bluuebunny/crossref_metadata_2025_split huggingface dataset:
Technology Screening & Selection for Site Specific, Adaptive and Cost Effective MMV Planning & Design
Authors: Das Debasis Priyadarshan , Tiwari Pankaj Kumar , Patil Parimal Arjun , Chidambaram Prasanna , Jordan Leite Renato , Ebinining Amir M Syafeeq , Tewari Raj Deo , Baharuddin Salina , A Hamid M Khaidhir 
Published: September 2022

Abstract
Carbon Capture & Storage (CCS) has globally been recognized as the way forward to manage & reduce Green House Gas (GHG) emissions. However, for every geological CO2 storage project there are two inherent yet independent storage risks: loss of containment and loss of conformance. For early detection and mitigation of these risks, a robust Monitoring, Measurement and Verification (MMV) plan is of supreme importance. While several matured, newly developed and under trial monitoring technologies addressing various aspects of MMV are currently available but it's crucial to evaluate them in terms of applicability, durability, ease of operation & maintenance, and cost to the project. This study focuses on the screening and selection monitoring technologies to achieve a site-specific, adaptive, and cost-effective MMV plan and design.
Identification of critical containment & conformance risks were achieved through integrating information from various elements viz. CO2 plume migration forward modeling, 3-way coupled modeling, well integrity analysis, overburden risk analysis, CO2 marine dispersion modeling, environmental impact assessment (EIA), regulatory requirements, etc. Based on identified risks, the specific MMV elements were selected along with designing of their scheduling and frequency. Subsequently, an inventory of all available technologies addressing explicit MMV needs was prepared. These technologies were put through rigorous analysis on their capability of detection, operability, tool/technology longevity, availability, and associated costs. High-ranking technologies were then knitted for the final MMV planning & design.
As a part of the arduous screening, permanent ocean bottom (OB) monitoring technologies were analyzed and some of the alternate low-cost technologies surfaced that can cater to continuous and long- term data acquisition needs. Knitting of 3D Distributed Acoustic Sensor – Vertical Seismic Profile (DAS- VSP) hybrid with 3D seismic surveys would help optimizing the logistic requirements and reducing cost of monitoring survey acquisition over the project lifecycle. During the entire screening and selection process, Multi-Fiber Optic Sensor System (M-FOSS) technology emerged as the leading monitoring technology, which is cost-effective, easy to operate and has the flexibility to be deployed at well and/or on seabed. An exhaustive inventory of available/emerging MMV technologies and the cost versus benefit matrix was developed that can be used for MMV planning and design across CCS projects. The study focuses to streamline the long-term sustainability of the adapted MMV planning to enhance the project economics by ensuring the optimum value propositions of implemented technologies.
Best Practices in DFIT Interpretation - Comparative Analysis of 83 DFITs in the Canadian Duvernay Shale Play
Authors: Virues Claudio , Robertson Alexandra , AbouKhalil Emile 
Published: September 2022

Abstract
In September 2021, the Alberta Energy Regulator (AER) through a new pressure and deliverability testing directive issued new guidance for minifrac tests, also known as diagnostic fracture injection tests, to align with the current practice for conducting these tests. This paper statistically summarizes results from 83 of these DFITs, submitted by many operators from the Canadian Duvernay shale play. The main parameters analyzed were closure, reservoir pressure and permeability.
This newly updated directive sets out requirements for pressure and deliverability tests. In the development of tight or unconventional reservoirs, industry moved towards horizontal wells with multistage fracture treatments using a minifrac (also referred to as DFIT or diagnostic fracture injection test), which became the more common well test in determining closure, initial reservoir pressure and permeability. In this paper, a comparison of holistic vs compliance methods descriptions for closure pressure are provided. Complete governing equations for after closure analysis methods are described in detail to permit readers to replicate all results on reservoir pressure and permeability.
For closure pressure, the compliance model is compared to the holistic model that is published or commercially available. Comparisons are also provided for After Closure Analysis (ACA) models including the Soliman and Nolte methods as far as reservoir pressure and permeability are concerned. 83 field case studies are presented for horizontal wells in an unconventional shale play. The most significant findings are 1) a compliance closure pressure signature is not apparent in the analyzed DFITs, 2) closure pressure estimates, and outcomes are similar for the compliance and holistic methods 3) reservoir pressure determination differentiation using either linear or radial flow 4) PVT impact on interpretation and 5) order of magnitude difference for permeability determination on After Closure Analysis methods. The findings have direct practical implications for operators in the Canadian Duvernay shale play and analogous shale plays in USA and elsewhere. Accurate permeability estimates are needed for calculating effective fracture length and for optimizing well spacing and fracture design. Accurate closure pressure is fundamental to hydraulic fracture design and other geomechanics applications. Accurate initial reservoir pressure is important because it could be used for input for Rate Transient Analysis (RTA) for resources / reserves assessments in similar unconventional plays.
The novelty of the comparative analysis is in the ability to show in unconventional shale plays how closure pressure methods compared, and the implications of using different after closure analysis methods which could be of significant benefit to a practicing engineer or well testing interpreter
Innovative Applications of Oil Soluble Tracers in Unstimulated & Stimulated Multi-Stage Horizontal Wells for Long Term Flow Assurance and Production Monitoring
Authors: Ramanathan Venky , Mombourquette Cole , Martinez Alberto , Borschneck Sean 
Published: September 2022

Abstract
Sliding sleeves have been an integral part of horizontal multistage completions, however intelligent sleeves that provide reservoir insights were missing or cost prohibitive. This led to the innovative development of integrating oil soluble tracer applications with sleeve technology to provide superior completions and reservoir diagnostics. Conceived to validate flow in unstimulated wells / stages, the longevity and value of the data collected led to extending this application for long term flow assurance monitoring of unstimulated and stimulated wells.
Spinner based production logging techniques require intervention and have limited capability in wells with artificial lift. Tracer sleeve integration requires zero intervention and builds on the back of proven tracer diagnostics, and field proven sleeve technologies. A winning combination for production operation optimization.
The monitoring feature is especially useful in wells that are put on production prior to stimulation. These applications effectively allow for flow assurance and production profiling between unstimulated and stimulated traced stages. Fluid samples are collected at surface for a period of several months, over which time trend fluctuations in tracer concentrations are monitored and evaluated.
Reservoir intelligence that production engineers can act on is now available at their fingertips. With more than two-hundred-fifty (250) installations on multiple wells during the first year of application, tracer sleeves have become part of the standard operating process. Results obtained over a multitude of study wells have indicated that tracer sleeve technology provides effective monitoring of both the relative flow contribution, and flow assurance of each traced stage for the subject wells. Studied wells were monitored for periods no shorter than three (3) months following initial production, and in most cases continued to display detectable readings from tracer sleeves well over nine (9) months. This has also led to lower intervention costs and limiting the number of interventions to wells that show unsatisfactory tracer concentrations. In conclusion this diagnostic approach has provided validation and insight for wells or regions of a lateral where previously, flow contribution and productivity were assumed.
The introduction of oil soluble tracers into production sleeve technology has allowed for short- and long-term diagnostics (flow assurance and production monitoring) of hydrocarbon contribution in unstimulated and stimulated regions of horizontal multi-stage wells in a hybrid completion. A superior diagnostic solution where cost prohibitive or intervention options were the only available alternative.
Iron Sulfide Scale Inhibition Through Adsorption of Chelating Agents
Authors: Gasimli Nijat , Mahmoud Mohamed , Hassan Amjed , Shahzad Kamal Muhammed , Patil Shirish , Al-Abdrabalnabi Ridha 
Published: September 2022

Abstract
An important oilfield issue is the formation of a wide range of scales during oil and gas well operations. Oilfield scales hinder assessing an optimum hydrocarbon production as their precipitation on formation, various surface, and downhole equipment leads to many problems, including pressure decrement, formation damage, and operational failure of subsurface equipment. One type of these scales is the iron sulfide scale and based on studies in the Khuff reservoir, iron sulfide scales are likely to deposit on production tubing and rock formation. Therefore, it becomes essential to restrain the occurrence of iron sulfide scale using environmentally friendly chemicals in production tubing, water injection wells, and near-wellbore formation.
The primary focus of this work is the prevention of iron sulfide scale deposition in carbonate formations during water injection applications. Iron sulfide scale inhibition was studied through dynamic inhibition adsorption experiments. In contrast to conventional experiments, for scale inhibition and adsorption of chelating agents (static bottle, dynamic filter tube tests) and simulation studies, a novel experimental setup (coreflooding experiments) was proposed to study the inhibitor adsorption. Broad concentrations of high-pH aminocarboxylic acids (such as ethylenediaminetetraacetic acid (ETDA) and diethylenetriamine pentaacetate acid (DTPA)) were examined (10 wt%, 15 wt%, and 20 wt%), at temperatures of 120°F and 200°F.
Results of the study revealed that iron (III) precipitation is an obvious threat causing severe formation damage in carbonate rocks by significantly decreasing the rock permeability. Adsorption of chelating agents on limestone rocks highly depends on their concentrations. Specifically, an increase in the concentration of EDTA and DTPA at elevated temperature conditions resulted in higher adsorption. The inhibition experiments revealed that 20 wt% EDTA could significantly decrease the iron sulfide scale precipitation.
Unlike the conventional testing methods for scale formation and prevention, a novel experimental setup - coreflooding during the inhibitor adsorption, formation, and inhibition of iron sulfide scale in carbonate formation was used. The main advantage of the method is the consideration of permeability alteration happening due to the scale formation. Another point is that in previous studies, various scale control chemicals and experimental approaches have been suggested for iron sulfide scale inhibition, and polymeric, phosphonate, and sulfonated co-polymeric inhibitors were used. However, the subgroup of chelating agents - aminocarboxylic acids, was used in this study.
Online Flow Assurance Tool for Optimum Wax Management at Field
Authors: Bhaskoro Petrus Tri , Anuar Astriyana , Rasib Amira A , Wollebaek Lars , Rezvany-Hesary Farnaz , Lutro Henrik , Henriksson Johan , Sariman Mior Zaiga , Shafian Siti Rohaida M , Torres Carlos Francisco 
Published: September 2022

Abstract
Traditionally, a field's wax management and operating philosophy have been developed by conducting a rigorous Flow Assurance (FA) study. Optimization at field level warrants the study to be updated from time to time to reflect the actual field performance. This accounts for overall field performance but does not incorporate variations due to operational changes. Rather, the operating philosophy is based on representative scenarios where conservative measures are often used to safeguard operations. With the increasing number of waxy crude oil pipelines within company that demands immediate attention, an online prediction/monitoring tool that quickly adapts to operational changes is one important enabler, not only to optimize operations and address the huge Operating Expenses (OPEX), but also to address remote/unmanned operation's requirement especially for subsea operation. Unfortunately, to date, such a tool is not commercially available or deployed widely. To address this gap, this paper aims to present the Online Wax Smart Meter development concept and to showcase the performance of an online wax monitoring tool which enables fast and optimum wax management.
Novel Dual Completion Architecture Improves Oil Production and Boosts Secondary Recovery with Minimal Surface Footprint
Authors: Leon Fernando , Silva Angel , Villalobos Jorge Luis , Guerrero Ximena , Amores David , Villarreal Alejandro , Cuenca Dario , Cuenca Diego , Jaramillo Dorian , Corella Byron , Perez Mauricio 
Published: September 2022

Abstract
The novel dual electric submersible pump (ESP) completion was designed to maximize oil recovery by improving waterflooding efficiencies while minimizing capital expenditures (capex) and surface facilities. The design enables the operator to produce oil and formation water from the same well. The injection of water, produced from the same oil producer, is part of a waterflooding project to boost secondary recovery.
Based on the dual concentric completion (DCC) concept, this novel solution integrates an inverted flow architecture to provide the upper ESP with direct access to the lower reservoir zone, which is the water-producing zone. This single ESP is then used as the only equipment to lift the produced water and then provide sufficient pressure for direct injection into a neighboring well, without the need for surface treating and handling facilities. Oil production is lifted by the encapsulated lower ESP. The complete solution includes a monobore anchor with an automatic release tool to eliminate oil-zone damage during the completion phase and maximize water-zone productivity.
The upper reservoir expected to produce approximately 700 BOPD with 1% water cut; after the successful implementation and commissioning of this novel architecture and its impact on the secondary recovery process, the recorded production reached more than 1,000 BOPD, with an overall 35% oil production increase in the field.
Using a monobore anchor with an automatic release tool to perforate the lower sand allowed to combine the underbalance technique with clean perforations system and high impact penetration charges, which resulted in greater water zone productivity and improved pump efficiency, reducing power consumption by 33%. Considering that the project was implemented with a local diesel generator, the total CO2 emissions reduction was approximately 700 metric tons per year in just one well.
Because the novel inverted DCC solution does not require the construction of traditional surface facilities for water injection, which include horizontal pumping systems (HPSs), capex was significantly reduced. In addition, because this solution was developed, designed, and implemented in far less time than a traditional method would have been, production was increased earlier than otherwise possible, helping the operator meet production targets and increase cash flow.
An Integrated Method to Mitigate Hazards from Hydraulic Fracturing-Induced Earthquakes in the Duvernay Shale Play
Authors: Hui Gang , Gu Fei , Chen Zhangxin 
Published: September 2022

Abstract
In recent decades, a remarkable increase in induced seismicity in the Western Canada Sedimentary Basin (WCSB) has been largely attributed to the hydraulic fracturing (HF) operations in unconventional plays. However, a mitigation strategy concerning geological, geomechanical, and operational susceptibilities to HF-induced seismicity has not been well understood. In this work, an integrated method is proposed to mitigate potential risks from HF-induced seismicity in the Duvernay play near Crooked Lake. The geological susceptibility to induced seismicity is evaluated first from site-specific formation pressure, a distance to the Precambrian Basement, and the existence of pre-existing faults. The regional in-situ stress and rock mechanics are then assessed to determine the geomechanical susceptibility to induced seismicity. Next, the operational susceptibility is determined by comparing induced seismicity with operational parameters such as total injection fluids and proppant mass. Finally, a multiple linear regression (MLR)-based approach is proposed by considering the feature importance of different parameters. It is found that regions with a low formation pressure (&lt;60MPa), a great distance to the Precambrian Basement (&gt;260m), a low minimum principal stress (&lt;70MPa), and a low brittleness index (&lt;0.62) tend to be seismicity-quiescent regions. Three new horizontal wells are drilled and fractured to validate the applicability of our MLR-based approach. High-resolution monitoring results indicated that 95% of the induced events had a magnitude of less than 2.0 during and after HF operations (three-month time window and five-kilometer well-event distance), among which the maximum magnitude reached M3.05 (&lt;red light magnitude M4.0). Therefore, the MLR-based approach was successful in mitigating potential seismicity risks, which can be applied to other regions to guide seismicity-free fracturing operations in unconventional plays.
Microwave-Assisted Catalytic Heating for Enhanced Clean Hydrogen Generation from Methane Cracking in Shale Rocks
Authors: Yan Keju , Yuan Qingwang , Jie Xiangyu , Li Xiaoqiang , Horita Juske , Stephens Jacob 
Published: September 2022

Abstract
Steam methane reforming (SMR) technology generates about 95% hydrogen (H2) in the United States using natural gas as a main feedstock. While hydrogen is clean, the process of hydrogen generation via SMR is not, as it emits about 10 times more carbon dioxide (CO2) than hydrogen. The CO2 has to be captured and sequestrated in reservoirs or aquifer systems, which is costly. A revolutionary approach is to generate and extract hydrogen directly from petroleum reservoirs by taking advantage of the abundant unrecovered hydrocarbons in reservoirs. This approach does not involve natural gas production, transportation, or refinery. Meanwhile, the CO2, if generated, will be sequestrated simultaneously in reservoirs without being produced to surface. This approach is therefore potentially low cost and environmentally friendly. In this paper, we propose to use microwave-assisted catalytic heating to enhance methane conversion to hydrogen within shale gas reservoirs. To validate this concept, we conducted a series of experiments to crack methane streams flowing through shale rock samples and powders in a microwave reactor. With silicon carbide (SiC) as the microwave receptor, the temperature of shale samples can quickly reach to above 700 °. The methane conversion efficiency is up to 40.5% and 100% in the presence of Fe and Fe3O4 catalysts at the measured temperature of 500° and 600 °, respectively. Interestingly, the presence of shale is favorable for methane cracking at a relatively lower temperature compared to the case with the same weight percentage of SiO2 in heated samples. The thermal decomposition of carbonate in shale rocks also benefits the improvement of permeability of shale. The influences of different shale weight ratios and methane flow rates are also investigated.
Overall Enhanced Surveillance and Production Delivery Strategy: The Backbone of Oil Production Sustainability at Country Level in Malaysia
Authors: Bakar Hasmizah , Mohd Khalid Ruzanna , Idris Khairul Nizam , Borhan Nor Aisyah , Masoudi Rahim , Abu Bakar Mohamad 
Published: September 2022

Abstract
While the world is still reeling from the unprecedented challenges brought on by the pandemic, the energy sector remains focused on business continuity standpoint. It is a big challenge for Enhanced Value Optimization (EVO) taskforce, as appointed focused group in PETRONAS Malaysia Petroleum Management (MPM) to monitor and assure national production target delivery for all hydrocarbon resources in Malaysia. The focus was devotedinto oil fields in Malaysia. As regulator, it is crucial to quickly act to implement and adjust regulations & steers to meet new demands for safe operations during global pandemic. Several work streams have been lined upwith specific goals and indicators to manage the upside potentials and risks for late life reservoirs, well integrity issues, new oil project, unplanned deferments, production enhancement and idle wells reactivation activities. Through regular engagements with operators, Opportunities and Threats (O&T) are collectively registered and tracked in monthly Malaysia oil production conversation to generate short-term and long-term additional potentials and trigger any constraints to base production in advanced. This paper will also discuss on the limitation of resources, operational window, Malaysian government enforcement for isolation & quarantine during pandemic high time, widespread budget reprioritization, probability of success for execution of activities to realized opportunities and mitigation plans to mitigate threats from both sides, regulator and operators. In improving production performance conversations with operators, EVO Command Centre leverages on PETRONAS UP Mobile Application and UP Web with desired solution and integration from various data reporting dashboard as communication for quick business decision platform. The value of EVO as special taskforce in MPM for more just a reporting medium comes through intensification of efforts and proactive management of overall oil assets to realize business production target. The authors would also like to share their experienceas devoted Shapers and Enablers to safeguard Malaysia production target that may inspire other petroleum authorities in transforming the ambition(s) into action.