bluuebunny/crossref_metadata_2025_split huggingface dataset:
Resolving Productivity Mismatched with an Integrated NMR Pore to Production Solution
Authors: Jee Jassica , Azmi Adif Azral , Daud Muhamad Saiful Hakimi , Wong Kent Fui , Lee Samie Sok Foon , Ramdzani Rena Alia , Kalidas Sanggeetha 
Published: October 2023

Abstract
Accurate estimation of reservoir properties such as shale volume, porosity, water saturation, and permeability is vital for reserve estimation and producibility. However, reliance on model-based computations alone can introduce uncertainties if the measured data or core results are biased. This paper addresses the case of Field A in Sabah, Malaysia, where the actual production rate falls significantly below the expectations of the model-based analysis. The observed permeability derived from production modeling based on well-test analysis is considerably lower when compared to log-derived and core-measured permeability profiles. To mitigate these uncertainties and enhance production well modeling, we present a workflow that optimizes the utilization of nuclear magnetic resonance (NMR) from pore to production analysis. The workflow involves deriving a pseudo capillary pressure to determine relative permeability, which serves as an input to reduce production well modeling uncertainty. We discuss four key workflows in this paper.
The first workflow focuses on removing the hydrocarbon effect on NMR T2 distribution to reveal the actual rock properties. Subsequently, NMR Factor Analysis, an unsupervised machine learning technique, is applied to the water-saturated T2 distribution to identify clusters representing unique pore body profiles for each cluster. The following workflow utilizes an automated calibration process that incorporates core-MICP data and machine learning-derived clusters as inputs to generate a continuous capillary pressure-saturation height relationship from NMR and pore throat size distribution index for relative permeability calculations. This workflow provides Production Engineers with an alternative to use NMR-derived relative permeability as an input to calculate the KH window (effective permeability multiplied by thickness) and develop a well-calibrated model for zones without pressure build-up tests. The implementation of this workflow enhances the credibility of the model and reduces uncertainty for production optimization.
Major Greehouse Gas Reduction from Flare Verification
Authors: Mohamad Nor Azli Mohamad Farizal Bin , Seah Shi Ming 
Published: October 2023

Abstract
Membranes are utilized in Acid Gas Removal System (AGRS) at offshore platform to remove carbon dioxide (CO2) from sour gas reservoirs. CO2 selectively permeates the membrane compared to methane and the CO2 rich stream is sent to flare system as permeate flare. This permeate flare is measured by an Ultrasonic Flowmeter (USM) installed as permeate flare meter in 2020. When verification exercises was done, it was first observed that there was a huge discrepancy in mass balance values with the mass output being significantly higher than mass input by 10 to 20%.
Upon verification of the inputs from permeate flare meter to Distributed Control System (DCS), it was initially hypothesized that standard density input assumptions of 0.714kg/Sm3 is unrepresentative of the density values of the supposedly CO2 rich permeate flare. This has caused a large overestimation of permeate flare values.
Operations crew at offshore platform utilized CO2 sampling tubes as a solution for quick sampling of permeate flare and sampling results yielded CO2 compositions of 40 mol% which was the maximum limit of the tubes. Using a conservative approach of assuming the remaining composition of permeate flare to be methane, the permeate flare standard density was then estimated to be at 1.156kg/Sm3. Applying these setting to the input at DCS then yielded an initial 39% decrease to permeate flare values. Meanwhile, third party analysis of permeate flare compositions are conducted on a later date with density values from permeate flare compositional analysis and differing.
The team studied further into the capabilities of the permeate flare meter on live density calculation and proceed to set up trending for calculated density from the meter. The density values calculated by the permeate flare meter were comparable to sampling results. Furthermore, the mass balance between input and output has significantly been improved to be within 3% to 5% of each other. As a result, the team has successfully achieved reduction in reported permeate figure by 4.81 mmscf/d annualized or 97034.26 tCO2e.
Understanding Cement Gaps: A Blueprint for Microannulus Identification
Authors: Singh Kamaljeet , Kumar Apoorva , Dutta Shaktim , Sinha Sahil 
Published: October 2023

Abstract
In many cases, we observe that log responses from ultrasonic, flexural, and sonic logs do not meet the expectations of the executed cementing job without showing major issues. Also, often the logs do not even see the cement behind the casing. These scenarios are most often caused by either a wet microannulus or a dry microannulus. Often the effect of a microannulus is not recognized, and this may lead to the incorrect assessment of cement condition. If this issue is not resolved, it can lead to costly and unsuccessful attempts at intervention.
Successful detection of microannulus was done using the combination of flexural attenuation, ultrasonic pulse-echo technology, third interface echo (TIE) and cement bond log-variable density log (CBL-VDL) measurements. If a dry microannulus is present, ultrasonic acoustic impedance (AI) is more affected than the sonic log and responds earlier to the dry microannulus. If a wet microannulus is present, the sonic log is more affected than ultrasonic AI and responds earlier to a wet microannulus.
In this study, we encountered several wells with varying sizes of dry and wet microannulus. In some wells, a large size dry microannulus was observed and the affected ultrasonic data were mainly showing gas as if no cementing had been conducted. Some wells had a small dry microannulus and the affected ultrasonic measurements showed the annulus to be filled with liquid and cement. Apart from this we also observed several wells with varying sizes of wet microannulus affecting the ultrasonic and sonic measurements by varying degrees and ultimately affecting the cement interpretation.
This work presents the culmination of technological excellence and technical expertise that helped clients to understand the condition of their cement better.
Acidizing Job Optimization in DSF Field New Steamflood Area
Authors: Aji Muhamad , Nugraha Baruna Satria , Irawan Indra 
Published: October 2023

Abstract
Once producer wells experience the impact of steamflooding, they exhibit an increase in temperature, which stabilizes at a certain level, accompanied by a rising trend in fluid and oil production. Subsequently, the wells enter a plateau phase that can last for several years. However, certain hot wells have shown a shorter plateau period and encountered a rapid decline in production, possibly indicating formation damage. This paper provides an explanation of the evaluation process for scale problems and proposes an acidizing solution to mitigate the issue.
The team performed a comprehensive water analysis, evaluating various parameters and comparing the data with those from other areas in the DSF field. The findings revealed that the hot wells in DSF Area-X exhibited a higher scale index, indicating a propensity for calcium carbonate scale precipitation. Considering evaluations from production decline analysis, well maturity, and pump performance, the team proposed an acidizing job utilizing simple acid (HCL) with both bullhead and coiled tubing techniques. The optimization process encompasses opportunity identification, program generation, execution management, and post-job reviews. To expedite and enhance the process, the team leverages digital technology.
The initial results of the acidizing job were highly promising, as the productivity of the wells showed significant recovery, confirming the successful removal of scale from the wellbore. Both the bullhead and coiled tubing unit (CTU) techniques demonstrated similar effectiveness in scale removal. However, the bullhead technique proved more economically advantageous due to its lower cost and faster cycle time. The number of hot wells encountering scale issues continued to rise aligned with the progress of the steamflood process, resulting in an increase in the volume of acidizing jobs. Over the past three years, the team has executed approximately 200 acidizing jobs per year, which have successfully contributed to the recovery of around 1600 barrels of oil per day (BOPD) on an annualized basis. This significant recovery has played a crucial role in improving the base production decline from 45% to 12%.
This paper addresses the prevailing paradigm that scale formation does not occur in new wells. It provides evidence that scale deposition in steamflood fields is accelerated because of temperature rises. This valuable information holds significant benefits for future steamflood projects, particularly within the DSF oil field.
Competency Rulers on Social Performance in Human Rights Management
Authors: Foo Siang Choon , Raja Musa Raja Tatina 
Published: October 2023

Abstract
Company must aspire for its business presence to positively and have strong management of Social Performance where impacts arising from areas of its operation are managed whilst contributing to the society in a responsible manner. The paper aims to demonstrate the need of competency in a Social Performance skill-group in supporting companies in its Human Rights management. Generally, human rights issues that can arise include nuisance to communities, violation of communities’ rights, land acquisition, displacement, environmental degradation to that of forced and child labour. The more recent discourse on human rights is relevant to Climate Change and Just Transition. Therefore, it is important for companies to operate in a manner that adopt human rights management ensuring they respect the rights of affected stakeholders. Fundamentally, personnel appointed to implement these deliverables must have the apt knowledge and skills. In ensuring these knowledge and skills are relevant, a set of competency rulers can be established to ensure the nature of the tasks and deliverables are acquired as a practitioner in human rights management. Overall, the competency rulers must be relevant to indicators and requirements of the work that is relevant to guidance ranging from from United Nations Guiding Principles (UNGP), International Finance Corporation (IFC), International Labour Organisation (ILO) among others. In addition, familiarity with company's internal standards and guidelines are among the necessities for the personnel to execute their responsibilities. As the industry continues to face challenges in complying to legislations, meeting stakeholders’ requirements, expectations and standards pertaining to Social Performance; companies are also expected to demonstrate responsible operations in managing Human Rights. Hence, companies can strive to equip its employees with the right competency. In this case, the competency ruler on Social Performance is exemplary in addressing this.
A Practical Method for Measuring the Liquid Contact Angle of Fracture Proppant Pack
Authors: Zhang Peng , Wortman Philip Bertrand , Guo Boyun , Yang Xu 
Published: October 2023

Abstract
There is lack of a reliable method to determine the liquid contact angle of fracture proppant to characterize its surface wetting property due to the non-flat surface of proppant particle. The objective of this paper is to present and use a new method for determining the liquid contact angle of proppant pack for proppant selection in fracturing oil and gas wells. The water contact angles given by the new method are similar to the contact angles found in literature for the water-air-stainless steel 304 system and the water-air-copper system. The difference is 3%~3.5%, indicating that the new method is valid for determining liquid contact angles on the smooth surfaces of solids. The new method was compared with the sessile drop method for four water-particle pack systems where stable drops were established. The difference in estimated liquid contact angles is between 0.41% and 7.12%, indicating that the new method is valid for determining the liquid contact angles on the rough surfaces of particle packs. The new method was applied to estimating the water and oil contact angles on the surfaces of packs of 11 commercial fracture proppants. Comparison of derived water and oil contact angles suggests that all these proppants are oil-wet proppants. Two proppants are considered more water-wet than other proppants because of their lower water contact angles. Although one proppant was claimed by its manufacturer as oil-wet proppant, its low water contact angle suggests that it is a water-wet proppant. It was observed that liquid contact angle of proppant pack is not sensitive to proppant size for given types of proppants in the range of proppant size tested. The new method requires only drop volume and the wet diameter/area of the proppant pack to derive liquid contact angle. Even a liquid drop sinks into a proppant pack, the contact angle can still be estimated if the wet diameter/area is measurable. The new method may not be accurate in situations where the proppant particle size is so large that the liquid drop sinks into the pore space of the pack without leaving a circular wet area at the pack surface. Further investigations are needed to establish the critical size of the particle size. The liquid contact angles given the new method are dynamic contact angles if the liquid drops are not in thermodynamic equilibrium. The results are good only for comparison of surface-wetting behavior of particles, not for scientific but engineering uses.
Pressure Depletion Integrated Static Reservoir Model as Development Planning Basis in Mature Handil Field
Authors: Erriyantoro Eros Sidney , Muhroni Toni Okto , Suardiputra Aditya , Suwito Edy , Sianturi Julfree , Utama Fia Adhi 
Published: October 2023

Abstract
Handil is a mature swamp oil and gas field located in Mahakam Delta, East Kalimantan, Indonesia. Hydrocarbon is accumulated within series of multi-layered reservoirs, which are mainly channels and crevasse splay by facies. This study focuses on Handil Gas Pool, also known as Handil Deep Zone interval. This stratigraphic interval is the deepest and primarily produces gas through a depletion drive production mechanism. The unavoidable reservoirs pressure depletion occurred with high variation across the field. Still, Handil is expected to face upcoming aggressive drilling campaign. Therefore, the evaluation of the field remaining stakes becomes even more crucial, particularly for Handil Gas Pool interval, which represents the deepest development target.
Conducting a more conventional reservoirs study method, such as history matching with a dynamic model, in Handil Gas Pool context can be relatively complex and resources-consuming. This complexity arises due to the need for regular updates with newly drilled well data. Nevertheless, identifying and location reservoirs pressure depletion remains key to optimizing future development targets. Hence, a more efficient and practical solution has been deemed necessary to overcome these challenges.
The methodology used in this study was based on integrating reservoir pressure depletion into the static reservoir model. The workflow incorporated dynamic data synthesis, production history and allocation analysis, as well as reservoir pressure estimation through P/z analysis. The study also introduced the definition of Reservoir Pressure Unit (RPU), which served as the basis for modeling and analysis. By estimating and applying the current reservoir pressure, a depleted static reservoir model was generated, representing the current Remaining Gas-in-Place. Furthermore, the volume estimation of booked undeveloped reserves was taken out from the model.
This comprehensive approach resulted in a Producible Gas-In-Place model that can be utilized for estimating and proposing future development targets. The implementation of a well-designed automated well screening workflow, in combination with a detailed dynamic review, facilitated the identification and optimization of future development targets. Among more than 70 initial well candidates, over 20 have been identified as having potential above the current economic threshold. The findings demonstrate the efficiency and practicality of the proposed methodology in identifying future development well targets and its potential for application in similar mature gas fields.
A New Artificial Lift Approach in Telisa Low Productivity Reservoir: Utilized Very Low-Rate ESP
Authors: Aryanto Agus , Malau Aldani , Hanuranto Heru Trisakti 
Published: October 2023

Abstract
KS field faces low production challenges from Telisa formation. In addition, other problems in Telisa formation are also high GLR and solid production. ESP equipped with sand control and gas handler can still be used for liquid production above 100 BLPD. The problem is that the rest of the wells producing from Telisa formation that still use gas lifts, the production of which is already below 100 BLPD. In this case, the usual ESP configuration is no longer be used. The production method with gas lifts can no longer be used due to the limitations of gas production which continues to decline. Currently, there are still more than 30 wells that use gas lift and to maintain production from these wells, the right artificial lift solution must be sought. A modification has been made to the ESP artificial lift to be able to accommodate the very low production rate. The trial has been carried out in KS-001 and KS-002 for more than 1.5 years and as the result, the ESP is still running normally today.
To improve run life for low rate ESP which may exposed to down-thrust condition and increased temperature resulted from low cooling fluid pass thru ESP motor housing, several precautions must be taken during designing ESP which fit for application: Pump with compression stages construction were selected for low rate application. This compression stages design will improve down-thrust handling in the pump. Down-thrust force generated by pump will be transferred into protector thrust bearing, where the thrust bearings were covered with lubrication oil. High load thrust bearing were selected to handle the thrust load. Tandem BPBSL – BPBSL protector selected to give extra motor oil reservoir to the ESP motor in the case of motor run on higher temperature due to low cooling fluid passes thru ESP motor housing. Due high GOR up to 800 SCF/STB, with ability to handle free gas up to 45% GVF, combination of Advance Gas Handler and gas separator were selected for better handling of free gas produced by the well. In low flow rate ESP system, fluid velocity pass thru the ESP motor housing is essential for cooling system. In the case of KS-002, well was completed with 7″ casing. ESP casing shroud were selected to improve fluid velocity.
In overall ESP parameter in 2 wells trial are in normal condition, even though running with low frequency and limited liquid rate. Application of tandem protector, gas handling device, and sand screen successfully handle very low liquid rate with high GOR in hydraulic fractured wells. With the success of ESP's very low rate in Telisa, there is no longer any concern if gas production decreases.
This paper will describe an integrated application of very-low rate ESP in sandy gassy wells with low productivity. These applications are required to improve the run-life of the ESP in Telisa zone to minimize oil deferment.
Assessment of Different Field Development Strategies Deploying Maximum Reservoir Contacting (MRC) Well in Carbonate Reservoir: A case study of Oilfield R
Authors: Jia Han , Tong Min , Peng Hui , Deng Xili , Song Ruixuan , Wang Rui 
Published: October 2023

Abstract
Deploying horizontal well is one of the efficient methods to enhanced oil recovery. Maximum Reservoir Contact (MRC) well, based on the horizontal well, which indicates the contacting area of wellbore and reservoir should be as large as possible to obtain the optimum exploration effects.
The purpose of this paper is to build an assessment and optimization work-flow, which guides the well pattern improvement and well-type selection via a case study of the filed R in a Middle East Carbonate Reservoir. Analyzing several field development index, like production performance, gas oil ratio, water cut, pressure, etc. in a pilot-scale well pattern both for the conventional horizontal wells and MRC wells using different injection schemes, including injection timing, injection volume, and injection components, via reservoir numerical simulation.
The method using to evaluating reservoir exploration effect in this paper is numerical simulation, assuming different development strategies and well-type, via reservoir numerical simulator. Control-variate method as well as used in this study, which focus on keeping single factor analysis for the simulation. Comparing all the field development indexes among different cases while keeping other factors consistent, for example, exploring the influence from well types, which are MRC well and conventional horizontal well, two cases must be deployed the same injection schemes.
Simulating different cases with analyzing the results, MRC wells obtain the better oil production generally compared with conventional horizontal wells. However, oil production performance is not the only index which is cared for in oil & gas industry, additionally, in terms of reservoir engineering, water cut, water breakthrough, gas breakthrough, gas oil ratio, oil steady production plateau, etc., while some economic indexes are extremely concerned by the experts and companies. Consequently, assessment of MRC wells effect should consider many factors from the perspective of oil & gas industry. Well trajectories adjusting with target layer or reservoir is also the MRC technique, optimization of well trajectories profits the production performance both for MRC wells and conventional horizontal wells.