bluuebunny/crossref_metadata_2025_split huggingface dataset:
Two-Way Acoustic Telemetry for Completion Installation, Control, and Monitoring
Authors: Geoffroy Gary , Werkheiser Gregory , Coffin Maxime , King Kimberly , Frosell Thomas 
Published: October 2018

Abstract
Technological advances are enabling the completion phase of well construction to evolve from interpreting surface-measured pressure and load charts to more direct communication for determining downhole activity and wellbore conditions. Bi-directional acoustic telemetry provides a method for communicating with downhole tools in real-time, where commands can be given to trigger an operational activity in lieu of traditional mechanical means, such as dropping a ball and building pressure, and in addition receive feedback that the activity has occurred.
While current completion methods have been successful using pressure and applied mechanical loads to actuate tools, there are certain scenarios where operations are difficult to execute and it can be challenging to confirm that a piece of equipment has functioned as desired. There are environmental conditions, such as high deviations and s-shaped wellbore geometry, which can be prohibitive to tasks such as getting an activating ball to gravitate to bottom and land on its seat. Using bi-directional acoustic telemetry can eliminate the need for these manual manipulations.
The aforementioned scenario has long been an issue for wells requiring sand control where the completion design might dictate deploying screens into an openhole horizontal wellbore section, performing a gravel pack for wellbore stability, and reducing the production of fines. With the growth of Extended Reach Drilling (ERD), this problem has become more common. This paper discusses adoption of proven bi-directional acoustic telemetry as a method to reduce completion time and remove some of the uncertainty in completing a well. The signal can be transmitted through the drillpipe by use of repeaters that allow for communication to extended depths. When setting a packer, receipt of the command at the hydrostatically operated setting tool triggers the setting tool to function. As a result, the packer at the top of the lower completion sets and the screens become anchored at the desired location. Bi-directional communication allows for confirmation at the surface that the signal was received and the tool properly triggered. This telemetry can further be used during the gravel packing operations to get near real-time temperature and pressure readings from washpipe gauges housed within the screen assembly.
The example documented in this paper is a novel method of deploying a gravel pack system with a bi-directional, acoustic through pipe telemetry within completion tools now in development. This method provides a platform for real-time control and monitoring in the completion environment.
Unconventional Reservoirs Next Frontier: Efficient Production Modeling
Authors: Ayoub Joseph , Krishnamurthy Shalini , Blakey Brian , Xiong Hongjie , Thambynayagam Michael 
Published: October 2018

Abstract
The operational efficiency in drilling and completing unconventional reservoirs has made impressive progress in the past few years. However, modeling the physics of reservoir production, while making progress, still requires substantial time and resources making it applicable only on a small fraction of wells. In this paper, we propose and illustrate use of a novel generation hybrid model that enable viable application on every well. In addition, it provides a practical tool to simulate as many what-if scenarios as needed to identify best solutions and to assess validity of proposed interpretation techniques. Following a brief review of the model validation and the effect of angle between fracture planes and well axis, several examples are presented to assess the impact of many factors including, flow convergence toward the wellbore, fracture-wellbore connection impairment and fracture complexity. Fracture complexity causes significant production increase during the early years of production that decreases with time but can significantly improve the return on investment. The impact on production of flow convergence and that of the fracture-wellbore connection damage is illustrated and a diagnosis method is proposed. Last, a field example history match is presented.
Water Shut Offs in Two Openhole Gravel Pack Wells, Deepwater Angola
Authors: Carragher Paul , Bedouet Sylvain , Talapatra Didhiti , Hughes Andrea , Curran John , Hou Wei , Kosi Orlando , Ralph Stan , Gao Qiang , Gracia Jesse , Galvan Jeanine , Calvert Patrick , Alcoser Luis , Dean Doyle , Mason David 
Published: October 2018

Abstract
Achieving water shut-off in gravel packed wells is challenging, particularly being able to place a mechanical barrier to flow into a gravel packed annulus. Gravel packed wells, often in deepwater environments, are often high rate wells and interventions can be costly, therefore only techniques with a high probability of success are typically sanctioned.
Many gravel pack wells are completed in multiple sands. If there are barriers between the sands that are believed to be laterally extensive, and if water is entering the lower sand, then isolating the lower sand can be a cost-effective intervention. Deepwater wells in Angola were reviewed as to whether a chemical solution or a mechanical solution would be preferred.
Providing a suitable mechanical methodology could be developed, it was felt this would provide a preferred solution. Further criteria for applying a mechanical solution were developed, to increase the chances of success. Extensive well modelling was also conducted to identify an optimum set of plugs to be placed in the well.
The operator identified a company that had an emerging technology that could offer such a solution. They then worked together to mature the technology through a series of proof-of-concept tests, through trials in Alaska, an early application in a deepwater well in the Gulf of Mexico, followed by a series of qualification tests to be ready for application in Angola. The qualification tests considered not only the mechanical configuration of the wells, but temperature, pressure and wellbore deviation. The application would require placement using a tractor, therefore testing with connecting to the relevant equipment was also incorporated in the plans for the wells.
Using a deepwater rig, several plugs were run in each well, including a meltable alloy plug. The latter plug provided a barrier to flow in both the annulus and inside the sand screens. Although not providing a barrier to shunt tubes, extensive modelling work at Cambridge university showed that it was possible to influence gravel movement in the annulus and shunt tubes, so as to maximise the pressure loss.
Two wells have had plugging systems run. The first well has reduced water cut from 100% to ca. 40% and shown a significant oil rate benefit. The second well has also shown a reduced water cut (from 70% to 40%).
New Advanced High-Performance Ultrafine Micromaterials for Providing Superior Properties to Cement Slurry and Set Cement in Horizontal Wells
Authors: Pernites Roderick , Clark Jordan , Padilla Felipe , Jordan Andrew 
Published: October 2018

Abstract
Wellbore cementing is critical for zonal isolation, bonding and supporting the casing downhole. In this paper, a novel high-performance micromaterial is presented for significantly improving the quality of the cement slurry and set cement tested in different API cements for horizontal wells. Its performance is compared to conventional Pozzolanic materials currently used in increasing cement properties. Strongly attractive for cementing horizonal wells, the innovative micromaterial provides excellent slurry stability, free water control, particulate suspension, and additional fluid loss control to superior set cement properties including high early compressive and tensile strengths, extremely low permeability, and zero shrinkage. This material offers consistently high performance and no variability of product quality as compared to Pozzolan materials that are derived as a by-product of coal burning.
The key novelty and invaluable contribution of this research to the field is the application of a unique high-performance micromaterial that can deliver multiple desirable properties in both slurry and hardened cement. With the illustration of the material giving many good surprising properties, the cement design can be optimized by reducing the dosage of several cement additives in the admixture, giving potential cost savings to service companies or operators. During our investigation, the new material does not require an additional chemical to activate its unique functionality.
A Black-Oil Approach to Model Produced Gas Injection for Enhanced Recovery of Conventional and Unconventional Reservoirs
Authors: Du Fengshuang , Nojabaei Bahareh , Johns Russell T. 
Published: October 2018

Abstract
In this study, a fast and robust compositionally extended black-oil simulation approach is developed, which is capable of including the effect of large gas-oil capillary pressure for first and multi-contact miscible, and immiscible gas injection. The simulation approach is used to model primary depletion and gas flooding in a high-permeability reservoir using a five-spot flow pattern for different reservoir pressures. The comparison with fully-compositional model shows good agreement. For an initially undersaturated reservoir with both injection and production wells pressures above the original bubble-point pressure, gas evolves near the injection well and it later breaks through the production well as produced gas is injected. Additionally, the primary depletion and huff-n-puff gas injection in tight shale reservoirs by using the compositionally extended black-oil model indicates that the effect of large gas-oil capillary pressure on recovery becomes smaller as reservoir pressure is higher. Finally, a dynamic gas-oil relative permeability correlation that accounts for the compositional changes owing to the produced gas injection is introduced and applied, and its effect on oil recovery is examined.
Select Naphthenic Acids Beneficially Impact Oil-Water Dynamics During Smart Waterflooding
Authors: Reilly Teresa , Medina Bryan , Lehmann Teresa , Alvarado Vladimir 
Published: October 2018

Abstract
Injection of a generic naphthenic acid blend in waterflooding experiments has been shown to enhance oil recovery. A brine-oil interfacial response upon addition of organic acids has also been recorded and linked to the improved recovery response. The purpose of this work is to analyze the effect of several individual naphthenic acids on the oil-water interface and thereby determine which structure of acids is most potentially influential in improving oil recovery. Acids were selected based on water solubility and structure; analyses were conducted on several molecular structural characteristics to assess the relationship to interfacial responses. Based on the observed fluid-fluid interactions and the likelihood that the acid blend in previous work contained some of the acids studied, we propose a causative connection between the addition of organic acid blends and the recovery efficiency.
Data-Driven Prediction of In-Situ Combustion Dynamics
Authors: Ogunbanwo Olufolake , Koh Yoo Kuy Hun , Gerritsen Margot , Kovscek Anthony R. 
Published: October 2018

Abstract
This paper presents a new workflow for the simulation of in-situ combustion (ISC) dynamics. In the proposed method, data from kinetic cell experiments, depicting the combustion chemistry, are tabulated and graphed based on the isoconversional principle. The tables hold the reaction rates used to predict the production and consumption of chemical species during in-situ combustion.
This new method of representing kinetics without the Arrhenius method is applied on one synthetic and two real kinetic cell experiments. In each case, the new method reasonably captures the reaction pathways taken by the reacting species as the combustive process occurs. A data-density sensitivity study on the tabulated rates for the real case shows that only four experiments are required to capture adequately the kinetics of the combustion process. The results are, however, found to be sensitive to the size of the time step taken. The method predicts critical changes in the reaction rates as the experiment is exposed to different temperature conditions, thereby capturing the speed of the combustion front, temperature profile, and fluid compositions of a simulated combustion tube experiment.
The direct use of the data ensures flexibility of the reaction rates with time and temperature. In addition, the non-Arrhenius kinetics technique eliminates the need for a descriptive reaction scheme that is typically computationally demanding, and instead focuses on the overall changes in the carbon oxides, oil, water and heat occurring at any time. Significantly, less tuning of parameters is required to match laboratory experiments because laboratory observations are easier to enforce.
Field Demonstration of a New Method of the Automation of Continuous Circulation Drillpipe Connections
Authors: Johnson Rachel , Luo Yan , Grace Christopher , Milne Adam 
Published: October 2018

Abstract
Continuous circulation technology is used to maintain constant circulation of drilling fluid in a well by enabling the rig pumps to remain on during all steps of the drillpipe connection process. Continuous circulation is a managed pressure drilling (MPD) technique; it improves drilling success for difficult high-pressure high-temperature (HPHT), narrow pore pressure/fracture gradient, and extended reach horizontal wells.
Traditionally, a continuous circulation system relies on a manifold connected into the rig standpipe, which diverts flow to and from the topdrive to a side port on a sub that is threaded into the top of each drilling stand. Historically, this side port flowline is connected manually by an operator, within the rig floor red zone, in a single barrier pressure environment. To enhance safety by removing exposure to any single barrier pressure applications, a new system was developed that automates and enhances the current manual process.
The automated continuous circulation system includes a connection tool that is mounted on a manipulator arm; after it is delivered to the drillstring and clamped, it will use a human machine interface (HMI) to automatically and remotely remove a threaded side port safety cap, connect the side port flowline, and control the manifold flow diversion process. The system is controlled at the HMI by an advanced software system that is capable of functioning autonomously, with operator verification steps. Internal robotic mechanisms drive the system to perform the exact steps as a human without requiring modifications to the proven continuous ciruclation sub design, all while providing instantaneous feedback to the operator located at the remote HMI.
A prototype tool was assembled and successfully tested in November 2016 in the Val D'Agri oilfield region in southern Italy. With a rapid technical development cycle of less than one year in a down market, a commercial tool was developed and deployed, including the implementation of all lessons learned. This system is the first in the industry to provide threaded engagement of the side port flowline, and a successful undermount delivery arm. This paper presents results from more than 1,000 diversion connections in both laboratory and field environments.
With a 10-year track history of the manual system, the automated system enables the operator to improve upon proven technology to safely deploy continuous circulation capabilities in offshoreapplications, from fixed platforms to floaters, in areas with strict industry certification regulations, personnel in red zone limitations, and double pressure barrier requirements. The system reduces overall added connection time from typical manual systems, increases safety, and maintains the benefits of continuous circulation to reduce nonproductive time (NPT) and total drilling days.
Drill Faster Wells by Transmitting Torque From the Strongest Power Sections to the Most Reactive Formations
Authors: Moisan James , Chapman Christopher , Marchand Nicholas , Smith Roger , Skyles Lane 
Published: October 2018

Abstract
Drilling Operators are continually striving to reduce the drilling cost of every well. Reducing the drilling cost can come from improved performance of the downhole motor. Power sections with even wall rubber technology have provided the latest step change in performance of these downhole motors. These power sections deliver higher torques than conventional rubber lined stators; without a loss of performance in other areas. However, delivering the higher torques from the power section to the drill bit requires new torque transmission technology in the lower end of the motor. The following paper will discuss a new technology utilized to transmit these higher torques. It also includes the developmental history of downhole motor power sections.
Modeling and Data Analytics Workflow From Delineation to Development: A Case Study Utilizing Limited Data in the Extensional Deep Dry Utica Shale Play of Pennsylvania
Authors: Passman Andrea 
Published: October 2018

Abstract
The Deep Dry Utica, also known as the Extensional Utica, is a newly recognized shale play in Pennsylvania and West Virginia. The most developed part of the dry gas Utica shale, in Monroe County, OH, is an inexact analogue as it shares limited characteristics with the Deep Dry Utica to its east. Unconventional workflows based on analogue plays often rely on the statistical significance of trends, impossible to exploit when each data point in a new play is unique, and results are unrepeatable. With only the data from a handful wells in the public domain, and a few wells being drilled by operators where the data is still private, understanding the reservoir and geologic complexity of the Deep Dry Utica has eluded most operators. The play has seen early successes and failures, with wells exceeding initial production rates (IP) of 60 MMcf/day and wells so difficult to drill that they were unable to be completed due to financial limitations. Thus, structurally complex shale plays like the Deep Dry Utica with limited data require a new methodology to rapidly move from delineation to development mode. With a limited heterogeneous data set, subsurface modeling and data analytics in conjunction with analogue analysis allow operators to rapidly understand performance indicators, optimize location selection, well spacing, horizontal drilling and completion designs.
This paper describes the modeling and analytics-based workflow utilized to unlock commercial viability of the Deep Dry Utica, making the play commercially competitive with Marcellus Shale development. The workflow described in this paper utilizes earth modeling, reservoir and completion modeling and contemporary data analytics techniques to accelerate development. The workflow is demonstrated in a case study from the Deep Dry Utica in Pennsylvania, moving from delineation to commercial development, with less than a dozen data points across 500,000 thousand acres.
A New Look at Sealing with Bismuth and Thermite
Authors: Carragher Paul , Fulks Jeff 
Published: October 2018

Abstract
Annular gas migration through micro-annuli in cement, or casing vent flow, is a common issue over the life of a well. This results from poor cement jobs or porous cement that cannot successfully prevent gas flow from creating channels while curing. Remediating this through traditional practices of perf and squeeze or section milling is often expensive and unreliable. This paper will demonstrate a new way to create gas tight seals in casing annuli, minimizing the chance a well will experience casing vent flow by overcoming the limitations of cement in gas environments. This solution can be implemented at any stage of the well but is most effective when utilized as part of the original well construction.
The Best Practices and Approaches for Replication of Achimov Formation Development Technologies
Authors: Nenasheva Marina , Okunev Maxim , Sleta Natalia , Timirgalin Azamat , Zhukov Vladislav , Garenskikh Dmitriy , Volkov Georgy , Priklonsky Oleg 
Published: October 2018

Abstract
The paper presents an analytical review of approaches to the development of the Achimov deposits and its foreign analogues. The purpose of this study was to identify key drivers that determine the success of developing low-permeability reservoirs with a highly heterogeneous both horizontally and vertically.
The first part of the work is devoted to the review of technological solutions used in foreign analogues fields. During preliminary screening of open sources, about 20 deposits of similar genesis or reservoir properties with Achimov deposits were allocated. For further consideration of technological solutions, a more detailed examination of each of the supposed analogs was made according to a set of key criteria, as a result of which 8 formations were singled out.
The second part was devoted to a retrospective analysis of the development of Achimov deposits in licensed areas of Gazprom Neft. To determine the optimal technological solutions, the whole stock of wells in the Achimov deposits was analyzed.
The analysis of publications on foreign analogues, allowed to allocate a pool of technological solutions in the field of completion of wells and hydraulic fracturing of the formation. An approach to a comparative analysis of the efficiency of the applied technologies was proposed.
In the course of a retrospective analysis of the technological operations carried out in Gazprom Neft on the Achimov wells fund, statistics were collected on the productivity, the initial well performance indicators, the parameters and the number of fracturing per well, the type of completion. The collected statistics was analyzed for the search for obvious and non-obvious dependencies, to identify key drivers of the effectiveness of Achimov deposits development. This analysis made it possible to identify the most optimal "historical" technological solutions, the mutual influence of technological parameters, as well as to identify hypotheses on the most effective involvement in the development of Achimov deposits for further verification in the pilot works.
In this work, a generalization of Russian and foreign experience in the development of Achimov deposits and its analogs was carried out. Based on the results of this work, hypotheses were generated on key drivers of Achimov deposits development effectiveness, as well as a pool of technological solutions for further testing the effectiveness of technologies within pilot work.