit , Jainal M Saifunazim , Adenan Mustafa , Takei Jamaludin B , Ali Toslan B , Janor M Nazori 
Published: November 2018

Abstract
An innovative work process for integrated and collaborative way of working has been developed and is being operationalized throughout all PETRONAS Carigali operating blocks, within Malaysia and also, in all International Countries wherein PETRONAS Carigali is the operating partner. This process is inline to the Company's vision for a phenomenal shift in the way that the company's workforce accomplishes its tasks, employing latest digital technologies and efficient work processes. Through this work process, the intention is to integrate all systems and tools, adopt collaboration between various work disciplines and come up with a novel work process that is lean with the prime objective of maximizing production and improving the production efficiency.
This integrated and collaborative work process is being named as Reservoir Well Facility Management (RWFM), encompassing all the six production lenses and is thus an end-to-end business process. The geographical areas of operation of the Company are vast and scattered across the world. Thus, a need has been felt to standardize the work practices across all operating blocks in order to ensure that there is a standardized and integrated way of working at every work location. Also, there have been a number of digital solutions deployed over the last couple of years and the immediate need is to integrate all these solutions as well as to enhance their utilization. This RWFM work process will facilitate increased utilization of the tools as well as integrate all the current solutions.
The new work process has been deployed as a program at most of the Assets of the Company. The process will take some time to be fully practiced and the program team will be looking at a stabilization period before the Assets actively implement it in their daily routine. There is a Change Management effort ongoing in parallel to assist the operationalization team and to bring in the mind set change to inculcate the new way of working. This paper will entail a detailed discussion on the work process and the operationalization activity undertaken by the focused team.
New Techniques Developed to Safely Unload and Test High Rate Offshore Sour Gas Well With 7-in Monobore Completions-Lessons Learned Gas Wells Offshore Sarawak Malaysia
Authors: Azraii Azraii Fikrie , Adhi Adhi Naharindra , Hui Chie Thian Hui , Claire Claire Chang , Ridzuan Ridzuan Shaedin , Roh Cheol Hwan , Zarir M. Zarir , Firdaus Firdaus Bidi 
Published: November 2018

Abstract
Sarawak, Malaysia first offshore high rate dry gas field has an over pressured reservoir. Successful pressure control during drilling required the use of barite in the water based drilling mud in PMCD mode inside carbonate. Barite is very abrasive and is insoluble in any acid or solvent. Any barite left in the reservoir due to mud losses has to be produced back to surface after completing the wells. This cleanup is crucial for the safety and longevity of permanent facilities, especially when high rate gas wells are involved; due to the high rate of impact of any solids that may be produced with the gas. It is also critical to design the cleanup job carefully to ensure proper equipment and safety measures are taken to avoid washouts and related safety hazards.
To ensure solids free production from day one, a procedure was implemented and successfully executed during the development of this first offshore high rate high-pressure sour gas field. This was achieved by using the tender rig as a main support and complementing the safety with the incorporation of the selected well testing equipment management system. In addition to the proper equipment, a detailed cleanup procedure, which covered systematic production ramp up and defined solids free criteria, was implemented from well owner or asset. So far, this well cleanup setup and program has been implemented on several wells on platforms with minor erosion and no safety issues.
One platform with several wells is already producing and is flowing trouble free. This paper will describe the details of the setup of the rig facilities to clean these barite fluids from the wells, and the solids control equipment used and the cleanup procedure.
Specific Analyses for the Reassessment of Existing Offshore Platforms Under New Seismic Conditions
Authors: Brocherie Jérome , Bounhoure François , Barbier Frédéric 
Published: November 2018

Abstract
The recent major seismic events in South East Asia have led the Oil & Gas Companies to reevaluate the design of their offshore platforms with sometimes more stringent seismic conditions than original ones. The Yadana offshore platforms located in a high seismic activity area in the Andaman Sea, operated by TOTAL E&P MYANMAR, were part of this important work. DORIS Engineering and GDS have developed specific seismic analyses to validate the design under new conditions.
This paper will present the different engineering challenges which were faced to revalidate the structural integrity of the different jacket type platforms under new seismic conditions. It will describe the methodology specifically developed for this project and how were identified and defined the necessary site modifications. These analyses were developed to assess more accurately the maximum relative displacements of jacket type platforms connected by bridges and to validate the stresses in foundation piles. It will also address the offshore works performed on the platforms with a maximization of SIMOPS works and limited shut down periods.
Insufficiencies in the conventional design approach required to develop specific methods to validate the integrity of the jacket foundations and the platforms displacement (bridges). This paper will address, in particular, the design methodology used to verify the integrity of the jacket foundations and to define the required topsides and jacket reinforcements. A time domain approach, based on the "ASN" guidance used for nuclear facilities, was developed to verify the pile stresses and assess more accurately the maximum relative displacement of the platforms connected by bridges. The offshore works were afterwards performed in a timely and cost-effective manner. The detail engineering and the operation offshore had to include risky and unconventional operation such as bridges pot bearings replacement or piping modifications on bridges. SIMOPS works were maximized allowing the shutdown to be limited to the shortest duration.
This paper presents the different engineering challenges which were faced to revalidate the design of existing platforms. It presents the specific methods which have been successfully developed by engineering to validate the design. This project is a good example of a "brownfield" project, from a challenging situation through development of a reliable and efficient engineering solution to successful completion of offshore works.