bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pioneering Oil-Degradable Nano-Composites for Deepwater Sand-Control Tools: To Preclude Annular-To-Tubular Communication During Deployment in Brine, and Degradation-To-Removal in Oil, Ensuing Production
Authors: Roy Ting , Ben Naceur Kamel , Singh Manjinder , Markel Daniel , Harp Leonard , Ardic Hifzi , Wilkinson Christian , Roy Indranil 
Published: September 2022

Abstract
In the energy industry many applications and embodiments are envisioned, for temporary sealing to dissolvables where deployed tools may remove themselves without any intervention, and on demand. Triggers for dissolution are often common downhole fluids of an aqueous nature. Metals designed to undergo accelerated corrosion via anodic dissolution or hydrolysable polymers triggered by brackish water, flowback or produced, facilitated by elevated downhole temperatures, are common. However, there is not a single formulation with tailored properties, engineered to degrade in presence of oil.
Here we present, industry's first oil degradable, nano-composite formulations, for HPHT temporary sealing. An application, as a one-way port plug or ball valve for deploying a sand screen using this novel technology will be ideal. The ball would seal against the flow-ports or nozzles when running in hole and circulating fluid through the screen to the toe and back up the annulus. Once the screens are set, and the well put on production, the oil will produce through the flow ports or nozzles, better known as inflow control devices or ICDs’ and drive the ball away. The ball is to be retained in a cage to allow unrestricted production. In reality, this solution however presents challenges. Production of solids, waxes and asphaltenes often gum up the ball in the cage and restrict production, often needing costly intervention. The ideal scenario will be if the ball seals can dissolve in produced hydrocarbons aka oil of varying API gravities. This will ensure unrestricted production, reduce possibility of intervention and rig time savings, all in all a step towards lowering our carbon footprint.
To augment the patented answer product, a step change in adding sensing and intelligence, nano-particulates and/or sensors as unique-identifiers are accommodated in the composite bulk, as tracers, control-released during degradation. As these nano-particulates, flow-back with production to the surface, these tracers with a unique fingerprint, are identified as they pass-through an in-line detector identifying the nano-crystal. The detector, comprising a remote computing system configured to store and relay information relating to these tracers is under development. This industry first is a paradigm shift in remote-monitoring, alerting any end user, anywhere in the world, of selected downhole event triggers, without running any device in the well.
Design Mud Weight and Control Breakout Width Based on Angle of Intersection Analysis
Authors: Zhang Jianguo , Edwards Stephen 
Published: September 2022

Abstract
Numerous wellbore instability problems have been reported when drilling through laminated shale formations because of anisotropic (weak) strength along bedding layers. The anisotropic strength is defined through the analysis of stress distributions around wellbore and angle of intersection (AOI) between well trajectory and weak bedding plane.
This paper presents a method to calibrate a wellbore stability model, design mud weight and control breakout width based on analysis of AOI and anisotropic strength. The proposed method includes four (4) steps as follows:
AOI is calculated by using bedding plane data (dip angle and dip azimuth) and well trajectory information (well inclination and azimuth). Based on single plane of weakness theory, the stress distributions around deviated wellbores in laminated shales are analyzed to show that failure can occur either along or across bedding planes depending on AOI. The profile of collapse pressure for both isotropic and anisotropic strength model are calculated along with the AOI. Drilling data (mud weight, cuttings/cavings pictures etc.) combined with azimuthal density image are used to choose and calibrate the wellbore stability model.
Lab strength test results with different angle to bedding plane are used to calibrate rock strength model and field data are collected and analyzed to define acceptable breakout width. Field data demonstrates that AOI can have a significant effect on wellbore stability. It is observed that severe borehole problems occurred in hole sections with low AOI (&lt;30°) especially when a low mud weight is used to allow a wider breakout. Minor wellbore instability still occurred in some hole sections with low AOI even when the zero breakout criteria was used for mud weight selection. The instability observed can be attributed to swab – decreased ESDs being exerted on the formation while pulling the bottom-hole-assembly out of the hole and time-dependent effect.
The ‘zero breakout width’ criterion is recommended for AOI less than 30°, the ‘(90°-Inclination) breakout width’ criterion for AOI between 30° and 60°, and the ‘(90°-2/3*Inclination) breakout width’ criteria for AOI greater than 60°. If the mud weight window permits, then it would be beneficial to increase the mud weight by an extra 0.2 ppg to cover swab effects in shale formations that have an extremely low AOI (&lt;15°). If not, mechanical means to prevent hydrostatic pressure drops such as slower pipe reciprocation or managed pressure drilling (MPD) need consideration.
The Redesign and Evolutive Development of Legacy Reservoir Data Management Systems – A Case Study
Authors: Pires Paulo , Gramorelli Fernanda , Nunes Fabiano , Elerati Luiz , Souza Fabio , Netto Carlos , Silva Charles , Nazareth Leandro 
Published: September 2022

Abstract
Apart from proposing fundamental changes in every part of the value chain (namely, people, processes, and technology), Digital Transformation may induce the abandonment of long-established legacy systems for new, modern technologies. However, instead of their replacement, the redesign and evolutive development of these systems might prevent negative disruption new software may cause on critical processes or routines. In this paper, the successful case of a Petrobras reservoir data management system is described. Relevant aspects related to redesign and evolutive development are discussed. The outcomes from this experience places the modernisation of legacy systems as valuable Digital Transformation strategy.
Improved Information Retrieval From Well Related Documents Using Supervised Learning
Authors: Miers Glenn , Czernuszenko Marek , Hughes Brian 
Published: September 2022

Abstract
We introduce a system for rapid retrieval of relevant well related information from a corpus of over 20 million documents. This allows for exploration workers to retrieve important business data more quickly. Tracking down all of the information required to make complex business decisions is a time consuming and error prone process. This poses a direct risk of expensive miscalculations and missed opportunities. A first version of this system is currently undergoing tests with select users. As the work here represents the first version of the system, it is expected that improvements will be made. This is a system that can be used at enterprise scale to enable searches to more easily yield usable information to workers.
This system uses a supervised learning model to identify well related documents from several categories. Examples of these categories include (but are not limited to) formation evaluation and well completion reports. A machine learning model was trained to classify documents according to input from a well document expert. This input came in the form of a set of labeled documents compiled by said expert. This model was then applied to over 20 million documents that are deemed relevant to the exploration process. The inferred classifications for each document were stored in a search engine in order to facilitate retrieval of documents by each of the labels from above. The benefits of this system are twofold. First, it reduces the number of documents that come back for a given search of a large corpus of documents. Second, it allows users without technical experience in well-related work to more easily find documents.
Production Data Analysis of Shale Oil Reservoir Using the Dynamic Drainage Pore Volume Concept: Lessons-Learned from Well-To-Well Fracture Driven Interaction in Lucaogou Shale Formation
Authors: Pan Yuewei , Qin Jianhua , Zhang Jing , Shang Jianlin , Ma Wei 
Published: September 2022

Abstract
Many pilot researches consider production gains or losses in parent/child wells in short-term thereby determining the optimal completion parameters (eg. well spacing, stage spacing). Long-term recovery varies from negative-to-positive during the post-frac-hit evaluation based on the magnitude of the pressure sink and the distance of parent/child wells. However, quantitatively analyzing frac-hits impact remains unsolved. This paper presents a novel workflow combining RTA diagnostic plots and the prediction of dynamic drainage pore volume (DDPV) to analyze the frequent well/well fracture-driven interaction (FDI) (commonly referred to as frac-hits) in the Lucaogou shale formation, Junggar Basin.
According to the published knowledge, different strategies have been employed in Lucaogou formation to minimize the negative effect and to avoid the parent/child wells (e.g cube-development). Thus, optimizing stage, cluster and well spacing in well-pad zipper-frac development is in necessity. This paper first reviews the frac-hit mechanisms in both parent/child wells and well-pad zipper-frac development. We then characterize, quantify and rank the historical frac-hit events in Lucaogou formation based on the documented data. With the prediction of DDPV using numerical integration/differentiation assisted by diagnostic plots and specialized plots in RTA (eg. flowing material balance plot, square-root-of-time diagnostic plot), the pressure sink front can be acquired. The accuracy of DDPV forecast is validated using a synthetic case study. We further apply it to three field case studies to demonstrate the versatility and applicability of the proposed workflow.
The successful applications suggest that the proposed workflow is an alternative to making field-development decisions, minimizing the negative impacts of frac-hits and thus freeing the cashflows. The outcomes are mainly but not limited to: 1) the common early departures from linear flow regime are in good alignment with the DDPV forecasts in both parent/child and well-pad development scenarios; 2) A competition of the per-well DDPV might be triggered during frac-hits in parent/child well and 3) long-term recovery in well-pad development with a tighter well-spacing might be boosted with a smaller per-well DDPV and DOI.
A Case Study of Flare Gas Reduction and Power Generation
Authors: Cottingham Byron , Bowman Zach , Kirch Paul 
Published: September 2022

Abstract
In the current energy industry, there is a strong emphasis on environmental, social, and governance (ESG). Specifically, managing the flaring of natural gas. Globally, 142 bcm of natural gas was flared in 2020. This resulted in around 265 Mt CO2, nearly 8 Mt of methane, and other GHGs being directly emitted into the atmosphere (Schulz, 2021). We have a focus of eliminating the emissions surrounding flare gas by utilizing the EPA’s Avoided Emissions and geneRation Tool.
The technology does this by utilizing a waste gas stream that would otherwise be combusted or flared and turn it into useable grid power. The waste gas stream is collected from the well and production equipment, then combusted in a natural gas generator. Power from the generator is converted to DC power, sent to a small capacitive bank, electronically synced, and sold back to the power grid using a 208 or 480v 3 phase connection. All applicable operational data is collected via sensors (power, pressures, errors, flow), stored in a database, and visualized through a website.
This paper presents and discusses a case study of using this waste gas stream technology to not only generate electricity but significantly decrease the emissions into the atmosphere through the EPAs avoided emissions tool. The first step involves identifying the appropriate pad site with stranded or flare gas volumes of at least 50 mcfd. Once a site is identified, the next step involves determining what the electrical infrastructure on location comprises and if it has 480v 3-phase power. With the location identified it is time to bring the unit on site. The unit is comprised of a natural gas generator skid and the patented technology skid. We installed a VRU and tied directly into the flare line and through a scrubber to the generator. The next step is to move the power to the proprietary technology skid unit and clean the DC power to grid acceptable AC power. We then moved the clean AC power to run the production equipment on site and the balance onto the power grid. On our case study test site, we captured 1.4 mmcf that would have otherwise been leaked into the atmosphere and generated approximately 80 MW that was sold back to the grid.
The technology presented in this paper reduced GHG emissions, provided a power source on location, and generated revenue for the operator. Our case study application would reduce GHG emission by approximately 3,400 lbs. in a one-year timeframe. The result of this technology is a new and novel technique for the energy industry to use to decrease emissions, generate onsite power, and generate revenue from selling power back onto the grid.
Autonomous Inflow Control Valves Restore Oil Production by Controlling Gas and Water Breakthrough in Acordionero Field, Colombia: A Case Study
Authors: Kearns Kent , Rios Felipe , Montero Jesus , Uzcategui Alberto A. , Fipke Steven , Molina Juan Luis , Mohd Ismail Ismarullizam 
Published: September 2022

Abstract
The Acordionero field is located in the Middle Magdalena basin of Colombia and produces from 2 main multilayered formations. Water injection is utilized to maintain reservoir pressures and improve recovery factors. API gravities vary between 14° and 24°. C&P vertical wells are drilled to access oil from several producing intervals. This inherently creates a challenging production environment, as injection water and/or formation gas can unpredictably breakthrough in any of the formation layers, impacting well performance and leading to well shut-ins and expensive workovers to re-establish production.
Even though Inflow Control Devices (ICDs) and Autonomous Inflow Control Devices (AICDs) have been successfully deployed to control unwanted fluids in oil producer wells, its application in vertical wells have been limited. The challenging environment and the inability to identify the problematic intervals led to the selection of the AICD-Valve due to its ability to autonomously shut-off gas/water based on the fluid properties of each zone. This technology is sensitive to both fluid viscosity and density and can autonomously choke zones that have higher gas/water concentrations. A detailed study was conducted, including well simulations and analysis of production data, which determined the benefits of the technology, particularly to control gas breakthrough.
A total of 6 wells have been retrofitted to date. Overall results have been positive with the AICD-Valves successfully restricting flow from intervals with unwanted fluids and applying a more effective drawdown to oil-rich zones. Gas production have been reduced to more than 50% in all wells and in some cases over 90%. The electric submersible pumps (ESPs) have shown a more stable behavior in comparison to pre- AICD-Valve installations, reducing gas locking events, leading to less common failures and well interventions. Water control is still under evaluation due to the obtained production results.
A Novel Cost-Effective Stimulation Workflow Unlocks New Perspectives for Matrix Acidizing in Fractured Carbonate Reservoir – A Case Study from Egypt
Authors: Hegazy Amr , Abdel Hakim Emad , Farouq Mohamed , Badran Hesham , Shalaby Roshdy , ElKaragi Alaa , Saleh Khaled 
Published: September 2022

Abstract
Matrix acidizing can effectively stimulate carbonate reservoirs, often resulting in skin factors on the order of –3 to –4. Wormholes can effectively connect the well with the reservoir. However, if the carbonate reservoir is naturally fractured, it will be difficult to generate dominant wormholes using conventional matrix acidizing. Hence, an effective acidizing technique is crucial to handle such heterogeneous carbonate rock, especially if the permeability contrast is vast between the matrix and fracture.
This paper exhibits a novel workflow developed by a multidomain team to reveal the true potential of the fractured carbonate reservoir in a heterogeneous complex basin in the Eastern Desert in Egypt called the GoS basin. The new logging program uses high-resolution wellbore imaging, nuclear magnetic resonance (NMR), and casedhole pulsed neutron logging technology and processing algorithms to record capture and inelastic elemental spectroscopy for matrix parameters, detailed mineralogy, and oil saturation. The output of this characterization portrayed complex challenges that prevent having defined acid distribution between the flow zones of the natural fractures and the unfractured matrix due to the permeability contrast of 130:1.
The key to success in dealing with such stimulation jobs is choosing the optimal chemical diversion, main acid treatment, pumping placement, and establishing a fit-for-purpose pumping schedule. Many experimental and laboratory tests were performed to prepare a viscous pill to be utilized as temporary isolation for the fracture or the fissures network prior to starting the full acid treatment. In addition to that, employing a passive diverter instead of an active acid-based diverter was a seamless technique to divert the acid away from each zone after pumping. The results of this novel workflow and the new acid technique indicate a sixfold increase in well productivity. The falloff analysis followed by the viscous pill reinforces the potency of the temporary isolation; this aids in treating the lower-permeability layers, which are the candidates for matrix acidizing. The applications of this novel workflow unlock the true potential of the lower-permeability reservoirs and maximize the estimated ultimate recovery.
This paper showcases our experiences with the use of this unique recipe in fractured carbonate reservoirs, and in reservoir characterization and provides lessons learned to fill knowledge gaps in this area and provide a complete workflow that can be utilized everywhere worldwide.
Success Story of Designing the First ESP-AICV Integrated System
Authors: Almusharraf Abdullah , Alghamdi Anwar S. 
Published: September 2022

Abstract
Electric Submersible Pumps (ESPs) are one of the most commonly used means of artificial lift, producing higher oil rates compared to other methods. On the other hand, Autonomous Inflow Control Valves (AICVs) have been proven effective to reduce water or gas production in high GOR wells. The objective of this paper is to address ESP design challenges when combined with AICV completion.
In AICV completed wells, reservoir parameters such as well productivity index and bottom-hole pressure may vary throughout the lifespan of the well which must be taken into consideration during ESP design. Multiple trials were attempted using ESP design models to cover optimal-case and worst-case scenarios at open and closed AICVs. Each scenario was presented with a different productivity index and bottom-hole pressure with corresponding flowrate, motor load, and motor temperature. In which, the ESP design ensured continuous flow to the surface, no gas presence at the pump intake, and sufficient flowrate for motor cooling, within acceptable pump thrust and motor load ranges.
Results have shown that following comprehensive ESP design modeling in AICV completed wells can potentially yield a resilient ESP system that can withstand dynamic reservoir conditions. It was observed that the AICV position has a direct impact on the productivity index. An open AICV increases the productivity index, whereas a close AICV reduces the productivity index. Moreover, reduction in productivity index drives down reservoir downhole pressure and pump flow rate, which increases the possibility of gas present at the pump intake and ESP motor overheating due to insufficient flow for cooling. ESP equipment was carefully selected to accommodate the fluctuating reservoir parameters. As a result, the ESP was integrated into the AICV completion and delivered the desired rates with minimal water cut and at the desired operating conditions.
This paper demonstrates a novel approach to designing ESP systems compatible with AICV technology by illustrating important factors to be considered in such complicated completions.
Fracture Conductivity Created by Proppants and Acid in the Austin Chalk Formation
Authors: Brashear A. T. , Hill A. D. , Zhu D. , Kerr E. , Scofield R. , Jordan D. , Estrada E. , Tajima T. 
Published: September 2022

Abstract
The Austin Chalk formation has seen numerous periods of active development since the early 1980's and has recently become a new focus as an unconventional resource. Due to the low permeability, fracturing, with proppant or acid, is required to economically produce the reservoir. This study presents the results of a series of conductivity tests performed to evaluate the stimulation efficiency of proppant fracturing and acid fracturing in the Austin Chalk.
The study uses both downhole core and outcrop samples. The downhole cores were from an Austin Chalk well in Webb County, Texas. The outcrop samples were collected from similar Austin chalk sub-intervals that the core samples were from and were collected from a road cut in the Del Rio, Texas area. Testing samples were prepared for the fracture conductivity tests based on API RP-61. Fracture surfaces were created either by tensile fracturing the sample, or by saw-cutting. For acid fracture conductivity, 15% HCl was injected to create acid-etched surfaces, and the effect of acid contact time was investigated. For propped fracturing, proppant size and concentration were set as study parameters. The fracture surfaces were scanned before and after each experiment in order to characterize changes in the fracture surfaces, such as acid etching and proppant embedment. Proppant size distribution was measured by sieve tests before and after conductivity measurement to evaluate proppant crushing. Closure stress up to 6000 psi was applied during the conductivity measurements, and some experiments stopped before reaching this upper limit because the sample lost mechanical integrity under a lower closure stress.
The study results show that because the mechanism of creating conductivity is different for acid fracturing and propped fracturing, the conductivities from the two stimulation methods behave differently. The initial conductivity varies but the level of conductivity at low closure stress generated from acid and proppant are similar. The conductivity from propped fracture exhibits a semi-log decline trend, with a low decline rate and sustained conductivity at high closure stress. The conductivity from the acid fracture experiments strongly depends on acid injection conditions and mechanical integrity of the rock after acidizing, indicating that design of the stimulation is critical for a successful treatment. Acid fracture conductivity in general declined more rapidly with increase in closure stress than did proppant conductivity. The observations from the experimental study revealed that both acidized and propped fractures have potential to create sufficient conductivities in the low permeability Austin Chalk formation.