bluuebunny/crossref_metadata_2025_split huggingface dataset:
Automation in Cuttings Analysis: Futuristic Preview of Digital Enablement for Geology 101
Authors: Shrivastava Chandramani , Bondabou Karim , Ammar Mahdi , Santo Simone Di , Yamada Tetsushi , Androvandi Sophie 
Published: March 2022

Abstract
Analysis of drill-cuttings collected on the rig has always been the most basic, yet most direct means of understanding the subsurface within its own limitations. However, automation enabled by digital transformation of this aspect of mud logging has greatly increased the importance of this data. A futuristic preview is being presented for the repositioning and value showcasing of most basic and widely available data, i.e., cuttings with digital enablement.
Cost-efficient characterization with lean sample preparation, reducing the adverse environmental imprint to near real-time formation evaluation leading to enhanced well placement and completion design is reshaping the old-school mudlogging with direct detection and quantification of minerals, total organic carbon (TOC), kerogen content and elemental composition; often minimizing the requirement for time-and-cost intensive wireline logging. Labor-intensive sample collection is getting automated, and subjective and descriptive interpretation per experience of mud-logger is giving way to digital, objective interpretation, ready to be integrated with logging-while-drilling data in real-time.
In addition to the X-Ray Fluorescence & Diffraction; newer technologies like Diffused Reflectance Infrared Fourier Transform Spectroscopy (DRIFTS) are being incorporated in wellsite set-up with reduced footprint on rig and minimized usage of chemicals. Unique automated process can analyze high resolution digital images to deliver plethora of information in minimum time; often augmented with the help of artificial intelligence. A futuristic view with building blocks of the automated interpretation process is presented.
Examples from different steps needed to achieve automation are provided, from sample preparation to digital analysis through machine learning for a holistic futuristic vision to highlight digital enablement in delivering the well-objectives in cost-efficient and timely manner honoring the changing market dynamics. This foundational cutting analysis (Geology 101) vision would drive further adavnces in this field.
A Risk Based Approach for the Integrity Management of Single Point Mooring Systems
Authors: Isnadi Biramarta , Mahasan Suhaimi , Omar Syahnaz , Fazli W Hariz , Sahari Yusuf , Suhendra Ave , Wong Ellis , Kamaruzaman Aiman , Khan Riaz 
Published: March 2022

Abstract
This paper describes the SPM Integrity Management approach using risk based strategies for Single Point Mooring (SPM) throughout its asset life cycle, to ensure that there is a structural integrity management processes are implemented and SPM asset fitness for purpose is always maintained. SPM is one of the most important assets for any oil and gas upstream business, as its primary function is for product export and offloading operations. PETRONAS UPSTREAM currently operate seven (7) Single Point Mooring (SPM) assets for its Malaysia Upstream/ Downstream. To manage the integrity of the SPMs, an Integrity Management system has been developed and includes newer assets and those that are approaching or exceeding design lives.
To optimize and focus limited resources toward critical activities, a SPM risk-based strategy and methodology for the SPM assets has been developed. The risk based inspection approach is aligned with the Structural Integrity Management (SIM) processes of DATA, EVALUATION, STRATEGY PROGRAM of the API RP2SIM code of practice. A qualitative risk based integrity management has been developed and for its implementation, inspection and maintenance activities shall target high expenditure items. SPM design, characteristic, assessment, and inspection data have been compiled and utilized in the risk based approach development.
With this risk-based approach, PETRONAS can optimize and significantly reduce its inspection and maintenance activities whilst keeping operational risk levels within acceptable limits. The risk-based approach provides that added advantage to look at inspections and maintenance activities critically and make informed decisions on resourcing and aligning inspection & maintenance campaigns for the future.
Inspection and maintenance measures also include an anomaly management, RBI, data management and inspections scopes of work which are being digitized and maintained within the Company's Structural Integrity Compliance System (SICS).
Direct Hydraulic Control Systems as a Key Enabler for Developing Shallow Water Marginal Fields
Authors: Hammond Steven , Zahari Iman , Berwanto Awaluddin 
Published: March 2022

Abstract

Objectives/Scope
In the current situation of the industry, high numbers of prospects are being considered as not economical to develop due to various factors including low reserves, high complexity and stranded locations with no suitable host facility to tie-in to nearby.
This paper will discuss how the utilization of direct-hydraulic subsea control technology, when coupled with shallow water tree technology, can be deployed to enable technically and commercially viable solutions for marginal shallow water fields.

Methods, Procedures, Process
Under these circumstances, direct hydraulic technology has a number of advantages over traditional EH-MUX control systems, such that direct hydraulics can enable the development of fields which would otherwise be uneconomical.
These advantages include –

Results, Observations, Conclusions
By using Direct Hydraulic technology, the project was able to achieve a commercially attractive and technically fit-for-purpose design, leading to successful project sanction (the first such project in Malaysian waters), and opening the door for similar future developments to follow.

Novel/Additive Information
This paper will present information and methods that will be of benefit to other Operators in the subsea industry who are seeking to unlock reserves that are currently in marginal fields and would be uneconomical to develop using other methods. The benefits that can be gained are both in terms of proof of concept using off-the-shelf designs, and opening up otherwise uneconomical fields for development. In this particular case, the project opens up a further 6 new fields which were previously considered uneconomic to develop.
Flow Assurance Testing with Re-Livened Oil: A Cost-Effective Analogue for Live Oil
Authors: Farrell Andrew Robert , Ewing Andrew , Frigo Dario Marcello , Graham Gordon Michael 
Published: March 2022

Abstract
It is widely accepted that live crude oil samples provide the most field representative fluids when investigating asphaltenes and paraffin wax problems in laboratory testing. However, this approach is limited by availability of live samples and the potential that samples collected during drilling will be insufficiently representative due to contamination. This paper demonstrates that re-livened oil comprising dead oil and just 1 or 2 solvents can be an acceptable replacement where live oil of sufficient quality is not available.
We outline a best-of-both approach: using readily available dead oil but replacing the volatile ends with components that reproduce much of the solvating and phase behaviour of live oil, and where they differ from it, they do so in a predictable manner, which can be readily modelled using an equation of state (EoS) simulator. This avoids the expense and time required to restore the oil to a precise replica of live fluid while still generating laboratory data to increase confidence in predictions for the actual live oil composition generated by the EoS software.
Illustrative examples are given to demonstrate different ways in which re-livened oil can be designed to mimic key features of live oil behaviour, and any differences can be modelled. Wax appearance measurements were made for re-livened oil and used to calibrate an EoS model. When used to simulate data for a live oil, the calibrated model gave excellent agreement with field data. Subsequently, deposition tests were carried out with re-livened oil and used to qualify a wax inhibitor for subsea application. Measurement of the Asphaltenes Onset Pressure (AOP) for re-livened oil was used to tune the EoS model for the analogous live oil, yielding predictions of the asphaltenes precipitation envelope (APE) that were consistent with those obtained using the live oil. This illustrates that live oil may not always be necessary to obtain a reliable APE, especially when the only live oil samples are of questionable quality. Solubility theory was applied to the selection of conditions for asphaltenes flow-loop deposition, wherein a precipitant is added to dead oil to induce deposition. This approach can determine both the identity and correct proportion of a suitable precipitant to simulate conditions close to the bubble point where deposition commonly occurs.
Our work shows how experimental results (both laboratory and field) were used to validate the methodology presented here. The findings of our work will lead to significant cost-savings in performing both flow assurance risk assessments and inhibitor qualification. Rather than going to the significant expense and operational difficulty and risk of collecting and transporting live samples, such screenings can be performed on re-livened fluids that are both field representative and cost-effective.
Integrated Online Emulsion Management System
Authors: Hon Vai Yee , Halim Nor Hadhirah Bt , Panuganti Sai Ravindra , Chai Ivy Ching Hsia , Saaid Ismail B M 
Published: March 2022

AbstractA full suite of integrated online emulsion management system (IOEMS) transforming the handling of decades old crude oil emulsion production issue at field from reactively onsite to proactively online. This technology is made possible with insights on emulsion formation from physics-based molecular models, access of huge database on crude oil properties, emulsion toughness and demulsifier chemistries, coupling with statistical and supervised machine learning application.Intriguingly, this innovation journey began with designing an enhanced oil recovery (EOR) technology in mind. Study on generating stable emulsion for oil recovery was the aim of our pioneering research initially. We successfully developed physics-based models to assess emulsion stability at molecular level. We then applied these models retrospectively for produced emulsion management, with advancement in data science and computational power. The technology concept is to design and plan demulsification strategy based on predicted emulsion stability. The robustness of IOEMS lies in the combination of the goods of accurate interpolated data based on machine learning, with that of extrapolated data from physics-based model. Firstly, mathematical models of relationships between crude properties and emulsion stability index (ESI) were established using statistical method. This led to a good 90% match with laboratory ESI data. Secondly, a demulsifier selection functionality was developed based on machine learning, covering dozens type of demulsifier. We used operating conditions, fluid and demulsifier properties as training data input, with the corresponding lab bottle tests outcomes as training data output to build a classification model via supervised learning algorithms. Its predictive accuracy is at 87%.By bringing the produced emulsion assessment from on-site to online, offshore emulsion sampling and the associated lab bottle tests are minimized. Health safety and environment (HSE) risks are reduced accordingly with the decrease of human intervention in field sampling. The emulsion stability predictive functionality enables operation to prepare early in anticipation of sudden spike of emulsion production and thus, avoiding unplanned well shut in. Furthermore, this function is especially useful when emulsion samples or historical data are not available during field development stage. Meanwhile, the recommended demulsifers from IOEMS are at 17% lower cost than the incumbent demulsifiers used at fields in Malayia, in addition to 90% manhour reduction from conventional trial and error demulsifier screening in lab.Ultimately, the IOEMS has successfully enabled step-change in oilfield emulsion management via an efficient and reliable scientific based digital platform.
Increasing the Safety and Efficiency of Completions with the Utilization of Remote Manipulation Systems and Elimination of Hanging Sheaves
Authors: Alleman Neil 
Published: March 2022

Abstract
The process of running completions typically involves an increased complexity of systems and setups. The running of control lines and umbilicals have historically used hanging sheaves to route the lines from the spoolers to well center and require increased number of personnel in the red zone during operations. These complexities introduce many risks and potential incidents that operators aim to eliminate.
Typical procedures for running completions require man-riding operations to hang sheaves in the derrick. Once the control lines or umbilicals are routed through these sheaves, they become overhead loaded objects and subsequently increase the risk of incident to personnel working on the rig floor. Other operational steps include the manual manipulation of lines to clamp the lines/umbilical to the tubular. This traditional clamping procedure not only requires an increased number of personnel in the red zone, but it also introduces inefficiencies to the operation. Through planning and the use of specialized remote manipulation technologies, operators can remove the need for overhead control line/umbilical sheaves and the manual handling of lines in the red zone.
Although risks do not always result in incidents, organizations still strive to eliminate risks throughout their operations. By using remote manipulation technologies that eliminate control line/umbilical hanging sheaves, the operators benefit from the following:
– Eliminating working at height for sheave installation – Eliminating overhead loaded components and increasing safety of personnel working on the rig floor – Decreasing the number of personnel required in the red zone and reducing manual handling – Increasing the efficiency of the operation
By using systems like these, operators have been able to increase average running speeds, improving from 8.8 to 5.9 minutes per joint, as well as eliminate potentially fatal incidents that have occurred during the completions running process.
Management of Mercury Offshore for Onshore Production Facilities
Authors: Saaibon Mohamed Sopiee , Kayat Zainab , A Karim Fatimah 
Published: March 2022

Abstract
The objective of this paper is to provide an approach in mitigating the adverse effects of mercury found in production fields which include the evaluation on the requirement for mercury treatment facility and suitable technology and best location for the production fields and onshore LNG facilities. The evaluation included assessment of pipeline integrity and managing unexpected increase in mercury content to ensure Mercury Removal Unit (MRU) is capable to treat the gas within the design specification
The method includes mercury mapping and analysis of the results. Evaluation of technology and type at various streams in gas, condensate and water streams. There is no method to predict mercury production forecast and sizing cannot be based on one exploration well data only. Subsurface data might not be representative due to improper procedure, sampling, preservation and timing. Rigorous technology evaluation was evaluated for various mercury species covering its vulnerability to operations abnormalities such as entrainment of moisture, spikes of mercury content, changes to feed gas, hydrogen sulfide content, historical experience of mercury contamination and its impact to operations and performance of cryogenic systems and chemical injection for pipelines. Review of effectiveness of mercury removal technology for gas stream cover metal sulfide based adsorbent and metal oxide based with H2S in-situ sulfiding. In view that there is no proven technology for condensates stream, particulates mercury removal using filtration and hydrocyclones of the multiphase condensate /water and water streams were considered
Mercury has exceeded downstream design specification and pose threats to existing LNG facilities aluminum cryogenic heat exchanger. Speciation, particle size distribution and the use of a practical size test rig on site, adsorbent -condensate compatibility test are approaches to determine the capacity of the MRU. Based on the selected technology, concepts were derived for gas and condensate to ascertain the feasibility of mercury removal, particulate filtration, mercury impact to pipeline integrity and the basis for the onshore mercury removal facility. This yielded seven (7) different concepts or options addressing both MRU gas and condensate either at offshore platform or onshore facilities. The concept select ascertained the optimum requirement to install the mercury removal unit onshore upstream of an Acid Gas Removal Unit in the LNG facilities. A two-stage filtration to remove mercury particulates above 1 micron was selected for offshore facility.
Understanding the behaviour of mercury and the distribution tendencies into the various streams and factors that influence this distribution would provide insight on the integrity of production and pipeline system and management of mercury for operations.
Well Control Optimization of Offshore Horizontal Steam Flooding Wells Using Artificial Intelligence Algorithm
Authors: Han Xiaodong , Zhong Liguo , Wang Qiuxia , Zhang Wei , Zou Jian , Liu Hao , Wang Hongyu 
Published: March 2022

Abstract
Maximizing the future economic return of the asset is an important issue in petroleum engineering. For heavy oil reservoir developed with steam flooding, its production cost is much higher than that of conventional production methods. Commonly used parameters optimization method such as single factor analysis and orthogonal test cannot guarantee to obtain global optimal economic benefits. It is necessary and urgent to form a better optimization method to achieve higher profit.
A new framework is proposed and presented to optimize well control parameters of both steam injection wells and oil production wells by integrating the reservoir simulator into the optimization algorithms. A net present value (NPV) formula for evaluation of horizontal well steam flooding project is proposed and the optimization objective is to maximize the NPV of production over the life. The generally acknowledged Particle swarm optimization (PSO) is used for solution of the optimization problem. This method has been tested for a typical offshore horizontal well steam flooding project. Results indicate that PSO gives good solutions for this problem and the following conclusions can be obtained. The NPV of the optimized project is improved and larger than the NPV of its initial guess. The control frequency has great influence on the optimal NPV, and the optimal NPV increases with the increase of the control frequency. Steam injection and oil production rates need to be controlled and decreased at the latter stage for mitigating ineffective steam cycle between injection and production wells.
The new method has been used for well control optimization of the first offshore horizontal well steam flooding pilot and this method would which will provide powerful technical support for the high efficiency development of the heavy oil resource with steam flooding.
A Novel Apparent Permeability Model in Shale Gas Reservoirs
Authors: He Lang , Yang Bin , Liu Jing , Na Xinyue , Ge Yang 
Published: March 2022

Abstract
A novel apparent permeability model of shale gas is derived considering the stress dependence, the thickness of adsorbed layer, slip flow, Knudsen diffusion and surface diffusion. The thickness of the adsorbed layer is derived according to the porosity occupied by the adsorbed phase in the capillary model. Consequently, the impact of the adsorbed layer and its change with the pressure on apparent permeability can be clearly revealed in the novel model in ultramicropores, or micropores, or mesopores, or macropores. With the stress dependence and the thickness of adsorbed layer considered simultaneously, the effective hole radius is substantiated to be smaller than the original hole radius to a certain degree. On account of this, the ratio of apparent permeability to the intrinsic permeability computed by the novel model is a lot distinct from the existing models. As the pressure increases, the ratio in the novel model declines from above 1 to below 1, followed by a slight upward trend. However, the ratio in other models drops all the way and yet remains above 1 as the pressure rises. Finally, the impact factors of permeability, including stress dependence coefficient, hole radius, reservoir pressure, Langmuir volume and Langmuir pressure, are analyzed. The contribution of slip flow, Knudsen diffusion and surface diffusion to apparent permeability is also illustrated.
Mechanical Isolation of a Challenging Reservoir: First Installation of High Expansion Straddle Packer in Indonesia
Authors: Hidayat Reyhan , Kurniawati Pratika Siamsyah , Kurniawan Aries Taufiq , Setyaji Irwan , Pancawisna Gerardus Putra , Marindha Rantoe , Umar Khalid , Dahnil Gitani Tsalitsah , Rahman Risal , Jamal Muhammad Nadrul , Safitri Yufa , Azhar Raden-Muhamad Prayuda , Lodiman William , Syarif Hibroni 
Published: March 2022

Abstract
Well N-1 in Mahakam Sisi Nubi field, East Kalimantan, had a problem with water and condensate production up to 11,000 BLPD which instantly rendered the production facility overwhelmed despite the high 34 MMSCD gas rate. To solve this, reservoir production profiling using production logging tool was first carried out. Selection of existing zone isolation method was then compared, yet none satisfies the challenges in this well due to restriction and cost issues. A relatively new technology, High Expansion (HEX) Straddle Packer, was introduced as another alternative. A series of engineering design and followed by operation design was then carried out to solve the well problem safely.
A dummy tool run with 2.875" OD and 30ft of length passed through the restriction safely. Caliper logging observes reduction in tubing ID from 3.9" to 3.0". Temperature of the borehole reached 115 deg C at 3417 mBRT of this well. The two water producing zones were next to each other with a total top reservoir to bottom reservoir length of 11 m. With these values, a custom 2.7" straddle packer was built and tested to required temperature and passed. Production simulation with 0.7" ID, indicated the well could still flow over its critical flow regime. After installation, the well flows with 11 MMSCFD of gas with ~1800 BLPD liquid produced, a 83% reduction over previous liquid flowrate. Despite the well flows only 30% from initial gas rate, this well can now flow at an acceptable liquid rate.
The successful installation of the first HEX Straddle expands the portfolio of mechanical water shut off methods in Mahakam and in Indonesia as this was the first HEX Straddle installed in Indonesia. Further study and replications are needed, yet this method can be a viable alternative if other has failed for wells with similar problems.