bluuebunny/crossref_metadata_2025_split huggingface dataset:
World's First Fishbone Openhole Gravel Packing Using Shunted Gravel-Pack System: A Case History from Bohai Bay, China
Authors: Wei Min , Cun Xi Hong , Liu Yaolan , Teoh Melissa , Moses Nicholas , Zhao Geng , Liu Xiao Li , Ren Xiaoqiang , Zhang Yong , Hua Jing 
Published: February 2024

Abstract
For the first time in China, shunted gravel-pack screens have been used for two long, fishbone type, multilateral openhole sand control wells in 2022. Shunt-tube systems have been widely used in cased hole and openhole gravel-packing operations in the past few decades as the most reliable sand control solution. However, this is the first shunted gravel-pack screen application in an openhole main bore with fishbones. This successful drilling and completion methodology can be used in this field and other locations to increase the well production rate by enlarging the reservoir contact area with fishbones without adding much capex to drilling and completion operations.
Challenges and solutions for two wells included running the completion tool string to total depth in complicated well configurations, optimized operating procedures, gravel-pack pumping design for complicated scenarios resulting from fishbones, and onsite operations. The work included a detailed analysis of post-job data.
The uncertainties of fluid loss and wellbore stability around the fishbones and the potentially unstable shale streaks in the 600-m-long openhole sections became challenging during gravel packing. Bridging was observed when slurry arrived at the openhole, and shunt tubes were activated much earlier than expected for both wells. Most (85%) of the packing was pumped through shunt tubes for the first well. High wellhead pressure caused by shunt friction was well managed to make sure as much gravel as possible was pumped. For the second well, 67% of the packing was pumped through shunt tubes.
As there were no bottomhole gauges ran on wash pipes, post-job analysis was mainly based on volumetric data to analyze the potential packing sequence for the two wells. Post-job data analysis indicated that early gravel bridging might be attributed to potential hole collapses around the lateral and shale sections. Without the use of alternate shunt-tube screens and proper carrier fluid, the job would likely have resulted in an incomplete packing and failed sand control operation. Packing efficiency was 123% and 146%, respectively for the two wells, and the oil production rate was two times higher than that expected.
Directional Drilling and Logging While Drilling Operation Optimization Methods in a Brownfield-Fast-Drilling Environment
Authors: Andoni B. , Wiharja A. , Yudhatama M. , Pratama A. , Haramain H. , Noviasta B. , Taufik E. , Karnadhi G. , Wijayanto T. , Murti K. W. 
Published: February 2024

Abstract
Delta Mahakam, located in East Kalimantan has been known as one of the old oil and gas fields in Indonesia which has been developed since 1970. With massive production over more than 50 years, the field has entered the brownfield period. The reservoir pockets get more difficult and challenging to reach. The environment is factory-drilling with a fast operation (up to 200 m/h instantaneous on-bottom penetration rate, multiple offline activities, and fast connections practices) and is considered to be reaching the saturation level. The challenge now is to identify the opportunity for marginal but continuous performance improvement to lower the overall drilling operation cost.
Specific to this Delta Mahakam brownfield, there are at least six (6) DD/MWD/LWD-related initiatives that were implemented to optimize the drilling operation: (1) Adaptive and Continuous development of drill bit design; (2) Robust metal-to-metal-based push-the-bit Rotary Steerable System (RSS) utilization to boost up ROP; (3) Downhole steerable motor with high torque performance power section to gain higher horsepower during drilling; (4) High-performance motorized RSS to improve performance in S-type high torque, interbedded high impact formation, and long reach wells; (5) Utilization of LWD tool with single co-located formation evaluation sensors to enhance safety, surface handling efficiency, and geo-stopping; (6) high-resolution real-time data for high-speed drilling and safe BHA pull out of hole (POOH). For the last 5 years, despite the more challenging oil/gas reservoir pockets to be targeted, the directional and logging while drilling performance in Delta Mahakam continuously increased. The drilling statistics show that 19.5% higher on-bottom ROP has been achieved by transitioning the BHA drive system from an elastomer-based to a metal-to-metal-based push-the-bit RSS system. For wells with a steerable motor application (high DLS requirement in wash-out prone zone), the high-torque performance motor helped boost up sliding ROP, improving the total drilling on-bottom ROP by 24%. For the wells with special challenges (S-type high torque, interbedded high impact formation, long reach), the high-performance motorized RSS has proven to achieve 39% higher on-bottom ROP, which potentially saved 175 hours of drilling time from 7 wells drilled compared to the traditional RSS-standalone approach. On the invisible lost time (ILT) reduction side, the utilization of an integrated single-collar LWD tool saved the surface handling time by an average of 34%, and TD determination by 43%. All those performance improvements are achieved without sacrificing the real-time data quality supported by the high-frequency mud telemetry technology which transmits the signal 200% faster than the average technology available in the industry.
Reducing Red Zone Entries and Rig Time with Fewer Slip Changes for Drilling and Casing Operations
Authors: Angelle Jeremy R. , Thibodeaux Robert L. , Smith Logan E. 
Published: February 2024

Abstract
The construction of wells in deepwater environments is accelerating toward a common goal of reducing the personnel required to construct wells and reducing or eliminating entry and working in hazardous zones which commonly existing around well center. Due to its repetitive nature, tubular installations are often viewed as an attractive focus to mechanize or automate. Within these operations an area often overlooked is the rig up, change out, and/or rig down of tubular installation equipment.
Deepwater well construction requires casing strings to be installed in the well by utilizing a drill pipe landing string. While this is common practice, it is a practice that introduces risk as handling tools are required to be changed out during the switch over from casing to drill pipe which requires multiple personnel operating in the red zone. This risk is also present when casing strings of varying diameters are installed which gives the well architecture additional clearance down hole. Additionally, tripping operations also contain multiple components the BHA and varying diameters of drill pipe requiring multiple slip changes.
While tool changeout is common and varies throughout the well construction process, one specific example that is commonly found in deepwater well designs are production tie-backs. They are often tapered with the top section of the casing string being a larger diameter than the bottom section to allow clearance for critical components contained within the completion string such as subsurface safety valves. Currently, to safely execute the installation of a production tie-back string, two slip system changes are needed as operations moved from the bottom section of casing string to the upper section of casing string and then to the drill pipe landing string. In this case, installation requires more equipment present on the rig, increased rig time due to the multiple slip changes, and increased safety risks as additional red zone entries are required to swap out slip systems. Additional examples include drill strings that contain components within the bottom hole assembly (BHA) that vary in diameter. This operation contains the same safety risks and inefficiencies as the previous example.
A novel slip system has been implemented that reduces the number of slip changeouts improving safety on the rig floor and decreasing rig time.
Enhancing Sand Management in Gas Field A: Integration of Acoustic Sand Monitoring with Online Sand Sampling for Improved Sand and Fines Detection
Authors: Simatupang Athur R. , Ambrose Jonathan L. , Ramli Mazlan , Ragunathan Thevaruban , Muslim Abdullah , Harahap Riza A. , Nurrahman Fahmi , Natanagara Bayu B. , Tanjung Erwindo , Satiawarman Anugerah 
Published: February 2024

Abstract
Acoustic Sand Monitoring (ASM) is currently used to detect and monitor the presence of sand particles in flowlines, however its effectiveness in detecting fine sand particles is limited due to the small size, lower impact energy, and tendency of the minute grains to remain suspended and not impacting the inner pipe surfaces. Quite frequently, flowlines produce external noises due to slugging and flowline pressure which can be misinterpreted as sand production on ASM graphs. This paper explores the combination of online sand sampling with acoustic sand monitoring in Field A, Indonesia, to improve sand production detection for sand production in gas wells in order to safeguard asset integrity and enhance production. A comparative analysis of utilizing the combined technology was performed aiming to shed light on the efficacy of combining both sand monitoring techniques. It was concluded that the combined approach of the acoustic sand monitoring with an online sand sampler is crucial for a comprehensive assessment of sand production, particularly in capturing finer sands to allow operators to determine their safe operating envelopes.
Engineered Scrubbing Fiber in Cement Spacer Improves Mud Removal
Authors: Persaud Aniesa , Munoz Moises , Kapoor Saurabh 
Published: February 2024

Abstract
Nonaqueous fluids (NAF) are widely used in offshore Guyana drilling operations. NAF are incompatible with all slurries because they affect properties such as thickening-time and compressive strength, in an unpredictable manner. Spacers are used to clean the mud on the borehole wall by water wetting; thus, reducing the mud on the wall risk by separating the mud from the cement in the casing and annulus to help acquire good cement bonding. Solids in the spacer increases the cleaning efficiency of mud on the wall. An engineered scrubbing fiber, presented in this paper, is added in the cement spacer to enhance its cleaning property by providing a scrubbing effect. This fiber removes the mud from the casing or formation by attracting the nonaqueous compound toward itself by a hydrophobic-hydrophobic interaction. The scrubbing fiber is applicable in all cement spacer applications and can be tailored to the job conditions once within its operating limits of density, temperature, and concentration. The cement spacer, with the engineered scrubbing fibers, is designed by following a sequence of laboratory tests, gathering the well and conventional cement spacer information. Laboratory testing was performed for the implementation of the scrubbing fiber in the cement spacer to confirm its performance with drilling fluid used in the Guyana operations. From comparative laboratory results, the engineered fibers at 1.5 lbm/bbl concentration in the cement spacer did not have any significant effect on cement spacer or cement slurry when compared with a cement spacer containing no fibers. The fibers, together with mutual solvent and surfactants, have been evaluated for mud removal efficiency and showed their ability to increase the cleaning efficiency as much as 93% mud removal. The best method to add the fibers to the cement spacer was also analyzed and was successfully performed during the mixing of the cement spacer on the rig and by being delivered to the well. The major benefits to the client by using engineered scrubbing fibers in the cement spacer are to improve cement bonding once in place (Eulberg and Hudson 2017) and in the case of plug cementing and liner operation, to reduce the risk of set cement in the drillpipe (Edwards et al. 2013) during pulling out of hole operations. The improved mud removal achieved by using engineered scrubbing fiber in the spacer has proven successful through laboratory tests, including cleaning efficiency. Field application of the fibers in the spacer increases the chances for successful zonal isolation and meeting a client's objectives.
Challenges and Opportunity in Delivering Low-Cost Solution to Re-Purpose Existing Pipeline into CO2 Service for CCUS Project
Authors: Karim K. A , Hussien H. , Koi S. W , Yusof N. A , Bahar F. W Ahmad , Talik H. Abedul 
Published: February 2024

Abstract
Re-qualification, conversion, and utilization of old existing pipeline to become CO2 pipeline based on DNV-RP-F104 become one of attractive opportunity to reduce overall CCUS CAPEX compared to laying a new CO2 pipeline. However, it comes with various technical challenges includes flow assurance, integrity status of the existing pipeline i.e. current condition of the pipeline, including limitation of existing pipeline material strength and corrosion due to overdue usage. Pipeline materials are expected to be able to resist rapid de-compression force thus preventing running ductile fracture (RDF) to happen. To also note that existing pipeline are generally corroded based on latest available in-line inspection outcome.
A comprehensive technical assessment followed by commercial assessment shall be performed in determining technical suitability of existing pipeline that to be converted into CO2 services. As a start, a study on pipeline fit-for-service (FFS) shall be performed to determine the remaining life of pipeline based on remaining wall thickness. A numerous iteration using Enhanced Battelle Two-Curve Method (e-BTCM) shall be performed for the entire length of pipeline which may comprised of various pipeline wall thickness and design specification. On top of that, process flow assurance simulation study shall be conducted in determining design and operating envelopes of the new CO2 flow regime for optimum and safe transportation of CO2 from gathering system to offshore injection reservoir. Additionally, corrosion assessment shall be performed to calculate the corrosion rate based on fluid composition and impurities thus predict remaining life of pipeline with CO2 services.
A study of 155km total length of existing pipeline is having some limitations for the conversion of the whole pipeline system to flow with CO2. One of the limitations is the first 10km of pipeline is not meeting RDF requirements. The attractive solution of the conversion whereby most of the pipeline length still can be used, while first 10km length will undergo pipeline rehabilitation such as pipeline clamping, pipeline sleeving or sectional replacement. It is observed that pipeline rehabilitation solutions play a major part in reducing total CAPEX for CO2 pipeline re-purpose. This paper will further define the challenges and resolution in delivering a low-cost solution for pipeline re-purpose in comparison to laying a ‘new’ pipeline.
Detailed assessment using e-BTCM in determining the required toughness of line pipe materials as well as optimum departing temperature has resulted in low-cost solution for CO2 pipeline re-purpose CCUS project.
A Novel Hybrid CO2 Capture System from the Atmosphere (DAC)
Authors: Wood C. , Aryana A. 
Published: February 2024

Abstract
The global energy transition has intensified the search for effective carbon capture and storage (CCS) methods, emphasizing the urgent need to combat climate change. Among these methods, direct air capture (DAC) has emerged as a crucial area of research due to its potential for removing carbon dioxide (CO2) from the atmosphere. However, existing DAC processes face challenges such as high energy consumption and cost, primarily stemming from the low concentration of CO2 in ambient air. This presentation introduces, an innovative capture technology designed to overcome these challenges. At its core, the terchnology incorporates a novel hybrid sorbent that combines the strengths of both liquids and solids (called liquid amine particles, LAPs), resulting in superior performance compared to traditional carbon capture technologies. This presentation provides an overview of the development and current status of this technology, highlighting its potential to achieve the lowest levelized cost of capture.
Integrated Modelling Solutions for Flow Assurance and Process Dynamics Using Physics and Data
Authors: Easwar R. , Kowta R. , Wadia N. , Thornett S. 
Published: February 2024

Abstract
Flow Assurance and Process solutions are the key drivers for design and efficient operation in terms of maintaining system integrity and profitability. Subsea and Export systems rely on modelling multiphase thermodynamic calculations for design and real-time monitoring systems. Topsides and Onshore systems require modelling of unit operations, control schemes and equipment specific operating envelopes. Due to these vastly different requirements, the oil and gas (O&G) industry relies on different software/ tools to understand flow assurance vs process conditions. Achieving a solution that provides a holistic perspective helps in preventing individual system contractor oversight, in understanding how individual system designs operate and fit together, in supporting integrated procedures development/verification, and can act as an operator training simulator (OTS) system.
A fully integrated process digital twin with both physics based and digital capabilities is required to achieve the above objective. The Integrated Dynamic Model (IDM) uses physics based hydraulic and thermophysical calculations in the design phase to inform integrated system responses that drive design decisions. In the operate phase, the IDM uses the field sensor data in real-time to monitor the field, trigger alarms/alerts for specific events, identify process anomalies like leaks and restrictions, assess hydrate formation potential and provide predictive functionalities to determine system states based on an operator action.
Transient events can trigger responses across system interfaces and may lead to hydrocarbon release into the atmosphere, production losses and system integrity/safety issues. The IDM helps in complete process digitalization, field operation verification, process optimisation, decarbonization and improving system integrity. With the utilization of the historical field data, the IDMs are further able to learn and understand field-specific nuances that further supports operator readiness.
The IDM is novel to the industry due to its capability to use production analysis data, equipment operating envelopes, control logic sequences and field data in real-time to provide informed decisions for integrated system design and operations. This paper will touch upon the integrated modelling and digital capabilities of the IDM through the lens of a couple of case studies – one in the design and one in the operate phase.
Revolutionising Cement Evaluation in Mexico's Exploration Wells: Unleashing the Power of Extreme Ultrasonic Technology
Authors: Moncayo S. , Juaristi J. M. , Vilchez O. 
Published: February 2024

The evaluation of well cementing has historically been a point of great importance during well construction. The evaluation of cementing has evolved over the last decades into an increasingly demanding technique, driven by both stricter regulatory requirements and more complex well construction designs.
Over the years, regulatory and normative requirements have evolved to ensure safety and environmental protection up to the surface. Isolation must be demonstrated after well construction, as well as at the end of the well's life before it is plugged and abandoned.
Cement bond log (CBL) and variable density log (VDL) were introduced in the 1960's. These tools provide qualitative insights into the cement's bond with the formation (VDL). This is achieved through the propagation of acoustic energy, leveraging the variance in acoustic impedance between the pipe and the material behind it—whether it be solid, liquid, or gas.
Added Values From CFD on Equipment Troubleshooting Diagnosis
Authors: Maktar M. Fariz , Chauvet Christian J. 
Published: February 2024

Abstract
Computational Fluid Dynamics (CFD) is branch of fluid mechanics that uses numerical analysis to simulate and solve fluid flow within products or systems operating under real-world conditions. It is a powerful tool that has numerous benefits in the oil and gas industry. Very often, CFD simulations are performed at design phase to ensure that equipment designed will achieve the desired performance. Similarly, CFD simulations can also be used to analyse existing equipment to ensure that it can adapt to new operating constraints and objectives. This paper focuses on the added values brought by CFD in diagnosing issues faced by a heat exchanger due to a change in its operating condition. A heat exchanger was reported to have perforated tubes, and a lab report showed that it was due to naphthenic acid corrosion (NAC) attack. Plant operators tried to resolve this by injecting a corrosion inhibitor (CI); however, the tube perforation still occurred. A CFD study was performed to understand and investigate the reason why tube perforation persisted even after CI introduction. The inlet and outlet areas of the heat exchanger were checked, as these areas corresponded to the tube perforation locations. CFD results showed presence of dead zones within the heat exchanger. A direct correlation was established between perforated tube locations and the dead zone locations where high acid Heavy Vacuum Gas Oil ( HVGO) had accumulated over time. Infinite contact time between the high acid HVGO and tube walls at these dead zones had subsequently rendered the CI ineffective. This led to direct NAC attack on the tube walls. Based on these findings, a countermeasure has been proposed and validated through CFD. The results show that dead zones are no longer present within the heat exchanger. Positive feedback from plant operators has been received, as no similar issue had been raised after three years since implementation. In second case study, the flow behavior within fire water system was replicated by means of CFD. Results show presence of deep vacuum within the overboard piping line during the operation of Pressure Control Valve (PCV). This led to huge force spike and pipe surge at the top pipe segment. Installation of vacuum breaker was recommended. Without being able to visualize the internal flow in the heat exchanger via CFD, it might have been difficult to anticipate the root cause behind this tube perforation. "X-ray vision" provided by CFD, gave engineers a better understanding of what had occurred, hence enabling us to pinpoint the exact root cause of the issue. This approach of troubleshooting and diagnosing equipment via CFD had not only provided significant cost cuts by minimizing physical assessments but had also delivered prompt responses and quick solutions to plant operators, ensuring fast turnaround.