bluuebunny/crossref_metadata_2025_split huggingface dataset:
AI-Optimization of Lithium Recovery from Reservoir Operations - An Adapted Volve Field Study
Authors: Katterbauer Klemens , Al Shehri Abdallah , Al Qasim Abdulaziz , Yousef Ali 
Published: October 2023

Abstract
Lithium has become a valuable resource for a variety of applications, such as for batteries, in the quest for greater sustainability of the utilization of resources. These challenges have led to the demand for enhanced field operations and making the operations more sustainable while maintaining production levels. The 4th Industrial Revolution is having enormous impact on the oil and gas industry, and with the rise of the demand for lithium for battery and energy technologies, hydrocarbon reservoirs have become an attractive source for these valuable resources. Several reservoirs around the world have been demonstrated to contain significant quantities of lithium in their produced brines.
In this work, we present a new AI optimization approach for the optimization of lithium recovery from reservoir operations while maintaining reservoir oil production targets. The approach is novel in the both the AI framework utilized as well as its integration into a global optimization approach based on genetic algorithm to optimize both oil production and lithium recovery. The AI framework incorporates a deep learning LSTM algorithm for estimating oil, brine and lithium recovery based water injection levels. The deep learning model is then incorporated into a global optimization framework to optimize the water injection levels to maximize lithium recovery while maintaining reservoir oil production levels.
We provided a new AI optimization framework for lithium recovery from reservoir brine from an oil and gas reservoir. The framework enables optimization of lithium recovery while maintaining hydrocarbon recovery rates. The framework was successfully demonstrated on the Volve field, outlining the potential significant increase in lithium recovery rates from an optimized injection process. This framework may provide significant opportunities in enhancing reservoir brine utilization, and contributed subsequently to enhancing sustainability in reservoir operations.
Integrity Management Pass Panel Review Form: A Tool for Reviewing Critical Topside Pressure System Anomaly in an Offshore Normally Unmanned Installation During Drilling and Well Intervention Activities
Authors: Harmantoro Akhmad Tutus 
Published: October 2023

Abstract
Normally Unmanned Installation (NUI) is a facility with less severe human consequences because of its minimum manning during normal operations, i.e., 1-3 persons per visit. However, the number of manning increases drastically during well intervention activities. Tens of people dwell in the accommodation building on the liftboat or drilling rig that resides above the NUI platform. This circumstance raises safety issues, especially for the NUI platform with a critical wall thinning in its topside pressure systems since the boat or the rig does not have complete safety protection against the topside hydrocarbon release.
Pertamina Hulu Energi Offshore North-West Java (PHE ONWJ) has an Integrity Management Pass (IMPASS) business process to manage the integrity issue during well interventions in NUI. IMPASS requires collecting the integrity status in the respective NUI, highlighting and reviewing the critical pressure system integrity anomaly, and implementing recommendations established in the review. The liftboat or drilling rig may sail heading to the NUI if the relevant parties approve the IMPASS and implement the recommendations.
Reviewing the pressure system anomaly is the critical step in IMPASS. The reviewers shall ensure the effectiveness of hydrocarbon leak prevention and readiness to mitigate the probable leak occurrence. A custom programmed spreadsheet form, named IMPASS PREVIEW form, supports the review process to maintain consistency of the review results.
IMPASS PREVIEW form summarizes integrity anomaly data, collects operating conditions and existing safety protection system data, and applies process safety and risk-based concept to assess the protection system and establish recommendations. It classifies safety protection into prevention, engineering, and procedural control. Then, it automatically recommends stringent additional measures to the existing safety protection for pressure systems with more severe integrity conditions. It also predicts probable hazardous hydrocarbon events as the basis for the emergency drill plan.
IMPASS PREVIEW has been utilized to support approximately 100 well interventions. It promotes a shared understanding among relevant parties that allows early and consistent data collection. It also applies a consistent approach in every review with relatively shorter review duration. Since the recommendations can be immediately acquired, it allows early remediation action to set facilities ready to receive the liftboat and the rig in safe condition.
Strengthening Learning Culture in WK Rokan Through Digitalized Knowledge Management Supporting Dynamics Challenges of Drilling & Completion Operations
Authors: Hoviari Muhammad Abdunnasir , Dahlil Irwan , Rizki Freddy Frinly , Fikri Bima Surya Khoirul , Misnawati _ , Rahman Aznil Arif , Prawira Muhammad Riza , Lengkong Jane Serafin Theodora 
Published: October 2023

Abstract
Operational Excellence is paramount in oil & gas industries. Various efforts were made to achieve incident free while promoting efficient operation. However, in massive operation activities, the challenges become even greater because of the Short of Service Employee (SSE). The aggressive in increasing number of Rigs creates a high number of newcomers with limited skill, competence, and experience. Nevertheless, dynamics challenge operations are not an excuse to fail. Operation must be run safely for business continuity. Appropriate solutions are figured out to bridge the condition and applying Knowledge Management (KM) is one of them.
Drilling & Completion Rokan believes that learning culture is a strong foundation in achieving the vision and mission of the organization. The learning process has been carried out from the management level to the Business Partner's frontliners under learning group called D&C Learning Club - DCLC. Information and knowledge sharing is always delivered face-to-face or via online meetings. Digital technology such as social media has proven to be practical, easy to do and accelerates the learning process. However, this application has limitations for use in very massive and complex environments. Therefore, D&C Rokan has developed a KM platform that is more robust and provides better value.
The development research begins with the mapping process for the required knowledge. This mapping is scoped on Drilling operation and Engineering support. Then SWOT and TOWS analyzes were carried out to support the decision-making process in selecting applications for the KM platform. Decisively, team decided to choose "SharePoint" application because of its superiority in security, infrastructure availability, memory capacity and ability to provide an environment for community interaction, transforming knowledge based on a knowledge creation model, known as SECI - Socialization, Externalization, Combination, and Internalization.
The KM application, which is called KM&L, consists of 3 main parts: discussion platform, digital library, and learning calendar. The learning community remains a major factor in the success of achieving a learning culture. Activeness in questions and answers, discussion to find solutions, challenging each other and involving Subject Matter Experts (SME) will accelerate the process of creating knowledge, which is documented in a digital library. KM&L is expected to become One Stop Shop Learning. The expectation is not only to accelerate the learning curve for SSE, but also to retain knowledge for communities. These will eventually become one of the competitive advantages for D&C Rokan in achieving operational excellence: incident free operation and world class reliability & efficiency.
Low Cost Alternate Solution to Produce the Shallowest Productive Low-Quality Reservoir in WK Rokan
Authors: Afif Ikhsani Muhammad , Putra Azarico , Rafi Muhammad , Alfajrian _ , Barezzi Muhammad , Jati Nugroho , Sunjaya Rizky 
Published: October 2023

Abstract
Low Quality Reservoir in WK Rokan is quite famous as a large volume of remaining recoverable resource, where TLS Formation owned the biggest share (~51%) of the total Low-Quality Reservoir potential additional reserves. This formation develop widely in Central Sumatra Basin with range ~600 ft TVDSS depth and the deepest productive reservoir in ~4000 ft TVDSS.
The 600ft TVDSS TLS Reservoir is identified as the most challenging Low-Quality Reservoir in term of its subsurface and operation since this formation has been producing for decades. This Reservoir located in BLSO field in Riau Province, Central Sumatra, Indonesia approximately 140 km Northwest of Pekanbaru or 50 km northwest of the DRI field. The field is a large elongated anticlinal structure bounded on the southwest by a major high-angle reverse fault. The shallowest productive TLS in WK Rokan has a minimum recovery factor with a low reservoir quality which has permeability range of 20-300 MD due to the thin overburden barrier (shallow structure), reservoir complexity (low reservoir permeability, low sand connectivity) that led to limitation of completion strategy resulted in low oil recovery. It is found in 1972, and commercially produced as an oil-producing well with a reservoir depth of 800 - 1000 ft TVD with current recovery factor only 8%. The drive mechanism in this reservoir is shown as a weak water drive reservoir.
The old-fashioned development strategy from this shallow low-quality reservoir is by having hydraulic fracturing with cased hole completion which will be driven a high-cost development scenario if we want to increase oil recovery in this reservoir. The alternate solution in developing this shallow reservoir is by optimizing productive section interface, and Open Hole Screen Liner is coming out as solution with lower investment to add more recovery with average production 49 BOPD and low average water cut (51%).
This paper will talk about in how we develop well candidacy to apply open hole screen liner completion method, the result and future development plan to improve oil recovery in shallowest low quality reservoir in WK Rokan.
Unlocking High CO2 Wells - Strategy for Achieving Optimum Gas Blending Ratio
Authors: Mohd Fauzi Nurul Adlina , A. Rahim Nurul Afiqah , Gazali Muhammad Yusri , Giri Emelia , Mohd Nawi Mohd Shakir , Raja Azman Raja M. Rafiyudeen 
Published: October 2023

Abstract
Platform X has four (4) Non-Associated Gas (NAG) wells with total production rate of 75 MMscfd. Due to their high CO2 content ~ 10-13 mol%, NAG production were capped at production operating philosophy of 30 MMscfd. They were produced thru blending them with Associated Gas (AG) wells (ratio 50:50) to meet 8 mol% CO2 limit at pipeline from Platform X to gas processing hub (Platform Y). In a normal production, only two (2) NAG wells flowing, two (2) NAG wells remain idle causing a loss in production opportunity. The study was conducted to further unlock NAG potential by revisiting the blending NAG:AG ratio. Few steps were outlined for the study workflow; surface facilities readiness, data collection on-site CO2 gas sampling and flaring monitoring, data analysis thru Aspen HYSYS model simulation for theoretical and sensitivity data, and risk assessment for revised blending ratio. From the study, Platform X gas production can be optimized up to 55 NAG: 45 AG blending ratio. Actual on-site sampling dictates CO2 mol% at pipeline from Platform X to Platform Y to be around 7.5 mol%. It is comparable to Aspen HYSYS simulation result indicating a good model tuning. Sensitivity analysis generated from the model implies that the higher AG production, the higher NAG production as more gas can be blended with low CO2 content of AG well. Risk assessment stated overall risk-rating is low. Platform X is allowed to flow continuously with the revised blending ratio provided that wells flow rates not exceed the blended CO2 limit. Additional gas yielded is 7 to 8 MMscfd, daily estimated revenue ranges from RM 188,000 to RM 215,000. Flaring is able to sustain ~0.4 MMscfd, below Platform X limit of 1 MMscfd.
Improving Drilling Efficiency Using Intelligent Decision System for Drilling in Bohai Oilfield Based on Big Data
Authors: Xie Tao , Hou Xinxin , Huo Hongbo , Lin Hai , He Ruibing , Xu Dongsheng , Zhang Lei , Liu Hailong , Li Wenlong , Liu Xun 
Published: October 2023

Abstract
Making use of data generated from drilling process are challenging in oil industry, an intelligent decision system for drilling based on big data has been established to improve efficiency and reduce drilling cost of more than 400 wells are being drilled in Bohai oilfield every year. The data acquisition standard of offshore drilling and completion is formed, and the data are transformed and stored in database system. Based on the analysis of regional geological, seismic, logging and drilling data, various risks of the design well are evaluated to achieve the best drilling and completion design scheme. Meanwhile, real time intelligent prediction models with machine learning methods, such as Artificial neural network, Convolutional neural network, K nearest neighbor, etc, are established to predict and avoid pipe stuck, lost circulation, gas kick events. Moreover, a continuous improvement system is established to improve drilling efficiency through drilling parameters optimization. An intelligent decision system for drilling with the core of "pre drilling rehearsal-risk assessment-parameter optimization" has been formed. This technology has been successfully applied in 50 wells, the average well construction time has been reduced by 4.5 days compared with previously drilled wells. Bohai oilfield is accelerating digital transformation pace of drilling and completion, and the filed application show that digitization and big data technology can greatly help increase efficiency and reduce cost, which can also be a reference to other oilfield.
Maximizing the Value of Offshore-Setup Hydraulic Workover Unit to Monetize Onshore Gas in Brunei
Authors: Runtuwene Michael , Lopez Mario , Siew Sherry , Mappy Muhammad 
Published: October 2023

Abstract
Since 2019, a 340K type of Hydraulic Workover Unit (HWU) has been contracted by the Operator for production protection in case of ESP failures, primarily for the offshore assets. Due to the nature of contract and scope, there were times when the HWU was in standby mode while waiting for the next ESP replacement scopes and/or for the offshore vessel to be made available. When there was a requirement to recomplete a land gas well ‘S’ to increase gas lift supplies, an opportunity was seized to utilize the HWU to execute the recompletion scope.
Well S was a 4,300m deep exploration well that was drilled and tested in 2019 with a 2,000HP land drilling rig. The well had two zones of open perforation and it was then suspended with a combination of inflatable cement retainer, cement and sand plugs, and another V0 hydraulic plug above it. The first operational scope was to prepare the wellbore by clearing the access for the perforations, and the second scope would be the recompletion operation.
The opportunity was clear, but the solution wasn’t as straightforward. Originally this recompletion was planned to be executed with a land rig, but scheduling conflicts meant that the land rig arrival was delayed by a few years. The team saw the opportunity to maximize the assets at their disposal but there were two main challenges in realizing this opportunity. First, the offshore setup HWU required significant modifications to operate on land environment. This included adding components in the peripheral e.g. a crane, tanks/temporary pipe works and accommodation cabins. The second challenge was to assess and equip the unit that was supposed to perform non-complex hoisting operation, to be able to execute the recompletion scope which included fishing and milling, wellbore clean-up, TCP operation, and installing completions. The other important element of the HWU utilization is that it has a lower carbon footprint as opposed to drilling rig. In average, the fuel consumption of the HWU is nearly half of 1,500HP drilling rig and even though drilling rig operational efficiency is generally higher, the overall emission of HWU would still be lower in this case.
This paper describes the requirements set at the planning stage, to ensure that the minimum technical requirement was defined and that the project was competitively scoped. It outlines the challenges encountered in the preparation stage as well as in the operation stage, and how they were addressed, resulting in a safe and successful campaign and "out-of-plan" gas to support the production. Furthermore, this paper examines the boundary of the Hydraulic Workover unit and illustrates how thorough planning and risk assessment were critical for the non-routine activities.
Implementing Enhanced Reservoir Management to Arrest Natural Decline and Increase Production at Mature Y Field
Authors: Marawi Faizal Al , Avianto Adhi Mahendra , Tjahjono Hendro , Anggreiny Yayu , Rahman Yudi , Moestopo Hendar Suharnoko , Husna Ully Zakyatul , Hidayat Sachrul Wahyu 
Published: October 2023

Abstract
PT. Pertamina Hulu Rokan (PT. PHR) managed lot of oil field assets that categorized as mature fields. Field "Y" is one of the mature primary fields discovered since 1972 and over time has decline in oil production. To arrest the natural decline and efforts to increase production from existing wells, Asset Optimization Primary (AOP) Team implemented an Enhanced Reservoir Management with Well Intervention (WI) job as the key in the company's portfolio activities.
A robust subsurface WI program is generated massively, vigilantly implemented, and closely tracked. The main job recommendations from Enhanced Reservoir Management are well optimization by revisit reservoirs, perforation, water shut off, and stimulation. On the production strategy to ensure optimum production, it is critical to select single high-rate reservoir, comingle low-rate reservoirs, or single low-rate reservoir. Collaboration from various functions i.e., Asset Optimization, Drilling & Completion, and Operations are an important key in contributes to the success of the well execution program.
The result of WI jobs that executed in late 2022 showed positive results with increasing production with additional cumulative oil ~40MBO with other advantage was reducing fluid production. To sustain production from a mature field is important, continuous base business activities and expected to grow in terms of quantity, complexity, requiring new technologies and ideas, as well as new challenges with the aim to arrest the natural decline oil rate.
This paper discusses an Enhanced Reservoir Management which has been implemented in Field "Y" by integrating subsurface and production analysis to gain a deep understanding of how to get good well candidates. Additional data from new wells also provide new information in addition to surveillance data to support this analysis. Some of new innovations from the subsurface aspect are conducted High Resolution Stratigraphy (HiReS) Analysis and implement the Integration Current Isopach Net Pay Map to identify remaining hydrocarbon (bypassed oil) in each prolific reservoir.
Case Study: Utilization of a Hydraulic Workover Unit to Recover Highly Corroded 35 Years Old Dual String Tubing Completion with Dual Tubing and Dual Annulus Valve in Mahakam Offshore
Authors: Sinaga Rahmat , Solagratia Yosafat , Syafrudin Mochamad , Maharanee Miazzy 
Published: October 2023

Abstract
An operator has been significantly performing re-entry well drilling to increase operational efficiency. Therefore, a temporary abandonment campaign is critical to successfully achieving the objective of providing a well slot for the upcoming drilling program. Abandonment work has high uncertainties that require more time to prepare and to solve the possible situation in the work progress itself. Particularly in the old wells where the tubing completion has been installed for 35 years with limited sources of preliminary information or reference. Hence the operator has been utilizing a hydraulic workover unit (HWU) to perform an abandonment campaign in the offshore field.
This paper presented a case study of multiple wells abandonment of which an HWU is operated. The well was completed with dual string production tubing with dual tubing and dual annulus valves in 1987. Highly corroded tubing and difficulties to recover the existing tubing and annulus valves have been the challenges identified before the campaign began. Moreover, the history record of each well was limited has become additional challenge to start the project.
Evaluating the tubing conditions, and preparing HWU with Blow Out Preventer (BOP) and related equipment such as tubing cutters and fishing tools are essential parts of this campaign. Besides, collaboration work with the drilling team for designing the most accurate cutting depth and developing the abandonment program is crucial to abandon the well safely and efficiently.
Finally, the abandonment campaign was successful with zero incidents allowing the drilling team to conduct the operation in the drilling re-entry wells campaign.