bluuebunny/crossref_metadata_2025_split huggingface dataset:
CO2 Utilization: Converting Waste into Valuable Products
Authors: Berahim Nor Hafizah , Abu Seman Akbar 
Published: October 2022

Abstract
Carbon dioxide capture, utilization, and storage (CCUS), which includes conversion to valuable products, is a complex modern issue with many perspectives. In recent years, the idea of using carbon dioxide (CO2) as a feedstock for synthetic applications in the chemical and fuel sectors via reduction reactions has piqued interest. If the hydrogen is created using a renewable energy source, catalytic CO2 hydrogenation is the most viable and appealing alternative among the existing CO2-recycling solutions. CO2 hydrogenation has many chemical paths depending on the catalyst, and multiple value-added hydrocarbons can be generated. This research looks into a catalyst development for converting high CO2 gas field into methane and alcohols. The study focused on catalytic conversion of CO2 to methane over Ru based catalyst while in the case of alcohols using Cu based catalyst. Both catalysts were synthesized via impregnation techniques where the aqueous precursors’ solution were impregnated on the oxide supports, stirred, filtered and washed. The samples were then dried, ground and calcined. The synthesized catalysts were characterized using various analytical techniques (e.g., TPR, FESEM, N2 adsorption-desorption, XRD) for their physicochemical properties. The catalytic performance in CO2 hydrogenation was performed using a fixed bed reactor at various factors such as temperature, pressure, feed gas ratio and space velocity. The experimental findings indicate that conversion of CO2 to methane over Ru based catalyst resulted in &gt;84% CO2 conversion with 99% methane selectivity in the range of temperature 280 – 320 °C and at atmospheric pressure. In the case of hydrogenation of CO2 to alcohols, the catalytic performance of Cu based catalyst exhibited CO2 conversion of &gt;11% and selectivity towards alcohols, C1 and C2, both at 4% with reaction temperature of 250 °C and pressure 30 bar. These findings revealed that methane could easily be formed from CO2 as compared to alcohol. However, both technology conversions are dependent on the catalyst selection and its’ activity. Process parameters need to be optimized to maximize targeted product formation and suppress the side products.
Mitigating Sand Production by Polymer Injection in Indonesian Offshore Field
Authors: Zaitoun Alain , Salehi Nazanin , Bouillot Jerome , Hernando Louis , Wijaya Budi Rivai , Reynold Winner , Samosir Frans Samuel , Pradipta Adrianus , Witjaksono Arief , Kurniadi Wery 
Published: October 2022

Abstract
Several fields in South East Asia are suffering from excessive sand production due to clayey unstable reservoir rock. Sand production induces undesirable phenomena such as production loss due to sand accumulation in the well, damage of the pump and of the surface equipment, frequent well shut-in and heavy costs for cleanout jobs and pump changes. The operators are looking for an easy and cost-effective technique that could be deployed in the field, if possible rigless.
In a previous paper5, a pilot treatment consisting of specific water-soluble polymer injection showed good results in terms of sand production reduction and preservation of well performances. The polymer adsorbs strongly on the reservoir rock, forming a continuous film on pore walls. The film has a consistency of thin sticky gel stabilizing the rock. Moreover, the polymeric film acts as Relative Permeability Modifiers (RPM) and thus maintain oil permeability while reducing water permeability. This RPM property enables the deployment by bullhead injection into the whole open interval.
Field extension has been scheduled and similar treatments have been performed in 4 new wells. In the field, the polymer is injected by coiled tubing in each open interval selectively. The polymer is pushed in the formation by diesel/water postflush, which also re-saturates with oil the near-wellbore area and help production re-start. The feedback obtained so far can be listed as follows: No production loss occurred in all the treated wells.Sand-free production rate could be increased after the polymer treatmentSand production was totally stopped for a few months before coming back again after 4-12 months, at much lower rate than before.A re-treatment induced new period of sand-free production for several months.
Such results confirm the sustainability of the polymer technology. The field methodology has been optimized. It opens new perspectives and could become a new sand control system in the toolbox of the profession.
Successful Use of Novel Bio-Based Surfactant Internal Ketone Sulfonate (IKS) Chemistry for Indonesian High Temperature Reservoir: Formulation Development to Oil Recovery Efficiency in Native Reservoir Core
Authors: Fauzi Iqbal , Sulistiyani Sri , Permadi Imam , Prasetyo Arif Bagus , Miyondri Dodi , Utami Anis Nurrachmania , Pasarai Usman , Wangge Yohanes B Doi , Eni Hestuti , Roy Sayak , Vidaillac Cyril 
Published: October 2022

Abstract
Growing national demand and declining or maturing fields in Indonesia have pushed the country to increase and accelerate efforts to improve production from the maturing fields by engaging various tertiary recovery techniques as one of the strategic pillars in achieving national target of 1 MMBOPD oil production in 2030. Several fields are being considered and being studied strategically as potential for application of chemical EOR technologies. High temperature reservoirs in Limau block of South-Sumatran basin is an onshore mature field which has been identified as a potential chemical EOR candidate. Due to higher reservoir temperature (&gt;100°C) it is always challenging to develop a surfactant-based chemical EOR solution due to pronounced issues in chemical compatibility.
For any economical surfactant-based chemical EOR process an optimized surfactant or surfactant-polymer formulation needs to be developed in a laboratory which depicts good thermal stability, compatibility with polymer or injection water, exhibits ultra-low interfacial properties (&lt;10−2 mN/m) with crude oil and injection water brine, lower surfactant adsorption and higher production of residual oil from the native reservoir core using shorter slug (&lt; 1 PV of SP injection). In this current study, a detailed workflow was followed to successfully achieve the above key performance indicators (KPIs) for developing a tailor-made surfactant-polymer formulation in a high temperature (107° C) Limau field, which is always a massive challenge.
A multi-component surfactant formulation using the novel bio-based surfactant internal ketone sulfonate (IKS) as the primary surfactant was designed for high-temperature Limau reservoir. The detailed laboratory analysis shows that surfactant formulation along with polymer is able to exhibit a robust behaviour at the challenging reservoir condition. The detailed laboratory screening concludes that the designed robust SP formulation is able to induce ultra-low IFT (~1×10−3 mN/m), excellent solubility and compatibility at the injection water salinity, high incremental oil recovery (&gt;75% ROIP) with low surfactant retention in shorter SP slug injection in reservoir core.
Study of Casing Shielding Effect for Rotating Magnet Ranging in Non-Conventional Decommissioning Applications with Partial Access to a Target Well
Authors: Dorey Jamie , Ridgway Douglas 
Published: October 2022

Abstract
Regardless of their complexity, all wells must be properly plugged and abandoned at the end of their lifecycle to ensure a permanent seal between hydrocarbon-bearing layers, fresh-water zones, and the surface. In most cases, such a seal can be established via conventional well intervention where complete access to the target well is available.
Complex plug and abandonment techniques using access-independent magnetic ranging methods for subsurface well intervention are available for scenarios without access to the target well.
In some cases, the access to a target well may be available from the surface but restricted deeper down the well due to completion specifics, multi-wellbore structure, or well damage. In these cases, access-dependent magnetic ranging, such as the rotating magnet method, can be used to locate and follow the target well until the access restriction before employing access-independent techniques. This approach may significantly reduce the time and capital spending required for well abandonment.
This paper discusses the rotating magnet ranging method in application to the abandonment of wells with partial access. In these scenarios, magnetic ranging sensors are deployed in one or more concentric casing strings that cause a magnetic shielding effect and must be accounted for. The nature of this effect, its interference with the ranging measurements and correction techniques will be described.
A series of surface tests have been performed with the ranging sensor assembly placed within one, two, and three concentric casing strings to study the casing shielding effect on magnetic ranging measurements. The measurements were collected at different relative orientations and distances between the sensors and the signal source, simulating various downhole scenarios.
The results show that triple concentric casing reduces the cross-axis signal 30-fold, double casing – 8.5-fold, and single casing – 4-fold. However, even in the worst-case scenario, the signal stays strong enough to still be able to detect the source more than 20m away.
Access-dependent magnetic ranging methods can be employed in subsurface intervention decommissioning scenarios with partial access to the target well. The challenges associated with running magnetic sensors in a casing can be addressed allowing to minimize time and capital expenditures in non-conventional plug and abandonment.
Moving Rig Time Efficiency to Improve Operations, Reduce Non-Productive Time Rig and Emission Co2 Using on Trailer
Authors: Hidayat Teguh Rachman , Hariagung Erwin , Suharto Suharto , Kurniawan Fajar , Rosandi Didi , Riswandana Reza , Hidayat Rahmat Taufik , Irawan Gondo , Setiadhi Imam , Almadani Nadir Faisal 
Published: October 2022

Abstract
One of the efforts achieve Key Performance Indicator is to realize efficient organizational performance. Optimizing rig movement management is needed in PT. Pertamina Hulu Indonesia Sangasanga Field by reducing the duration of moving between wells and ensuring that the Rig cycle time kept to minimum. In real condition, all equipment in rig unit is still arranged on its own Skid with a large number of transport loads and in the activity of moving Rig/Hoist equipment between wells, all equipment transported is moved and rearranged at the next well location by using Winch Truck, Truck Crane, Flatbed truck and Crane. Moving activities with Winch Trucks and Truck Cranes accompanied by lifting activities have a high risk with 14 loading loads per moving rig. With far distance between sub working area and various obstacles such as river, bridge load limit, land and river transportation types resulting in long rig moving time. In 2019, to the second semester 2020 the loss when moving rigs reached USD 1,483 Million. The limited number of lifting and transporting equipment, the number of equipment and the loading-unloading process are the dominant cause for long moving rig time. To solve this problem, we modify the rig equipment into an On Trailer with the aim to arrange all Rig operational support equipment on the trailer both during operation and moving, and to reduce the number of loads, rig moving time and the risk of lifting. On Trailer is equipped with Handrail & walkway, sets of manual jacks, and trailer and prime mover connection including pneumatic line system. After the implementation of On Trailer, the frequency of loading, unloading and setting work drops to 9 times lower so the potential for tool damage decreases, moving rig time managed to decrease to 9.6 hours thus decrease rig personnel workload. By using On Trailer, it successfully reached cost efficiency of USD 1,354/well, the risk of work accidents due to lifting & rigging activities minimized to 9 times and reduce the CO2 emission is 2,487 Gj/year due to decrease of fossil fuel consumption.
Evaluation of Zonal Isolation Material for Low Temperature Shallow Gas Zone Application
Authors: Agista Madhan Nur , Khalifeh Mahmoud , Saasen Arild 
Published: October 2022

Abstract
Methane gas leaks from shallow gas zone have been reported in some areas in the North Sea. In the North Sea, shallow gas zones can have temperatures below 25°C with relatively low pore pressure. It is necessary to prevent the flow of this gas behind casings by performing proper zonal isolation with cementitious materials. A series of experiments were performed on three different types of industrially used and state-of-the-art cementitious materials and a rock-based geopolymer to evaluate their performance for shallow gas zonal isolation. Neat class G Portland cement, industrial rapid-hardening cement, gas-tight cement, and granite-based geopolymer were the selected materials. The research aims to reveal the performance of these zonal isolation materials and their potential shortcomings due to the low-temperature effect. Material characterizations were performed on three states of the materials: liquid-state, gel phase, and solid-state. Rheological properties and consistency are evaluated at the liquid state of the materials. Static gel strength tests were performed to evaluate the strength of gel structure and transition time. The compressive strength of samples was evaluated using an ultrasonic cement analyzer (UCA) and unconfined compressive strength (UCS). In addition, the scanning electron microscopy (SEM) technique was utilized to reveal microstructure of the materials. To have a similar hydration process as in the low-temperature shallow gas zone, slurries were mixed and pre-conditioned at temperatures of 4 and 25°C. The experiment shows that the hydration process of the cement is less optimum in the low-temperature condition, which affects the gel strength development of the cement during the transition from liquid to a solid phase. It also resulted in the lower final compressive strength of the cured specimens.
Correcting for Base Oil Contamination in Gas Condensate PVT Samples – An Improved Approach
Authors: Bon Jan , Ortega Alexander Jesus , Nalepa Wojciech , Do Giang Thanh Thi , Apolloni Rodmy Gerardo 
Published: October 2022

Abstract
PVT samples collected by wireline formation testers in wells drilled with Oil Based Mud or Synthetic Based Mud (OBM/SBM) can suffer from contamination due to the base oil in the drilling fluid. This is particularly a problem for lean gas condensate reservoir fluids. This study focused on improving decontaminated compositions by adjusting the subtraction factor for each OBM/SBM component.
To demonstrate the concept, a series of static condition laboratory PVT tests were performed using methane only and methane plus CO2 together with an SBM to determine what quantity of each component from the SBM vaporizes into the synthetic reservoir fluid. This was done by adding an excess volume of SBM to a PVT cell with pure methane and establishing equilibrium in order to saturate the fluid at reservoir sampling conditions, and then repeating with addition of 10 mol% CO2 to the gas stream. The subsequent composition was then analyzed to determine what quantity of each component from the base oil vaporized into the reservoir fluid.
Correction methods exist for compositional analyses that involve mathematical subtraction of the base oil contamination from measured compositions. These are spreadsheet exercises, since physically cleaning the samples any more than that achieved already during the sampling process itself is not possible. These correction methods assume either a logarithmic1 or gamma2 distribution to correct the C7+ fraction of the reservoir fluid.
During this process it is often noted that the OBM components do not vaporize equally into the reservoir fluid. We demonstrate through analyses that lighter hydrocarbon components from the OBM/SBM vaporize more easily than heavier components, and that the relationship correlates to the molecular weight of the OBM/SBM component. A linear subtraction process can therefore be improved with a volatility adjustment to each component, which we demonstrate is a function of the equilibrium ratio (K-value). Nagarajan et al. (2010)3 has previously suggested a K-value based correction method, however the novel approach outlined here is the calculation of the quantities in which base oil components will vaporize, giving a ‘pseudo vapor composition’ of the base oil, and using this stream as the first step in the subtraction process.
Fines Migration and Production in CSG Reservoirs: Laboratory & Modelling Study
Authors: Hashemi Abolfazl , Borazjani Sara , Nguyen Cuong , Loi Grace , Badalyan Alexander , Dang-Le Bryant , Bedrikovetsky Pavel 
Published: October 2022

Abstract
Fines detachment is an important component of methane production from Coal Bed Methane reservoirs. Production of coal fines is widely observed during dewatering and simultaneous gas-water production. The theory for fines detachment by drag against electrostatic attraction, model of the transport of those detrital fines, and their validation by laboratory test is widely used for planning and design of Coal Seam Gas developments. However, clay particles that naturally grow on coal grains and asperous parts of coal surfaces (authigenic and potential coal fines) are detached by breakage. To the best of our knowledge, the analytical theory for detachment of authigenic and potential coal fines is not available. The present paper fills the gap. Based on Timoshenko's beam theory, we derive failure conditions for breakage of authigenic and potential coal fines of the rock surface. It allows defining maximum retention function for fines breakage. The maximum retention is incorporated into transport equation of mobilized fines, allowing developing analytical models for linear flow of core flooding and radial flow of well inflow performance. Matching of laboratory coreflood data from four laboratory studies show high agreement. The model coefficients obtained by treatment of laboratory data allow predicting skin growth in production wells under fines migration.
Analytical and Numerical Sand Production Prediction Calibrated with Field Data, Example from High-Rate Gas Wells
Authors: Asadi Sadegh , Khaksar Abbas 
Published: October 2022

Abstract
Sand production prediction is essential from the early stages of field development planning for well completion design and later for production management. Unconsolidated and weakly consolidated sandstones are prone to fail at low flowing bottom hole pressures during hydrocarbon production. To predict the sand-free drawdown, a robust sand prediction model that integrates near-wellbore and in-situ stresses, rock mechanical properties, well trajectory, reservoir pressure, production and depletion trends is required. Sanding prediction models should be calibrated with field data such as production and well tests observation. In the absence of field data, numerical techniques can provide a reliable estimate on potential onset and severity of sanding at various reservoir pressures.
In this study, analytical and finite-element numerical models are independently used to predict the onset of sanding and volume of produced sand from high rate has wells with weakly consolidated sandstone reservoirs in onshore, Western Australia. The analytical method uses a poro-elastic model and core-calibrated log-derived rock strength profiles with an empirical effective rock strength factor (ESF). In the study, the ESF was calibrated against documented field sanding observation from a well test extended flow period at the initial reservoir pressure under a low drawdown pressure. The numerical method uses a poro-elasto-plastic model defined from triaxial core tests. The rock failure criterion in the numerical method is based on a critical strain limit (CSL) corresponding to the failure of the inner wall of thick-walled cylinder core tests that can also satisfy the existing wells sanding observations. To verify the onset and severity of sanding predicted by the analytical model, numerical simulations for an identical sandstone interval are developed to investigate the corresponding CSL.
This combined analytical and numerical modelling calibrated with field data provided high confidence in the sanding evaluation and their application for future well completion and sand management decisions. The analytical model was finally used for sanding assessment over field life pressure condition because of its processing simplicity, speed and flexibility in assessing various pressure and rock strength scenarios with sensitivity analysis over the whole production interval in compared with the numerical method which is more suitable for single-depth, single pressure condition and well and perforation trajectory modelling.
Stiff String Casing Design with 3D Orientated Casing Wear
Authors: Nobbs Benjamin , Aichinger Florian 
Published: October 2022

Abstract
The forces and stresses along a casing string are modelled using a stiff string torque and drag model. A post analysis of casing loads and stresses, considering wellbore tortuosity and centralisation is performed in addition to the effect of 3D orientated casing wear. A post analysis case study is presented to show the resulting effect on axial, burst, collapse and VME safety factor as well as VME body and connection design envelopes.
While running in hole (RIH) a tubular, the industry standard is to assume a smooth wellbore when performing a torque and drag calculation. The drilling process can cause significant local doglegs and ultimately increase the tortuosity of the wellbore. When applying a soft-string torque and drag model, it is possible that the stiffness, radial clearance, and high frequency surveys are not directly considered. The stiff string torque and drag and buckling model can model these effects, as well as the addition of rigid and flexible centralisers. This study involves the comparison of different casing design load cases, using the actual tortuosity of a drilled wellbore considering a 3D orientated casing wear.
The results show that there can be noticeable differences in overall axial stress with the addition of tortuosity. The stiff string model can directly calculate the additional bending stresses experienced by the tubular and this additional stress can be particularly prevalent while RIH casing with centralisers and high tortuosity. The reduction in API and VME stress envelope is also quantified using a 3D orientated casing wear model. A better understanding of axial stress state reduces risk of well integrity issues and can pinpoint areas along the casing in which special care must be taken during well intervention.
This paper will show the benefits of using a stiff string torque and drag model during casing design. Highly tortuous wellbores, especially ERD and HPHT wells, may exhibit stresses that are vastly different than assumed during preplanning phase. The design API/VME envelope may also be reduced due to casing wear.