bluuebunny/crossref_metadata_2025_split huggingface dataset:
High Temperature Dissolvable Materials Development for High Temperature Dissolvable Plug Applications
Authors: Yue Wenhan , Ren Jiaxiang , Yue Jianpeng , Cheng Peng , Dunne Tim , Zhao Lei , Patsy Matthew , Nettles Damon , Liu Yu , Liu Huailiang 
Published: September 2022

Abstract
Dissolvable tools have been used more in unconventional oil and gas operations in recent years. Currently, more and more wells in Southwest of China quires high temperature (HT) dissolvable plug. The HT dissolvable plug needs to hold pressure in water at 150°C for 24 hours. On the other hand, the dissolvable plug needs to be dissolved in 1% KCl at 95°C in less than 15 days. These requirements put big challenges on dissolvable materials.
Several HT dissolvable rubbers were developed to meet the requirements. The ambient and high temperature tensile testing were performed on the dissolvable rubbers. The dissolution testing of the dissolvable rubber was performed in brine at 140°C for 1 day and then at 95°C. Several dissolvable metals were developed and the slow strain rate testing (SSRT), Scanning electron Microscope (SEM)/Energy Dispersive Spectroscopy (EDS) testing were performed on these dissolvable metals. A special coating was developed to reduce the stress corrosion cracking of the dissolvable metals. Two HT dissolvable plugs were developed based on the dissolvable materials. The pressure holding testing and dissolution testing were performed on the two dissolvable plugs.
It was found that the tensile strength of the HT dissolvable rubber at 150°C was higher than 1200 psi and elongation was higher than 700%, which was higher than that of most of the commercial HT dissolvable rubbers. The dissolvable rubber coupon disintegrated to tiny pieces at 95°C in 4 days. One dissolvable metal displayed better stress corrosion cracking resistance than the other dissolvable metals. The dissolvable metal promotes discontinuous grain boundaries and secondary phases within the grain boundary to prevent crack growth and propagation at the expense of strength. The dissolvable metal was used for lower slip of the dissolvable plug. The special coating on the dissolvable metal significantly reduced the dissolution rate of the dissolvable metal at high temperature. The two dissolvable plugs passed the pressure testing a of 10 ksi at 150°C in water for 24 hours. The dissolvable plug was dissolved in 1%KCl at 95°C in 14 days. The weight loss of the plug was more than 95%, All the remining residues of the dissolvable plug was less than 2 cm. The pressure holding and dissolution testing results of the dissolvable plug successfully meet the field testing requirements.
This is the first time in the industry based on our knowledge a HT dissolvable plug passed 150°C, 10 ksi 24 hours pressure holding test in water and then dissolved in brine at 95°C in less than 15 days. The HT dissolvable rubber was specially designed to possess both high mechanical properties at 150°C and dissolution properties at 95°C. The dissolvable metal for lower slip was formulated to prevent crack growth.
The Future Called; It Wants to Know Where Its’ Data is?
Authors: Murdoch Euan 
Published: September 2022

Abstract
This paper will review the current state of downhole wireless completion technologies. It sets out an optimized strategy for the selection of commercially viable systems and provides a discussion of the technical hurdles that that are still to be overcome
Technologies for real-time wireless downhole data acquisition exist but their widespread adoption has been limited. By relying on theoretical calculations and limited reservoir coverage, some operators are basing critical decisions on a limited picture. This could be during the deployment of completions, leading to a failure to reach total depth (TD) or recognize and deal in a timely way with well control incidents or during the production, where quantification of the reservoir parameters is beyond the reach of a single pressure/temperature gauge. This is typically due to a lack of a value calculation for these technologies, and this paper will set out the information needed to improve the decision process.
There are a number of key wireless communication technologies that exist commercially for downhole deployment. These are: acoustic, electromagnetic, radio frequency identification (RFID), pressure modulation, and timers. The strengths and weaknesses of each technology will be presented, and it will also be shown how they can be used to complement each other. A number of global case studies will be presented; these will show the successful deployment of these technologies and the benefits that were brought. This information will then be built on to show how a wireless system should be implemented to satisfy the operators requirements within the technical and financial constraints of today's landscape. Finally, it will highlight the technology gaps that exist that hold the industry back from a "perfect" solution.
IADC Code Upgrade: Interpretation of Surface and Downhole Data to Support Drilling Forensics
Authors: Watson William , Witt-Doerring Ysabel , Sugiura Junichi , Pastusek Paul , Daechsel Dustin , Vallet Laurent , Amish Mohamed , Oluyemi Gbenga 
Published: September 2022

Abstract
This paper establishes drilling surveillance interpretation and monitoring techniques for digital drilling data which can be used to support drilling forensics and improve drilling performance.
One significant advancement in the last 20 years has been the widespread availability and use of sensors to monitor all aspects of the drilling process. The majority of sensors will take surface and downhole data at several hundred samples per second, process the data and store a record at one sample per second. The data from these sensors are collated and processed using some form of Electronic Data Recording system. The information is subsequently displayed in realtime and stored for offsite transmittal. This paper extensively evaluates the impact on drilling performance due to how data from such sensors are collected, processed and the information displayed.
A number of observations are investigated, analyzed and explained identifying how data quality, consistency, frequency, sensor errors and data artefacts can skew the displayed results. This can critically impact the drilling forensic analysis and subsequent interpretation. Failing to account for these data quality issues in realtime may mask drilling dysfunction causing accelerated damage to the drill bit and drilling assembly. This paper also aims to highlight techniques for displaying and interpreting drilling data to enhance drilling performance as well as diagnose dysfunction during reviews of historic wells. Understanding these limitations in advance and incorporating them in a team's surveillance strategy can help with the diagnosis of drilling dysfunction and aid performance improvement.
These recommended practices have been developed to offer a foundation for drilling surveillance, interpretation and monitoring as well as training for the industry. They have been created such that they can grow organically and may be used for developing subsequent industry publications.
The work described in this paper is part of a joint International Association of Drilling Contactors (IADC) / Society of Petroleum Engineers (SPE) industry effort to revise the IADC dull grade process.
Wettability Alteration of Kerogen by Interacting with Hydraulic Fracturing Fluid
Authors: Yi Xuan , Lee Kyung Jae 
Published: September 2022

Abstract
The recent increase in unconventional oil and gas exploration and production has promoted active research on hydraulic fracturing, but the impact of interactions between fracturing fluid and kerogen on the alteration of kerogen wettability has not been well understood. The objective of this study is to experimentally estimate the changing wettability of kerogen with various thermal maturity levels by the interactions with hydraulic fracturing fluid.
To achieve the objective, kerogen was isolated from a bulk rock of organic-rich shale with different types and maturities. Kerogen isolates was kept in a mix with synthetic hydraulic fracturing fluid under the temperature of 80 °C for 14 days. Relative changes of sulfate ions were analyzed by using Ion Chromatography (IC). In the measurement of kerogen wettability, sessile drop method was applied to measure the direct contact angle by utilizing the Drop Shape Analyzer (DSA). During the reaction with hydraulic fracturing fluid, kerogen isolates were analyzed by conducting functional group analysis, which provided the supplemental information on the wettability of kerogen. Functional groups of kerogen were analyzed by using the Attenuated Total Reflectance Fourier-Transform Infrared spectroscopy (ATR-FTIR).
The reaction of fracturing fluid and kerogen isolates from various organic-rich shales were conducted, and it is experimentally demonstrated that the interactions between kerogen and fracturing fluid would cause substantial wettability alterations in organic pores and fractures that depend on the types and maturities of kerogen. The DSA results indicated that the air/water-contact angle decreases after the reaction, regardless of the types and maturities of kerogen, while the higher level of maturity of kerogen led to a greater change of air/water-contact angle. The results of ATR-FTIR showed that the hydrophobic functional groups were lost in the mature kerogen isolates, and they were potentially lost in the relatively lower level of maturity-kerogen isolates due to the oxidation, indicating that the kerogen showed increasing hydrophilicity, which provided a strong support to the DSA results.
This study experimentally determined the wettability alteration of kerogen by interacting with organic additives in hydraulic fracturing fluid. The results of this investigation will provide a significant step forward in evaluating the multiphase fluid transport in organic-rich shales with the wettability alteration and resulting hydrocarbon production.
A Practical Approach to Model Four-Phase Flow Through Porous Media
Authors: Gong Xu , Fang Chen , Li Zhidong , MacIsaac Gordon , Motahhari Hamed Reza 
Published: September 2022

Abstract
The recent advancements in the field trial of the solvent-based Enhanced Oil Recovery methods indicate the presence and simultaneous flow of four phases (i.e. water, vapor, heavy liquid hydrocarbon and light liquid hydrocarbons) in the hydrocarbon reservoirs. The accurate modeling of these field observations is not achievable in the most commercial reservoir simulators as they are generally formulated for three phase equilibrium and flow calculations. This paper evaluates the merits of a newly proposed approach [1] to incorporate an algorithm to model the four-phase flow within the conventional three-phase reservoir simulation framework without need for major change in formulation or code revamp.
Compositional data from field pilot trial of the Cyclic Solvent Process (CSP) is used to evaluate the simulation model capabilities to model flow of four-phases in the porous media. The reservoir simulation models are used to history match the production performance of CSP process in in the field. Laboratory and field CSP data indicate the presence and flow of 4 phases in different stages of the CSP production cycle.
The previously proposed "phase-combination" approach shows limited capability to match the changes in the compositional assay of the produced hydrocarbons in CSP process. In this paper, an improved "Coflow" formulation is proposed based on the modified Einstein Equation for dispersed flow. The new formulation is implemented in conventional three-phase reservoir simulation framework and tested against the data providing superior capability in match in the field production assay data.
This paper provides a practical method to model four phase flow within the framework of the three phase reservoir simulation frameworks. The newly proposed "coflow" method in combination with the previously developed method provides a consistent framework to model flow of two hydrocarbon liquid phases in the porous media either in a continuous or dispersed flow patterns. This enables use of commercially available reservoir simulator for modeling of solvent-based EOR methods without need to significant changes in formulation or code revamp.
Effective Water Treatment in the Permian and Marcellus Shales to Mitigate Surface Equipment Failures
Authors: Kakadjian Sarkis , Korhonen Keith , Solomon Marvin , Kitchen Jarrett , Gebrekirstos Amanuel , Risner Jesse , Algadi Otman 
Published: September 2022

Abstract
Chemical and oxidative biocides are designed to sanitize water by reducing aerobic and anaerobic bacterial populations in the fresh, brackish and reclaimed source waters. These biocides are used extensively in high-rate fracture stimulations to reduce formation damage, chemical degradation, biogenic H2S and microbial induced corrosion (MIC). Oxidative biocides work by removing electrons from the cell wall of aerobic and anaerobic bacteria. The same electron transfer mechanism can be detrimental to surface equipment. This study presents the impact of several oxidative biocides on the corrosion rate and pitting of different frac iron alloys and how those biocides effect the mechanical integrity of elastomer seals. It also presents different remediation methods to mitigate their oxidative effects.
The oxidative biocides tested were Chlorine, Chlorine Dioxide and a Peracidic Acid blend. The corrosion rate of the iron alloys coupons was measured by weight loss analysis. This method can measure the rate of corrosion in pounds per square foot at time and was used to compare the impact of different residual oxidizers on the corrosion rate of the ground iron. Structural changes to the elastomers were detected visually.
The results of the study showed that the corrosion rate varied depending on the alloy/residual oxidative biocide combination. Usually, Peracidic Acid blend or Chlorine had the highest corrosion rates across all alloys tested; depending on the oxidative biocide/alloy combination, the corrosion rate could vary by a factor of 2X over the nine-week timeframe. Elastomer testing over 6 weeks showed variability in the types of structural changes depending on the concentration and oxidative biocide tested.
The lab and field testing included onsite monitoring of the corrosion rate, oxidation reduction potential (ORP), oxygen in solution and determination of the Langelier Saturation Index (LSI). The methodology has been effective in predicting iron failures related to the composition of the water and/or presence of oxidizers. Chemical solutions implemented to mitigate the surface iron failures included use of intermittent blends of water-soluble quaternary amines and surfactants. Since these remediation attempts have started, the replacement cost of frac iron has decreased from over 550K US$ per month, per frac spread to none, over a 3-month period.
A Simple and Practical Approach to Estimate Dispersive Mixing in Underground Hydrogen Storage Systems
Authors: Maniglio Marco , Pizzolato Alberto , Panfili Paola , Cominelli Alberto 
Published: September 2022

Abstract
Hydrogen represents a strategic vector to compensate for seasonal energy production/demand discrepancies, deriving from the rapid increase in renewables resources needed to achieve the 2050-net-zero emissions target. Subsurface porous rocks, like depleted gas reservoirs, are a promising solution to store the hydrogen volumes to accomplish those targets. The efficiency of Underground Hydrogen Storage (UHS) systems can be largely affected by the mixing between hydrogen and the original gas due to mechanical dispersion at different scales.
A methodology was developed to evaluate the loss of hydrogen in storage operations which can be ascribed to diffusive/dispersive phenomena. Results suggest that large-scale heterogeneity dispersive transport is the dominant factor affecting the hydrogen storage efficiency when compared to molecular diffusion, core-scale dispersion and, depending on the grid resolution, numerical diffusion. Moreover, reservoir-scale heterogeneities have far greater impact on hydrogen dispersivity than pore-scale heterogeneities, questioning the usefulness of experimental campaigns on reservoir rock samples.
The study provides a simple workflow to quickly estimate the impact of dispersion induced by large-scale heterogeneities on UHS efficiency. Results are of prompt practical interest for pilot applications as the methodology can be applied on real assets, considering the scale and storage strategy of interest.
Wellbore Integrity Impact on Carbon Leakage to Ensure Safe Geological Sequestration
Authors: Ning Yanrui , Tura Ali 
Published: September 2022

Abstract
Secure and safe geological sequestration is critical for the successful deployment of carbon capture and storage (CCS) projects and to mitigate global warming. Oil/gas reservoirs and saline aquifers, that are suitable for CO2 sequestration, often have older pre-existing wells near the potential CO2 injection wells. The legacy producing and abandoned wells have the potential to behave as CO2 leakage pathways, despite the existence of a good seal formation or structural certainty. In this study, this poorly understood and largely unknown leakage potential is researched to quantify the carbon leakage rate along one legacy well when carbon is injected into a storage formation in the Denver-Julesburg (DJ) Basin. This study investigates the risk of containment loss for a leaky well using a one-square-mile section of the DJ Basin. The results show that the completion of an older wellbore has a significant effect on the leakage rate results. A small portion (10-8) of the injected carbon can leak via a multi-segmented wellbore, while around 2.5% CO2 can leak to the drinking water layer via an open wellbore. Our results indicate that for secure carbon sequestration, a good geological storage site should be kept away from wells that have a surface casing depth of 476 ft or shallower and were drilled before 1994 in Colorado. The effective well permeability highly impacts the leakage rate, implying the importance of estimating the most representative value/range for this parameter. This risk assessment research is a part of the pre-feasibility study to support potential large-scale geological carbon storage operations in Colorado.
Biomineralization: A Natural Solution to Eliminate Gas Migration
Authors: Hiebert Randy , Panzo Lauren , Hyatt Robert 
Published: September 2022

Abstract
A Seneca Resources Company, LLC (Seneca) natural gas well in Pennsylvania was leaking methane from both the 13-3/8 in × 9-5/8 in (55 psi) and the 9-5/8 in × 7 in (85 psi) cemented annuli. Previous attempts to mitigate the problem had proven unsuccessful, which prompted the trial of a new method using the natural process of biomineralization.
BioSqueeze Inc. (BSI) was contracted by Seneca to apply their proprietary biomineralization technology to the well. To prepare the well, circumferential notches were cut through all casing strings all the way to the formation to allow fluid injection into the annuli. Biomineralizing fluids were then pumped into the well, where they formed crystalline calcium carbonate in the micro annuli.
After 1.5 days of treatment, the injection rate dropped by several orders of magnitude. Subsequent monitoring by a state regulator determined surface pressure had been eliminated and there were no escaping hydrocarbons.
Mechanically-Robust Nanocellulose Engineered Preformed-Particle-Gel for Conformance Control in Fractured Tight Reservoirs: Transport Through Proppant-Packed Porous Media
Authors: Wei Bing , Mao Runxue , Tian Qingtao , Lei Wenhai , Tang Jinyu , Wang Dianlin , Lu Jun 
Published: September 2022

Abstract
Preformed-particle-gel (PPG) holds promising potential for conformance control in fractured tight reservoirs because it enables mitigation of fracture channeling with insignificant leakoff. However, conventional PPG with weak and brittle network is severely vulnerable to shrinkage, breakage, fatigue and even degradation during extruding through narrow fractures that were much smaller than themselves, and finally results in the failure of gel treatment. Therefore, in this work, a new kind of nanocellulose-regulated robust particle-gel (N-PPG) was designed and prepared using high-modulus and green nanocellulose (NCF). The mechanical properties of N-PPG including hardness, springiness, resilience, chewiness and cohesiveness were assessed using a texture analyzer at the grain-scale. The results demonstrated that the presence of NCF (0.1 wt%) noticeably improved the mechanical properties of PPG, 49.5% increment of hardness, 29.3% of resilience, 86.3% of chewiness and 25% of cohesiveness. The swelling test showed that the salinity had slight effect on the swelling kinetics and equilibrium swelling ratio (SR) of N-PPG. N-PPG exhibited excellent tolerance to the acidic solution. After aging for 44 days, SR fluctuated slightly and maintained at 9 cm3/g. The gel skeleton was not collapsed, and the microstructure was similar to the control group (aged in the neutral solution). Upon transporting through the fractures, the porous media was packed using millimetric-sized glass beads to replicate proppant-filled fractures after hydraulic fracturing. N-PPG exhibited significantly higher resistance factor (Fr) and residual resistance factor (Frr), indicative of better performance in conformance control. The influence of particle size, velocity, and PPG elasticity on the transport and placement of PPG in fractures were investigated. Due to the preeminent mechanical properties, N-PPG was hardly broken even after being extruded out from pore-throat geometries with up to a particle-throat diameter ratio (Dg/Dp) of 15, whereas the control PPG was notably crushed, implying the low efficiency in deep applications of conformance control. The Fr of PPG in fractures analogously depended on Dg/Dp even if the superficial velocity (u) was varied from 0.72 m/d to 4.32 m/d. To fully consider the interaction between deformable particle and fluid in the complex pore-throat geometries, an Immersed Boundary-Lattice Boltzmann modeling (IB-LBM) was developed to numerically simulate PPG passing through a throat (50 μm). A spring-network model was used to capture the deformation of PPG. The grain-scale modeling yielded the pressure profile of PPG, from which a clog-deform-pass procession mode was defined.