bluuebunny/crossref_metadata_2025_split huggingface dataset:
Technology Focus: Bit Technology and Bottomhole Assemblies (December 2018)
Authors: Mensa-Wilmot Graham 
Published: December 2018

Technology Focus
Rock characterization, with regard to determination of mechanical and geologic properties, is critical for performance drilling. This consideration ensures appropriate offsets analysis. Additionally, it promotes several benefits in project planning and execution, with regard to bottomhole-assembly (BHA) design and compliance analysis, drive-system evaluations, bit selections, hydraulics considerations, drilling-parameter ranges, and anticipation of operational dysfunctions. Performance drilling, when deployed holistically, contributes to cycle-time and project-cost reductions.
In most instances, hardness is considered to be the most critical rock property in bit-selection discussions. Field performances, and results from this classification, have not been consistent with this claim. Recent research shows that, in addition to hardness, other rock properties, such as lithology types, heterogeneity, and abrasiveness, have equal importance in bit evaluations. Consequently, the discussion must move from rock-strength analysis to rock-drillability analysis, which is more inclusive.
BHAs must achieve their expected functional roles without creating vibrations or conditions that compromise project success. Vibration events commonly have been tied to BHAs or drill bits. Efforts aimed at addressing vibration challenges through bit and BHA changes have not produced the desired results. Researchers have identified additional influences (e.g., drilling parameters, drilling fluid types, rock-drillability factors, stabilizer types and geometries, reamers, wellbore trajectory, and drive systems) that also serve as vibration sources. Consequently, strategies or solutions aimed at addressing vibration challenges must target their sources to ensure effectiveness of such solutions.
Performance consistency, aided by effective bit-wear predictions, promotes cycle-time reduction. Improvements in rock-drillability analysis, bit selection, BHA design, drilling-parameter selections, and vibration remediation, coupled with the industry’s advancements in downhole-tool development and data analytics, must ensure appropriate monitoring and prediction of bit wear. Research must delve into the different bit-failure modes—wear and impact, different wear stages, and the totality of factors that drive the wear process.
Recommended additional reading at OnePetro: www.onepetro.org.
IADC/SPE 189697 Real-Time Downhole Data Resolve Lithology-Related Drilling Behavior by Christopher Viens, Nabors Drilling Solutions, et al.
SPE 187445 Real-Time Bit-Wear Prediction Using Adaptive Data Analytics by Vikrant Lakhanpal, University of Houston, et al.
SPE 188427 Experimental Investigation of the Effects of Rotational Speed and Weight on Bit on Drillstring Vibration, Torque, and Rate of Penetration by Vimlesh A. Bavadiya, University of Oklahoma, et al.
Controlled Source EM to Monitor Steam Injection in the Ratqa Heavy Oil Reservoir
Authors: Cuevas Nestor , El-Emam Adel Hassan , Al-Jenaie Jarrah , Hafez Mohamed , Ceci Federico , Pezzoli Mauro 
Published: December 2018

Abstract
Numerical studies are presented to evaluate the sensitivity of surface and surface to borehole Controlled Source Electromagnetic (CSEM) methods, to monitor the evolution of a steam plume injection in EOR for the Ratqa heavy oil reservoir, in North Kuwait.
A surface CSEM dataset collected over a pilot area in 2011 was used to determine a baseline 3D model of electrical resistivity at reservoir depth. To this end, the data underwent constrained 3D inversion, incorporating a-priori information from resistivity well logs and seismic horizons and focusing the inversion within the reservoir. The resulting 3D model provided high resolution of the lateral and vertical distribution of electrical resistivity within the reservoir, which was further verified by comparison with direct interpolation of well log data available over the entire area of the survey. Perturbations of the reservoir resistivity were then introduced by arbitrarily lowering the resistivity in a thin disk defined around a test wellbore, such as to represent a steam plume homogeneously expanding away from the borehole. Datasets were then numerically simulated to determine the expected response of EM measurements performed by surface deployed receivers and excited by sources deployed both on the surface and in the borehole, within the reservoir section. It was found that surface CSEM data could be used to recover the resistivity anomaly produced by the steam injection, provided that the injected steam generates a plume with a radius &gt; 60. Smaller plumes produce a surface response which was close to the measurement's noise level expected in a 4D time-lapse survey. A STB-EM configuration was found to yield a strong sensitivity of the response even for radius of the plume &lt; 20m.
At the outset the analysis presented here shows that resolution of surface based deployments is low, but they can be used to determine large scale variations within the reservoir. Novel and recently developed STB-EM technologies can yield the resolution required of the length scales variations expected in EOR processes.
Benchmarking Of Heavy Oil Fields: A Tool for Identification of Opportunities for Total Cost and Production Optimization
Authors: Ortiz-Volcan J. L. , Al-Khamees W. , Ahmed K. 
Published: December 2018

Abstract
This paper presents a practical method for benchmarking heavy oil fields as a tool for identification of opportunities for total cost and production optimization. The method combines actual data from typical heavy oil fields to define reservoir, well and surface complexity indices, for categorizing a subject field and a total cost breakdown model to map potential risks that could cause total cost to increase, potential project/process delay and poor production performance.
The benchmarking process consists of four steps: 1) classification of a subject field using Front End Loading (FEL) and complexity indices that account for: a) reservoir structural, stratigraphic, rock, fluid, energy, static and dynamic complexity, b) well complexity and c) surface processes complexity; 2) selection of analog fields within the range of indices; 3) use of causal maps to identify causes of uncertainty and risks that impact capital expenditures (CAPEX), operational expenditures (OPEX), production losses and cycle time; and 4) a total cost stochastic model is used to generate graphs providing the position of the subject field vs. analogs.
A total undiscounted cost breakdown structure provided information on the most critical cost drivers, where significant impact corresponded to OPEX. Causal maps described typical total cost drivers for surface and subsurface. Seven most significant groups of risks are modeled to visualize the impact on cost, production losses, cycle time and health, safety and environment with recommended mitigation actions ranked by cost benefit.
A database provides information about cost of production (Capex, Opex) from heavy oil fields undergoing cold production and thermal enhanced oil Recovery well-known heavy oil production areas from Venezuela, Canada, USA and Middle East.
Heavy oil fields undergoing thermal enhanced oil recovery indicated typical ranges for Opex from 2 to 22 USD/bbl and Total Cost ranges from 10 to a maximum of 40 $/bbl. A key observation is that cost of fuel and power is the largest single OPEX cost for thermal enhanced recovery accounting for about 50%. Significant production losses are associated to failures due to corrosion and blowouts is the most significant HSE risk.
The proposed method helps benchmarking total costs in heavy oil fields, which is a task that requires lot of efforts in researching available reliable sources from technical papers, regulatory agencies, and oil industry.
Understanding causes of high cost per barrel and their relationship with uncertainties and risks for heavy oil field, is a formidable tool for multidisciplinary cost optimization as it provides a common language that understood by all disciplines involved.
Laboratory Experimental Study on New Polymer in Xinjiang Lukeqin High Temperature and High Salt Reservoir
Authors: Wang M. , Xiao Q. , Gou Y. , Deng F. , Wang B. , Zhang D. 
Published: December 2018

Abstract
The Lukeqin Triassic reservoir in Xinjiang, China, is a heavy oil reservoir with high temperature and high salinity. The formation conditions are harsh. With the deepening of oilfield development, the reservoir enters into a high water cut period and faces the problem of stable oil and water control in the middle and late stage of development. In addition, the heavy oil reservoir has complex characteristics, such as deep, thin, thick and so on, so it can not be converted to conventional thermal recovery mode. Therefore, a solution to the reservoir conditions is urgently needed. In order to improve the mobility ratio of water drive, a new type of high temperature resistance and high salinity polymer SWP322 has been developed. In this study, the compatibility, viscosity, temperature resistance, salt resistance and shear resistance of the polymer in Lukeqin reservoir were evaluated and compared with that of HPAM. Finally, the formation conditions of Lukeqin reservoir are simulated to test the percolation and oil displacement ability of the new polymer SWP322 under the conditions of high temperature and high salinity. Experiments show that the polymer has a temperature resistance of 100°C and a salinity resistance level of 2.0×105 mg/L. The experimental results show that the polymer SWP322 has a lower dissolution rate at room temperature than HPAM, but its temperature resistance, salt resistance, shear resistance, and temperature resistance are far better than those of HPAM. With the increase of temperature and salinity, the apparent viscosity of HPAM decreased rapidly, while SWP322 was almost independent of temperature and salinity, and the viscosity retention rate was more than 99%; at the same time, the viscosity retention rate of SWP322 after core shearing also reached 98.6%, which proves that SWP322 is superior to HPAM in its resistance to temperature and salt, and excellent shear resistance also helps to maintain the viscoelasticity of the polymer in the formation. Increase oil displacement efficiency. In terms of seepage capacity, the flow resistance of SWP322 is much better than that of HPAM, and the resistance coefficient and residual resistance coefficient are all more than 5 times that of HPAM; in the process of simulated oil displacement, the displacement efficiency of water flooding is 30.43%, while the flooding efficiency of first polymer flooding and subsequent water flooding is 16.6% higher than that of water flooding; the oil displacement efficiency of double-pipe polymer flooding is 13.19% higher than that of water flooding; the oil displacement efficiency of single tube and double tube flooding system is 16.1% and 23.2% higher than that of water flooding, respectively.
Augmented AI Solutions for Heavy Oil Reservoirs: Innovative Workflows That Build from Smart Analytics, Machine Learning And Expert-Based Systems
Authors: Castineira David , Zhai Xiang , Darabi Hamed , Valle Manuel , Maqui Agustin , Shahvali Mohammad , Yunuskhojayev Alisher 
Published: December 2018

Abstract
Many heavy oil fields have recently seen exponentially higher volumes of data being made available from omnipresent connectivity. Existing data platforms have traditionally focused on solving the problem of data storage and access. The more complex problem of true knowledge discovery and systematic value creation from all this massive amount of data is less frequently addressed. There is a new, novel workflow that tackles the problem of building intelligent data analytics in heavy oil fields. This multidisciplinary solution builds from Augmented AI, i.e., a combination of artificial intelligence/machine learning and domain knowledge or expertise.
Our solution has been proven effective in a Latin American heavy oil field and is presented here. We built an integrated view of the reservoir through a series of smart metrics and KPIs. This was accomplished by integrating expert-based knowledge with the analysis of geological data, reservoir behavior and production and operational performance. Our analytics-based solutions were designed from the perspective of reservoir management, and consequently, they could assimilate production and cost/economic analysis with geological information (e.g., well logs and/or existing geological models) and reservoir performance (metrics for pressure, voidage, fractional flow, reservoir contact, etc.). From here, KROs (key recovery obstacles) were identified for this heavy oil field, and robust field development opportunities (i.e., behind-pipe opportunities and/or new well targets) were methodically proposed based on an innovative saturation mapping approach. Our solution exploited existing cloud economics at scale, sustained advances in hardware capabilities (including GPUs running machine learning workloads) and iterative improvements in algorithmic learning techniques.
Ultimately, we will demonstrate a smart analytics-based solution that can be systematically implemented in heavy oil reservoirs for robust diagnostics and comprehensive field development opportunity identification. The proposed methodology intelligently combines both field experience with data-driven and machine learning methods.
Industry First; Rigless ESP Enables Wellbore Access to Perform a Coiled-Tubing Clean Out.
Authors: Dornan Grant , Autry Sydney , Fox Pete , Krysinski Marina , Nutter Greg , Cheblak Samer 
Published: December 2018

Abstract
The Access ESP system, a Thru Tubing Conveyed Electrical Submersible Pump (TTCESP), also referred to as a rigless ESP system, was installed in a well that had a history of producing significant amounts of sand and fine solids. During production of the wellbore fluids, solids accumulate in the well bore and lower completion restricting the inflow and well performance below the ESP, requiring a clean out intervention with a coiled-tubing operation to clear the restriction and return the well to full performance.
This paper records the retrieval and replacement of the rigless ESP to access the wellbore and perform a coiled-tubing clean out of the lower completion wellbore without the use of a heavy workover rig. The rigless ESP retrievable assembly components were removed through tubing, in a live well intervention, using a slickline unit, and coiled tubing unit. The application of the AccessESP system provided significant benefits and demonstrated its potential application for any ESP operation that necessitates frequent well interventions, has high rig costs, or resides in locations with limited rig availability.
The rigless ESP retrievable assembly is made up of four segments that are retrieved individually. Beginning from the uphole end of the retrievable ESP assembly, the first segment is the tubing stop, next a tubing packoff with a standing valve, then the complete pump assembly from pump discharge, pump, and pump intake, and on the downhole end is the motor assembly which includes the seals, motor, downhole gauge, and plugarm wet connector assembly. When these four components of the retrievable ESP assembly have been pulled from the well thru-tubing, there is open access to the lower completion wellbore.
An isolation sleeve was installed to protect the wet connector dock in the rigless ESP permanent completion from mechanical damage during the coil-tubing clean out process. After the clean out was completed the isolation sleeve was retrieved and the four components of the rigless ESP assembly were reinstalled and the well was placed back on production. The intervention and methods described herein confirms the viability of the access to the lower completion and wellbore and to perform slickline and coiled tubing well work interventions with the rigless ESP system.
Once through Steam Generator Integrity OTSG
Authors: Al-Ajmi Ghassab , Abulkair Sayed , Mejbel Barzan , Alrasheedi Mahmoud , Al-Awadi Abdulla , Wahba Ehab , Osman Mohammed , Abdulaziz Reda 
Published: December 2018

Abstract
Kuwait Oil Company (KOC) intends to develop Lower Fars Heavy Oil field on the north of Kuwait that requires steam generation.
The Lower Fars Heavy Oil (LFHO) Development Project is targeted at a large heavy oil accumulation of approximately 7 to 15 billion barrels oil-in-place located in a desert area of some 1, 200 km2 in North Kuwait. The development of this heavy oil resource is important to Kuwait's production strategy.
The LFHO reservoir has been partitioned into Well-Blocks; Phase 1 of the LFHO Development Project consists of two such Well-Blocks, which are intended to achieve a target plateau of 60,000 BOPD over a ten-year period from start of operations. This rate will increase after ten years, with future phases ramping up production up to a final plateau of 270,000 BOPD.
Reservoir engineering work performed to date indicates that phase 1 areas can best be developed by two or three cycles of cyclic steam stimulation (CSS) followed by continuous steam flood (SF) with steam quality of 55% (wells) to 80% central processing facility (CPF). The steam will be generated by multiple Once-Trough Steam Generators (OTSG) located in a central processing facility (CPF).
The Once through steam generation (OTSG) will use for generating steam utilizing treated boiler feed water to improve recovery of hydrocarbon from a reservoir.
Integrity process for steam generation equipment considered on Project various stages e.g. equipment selection, design, fabrication, inspection and testing.
Integrity process also considered during operation process of OTSG units within a defined integrity operating window (IOW) to establish and maintain a controlled process environment which would enable boiler feed water to be converted into steam in a safe, environmentally responsible manner without upsets and planned shutdown.
Effect of Pressure and Temperature of Steam in Parallel Vertical Injection Wells on Productivity of a Horizontal Well During the SAGD Process: A Numerical Case Study
Authors: Sun Fengrui , Yao Yuedong , Li Guozhen , Qu Shiyuan , Zhang Shikun , Shi Yu , Xu Zhengming , Li Xiangfang 
Published: December 2018

Abstract
Great breakthrough has been made in heavy oil EOR mechanism under water injection at different state. New findings from both experimental and theoretical studies provide strong support for the broad application prospect of steam in heavy oil EOR. In this paper, a series of studies are carried out on productivity of a horizontal well with several vertical steam injectors during the steam-assisted-gravity-drainage (SAGD) process.
In this paper, a novel topic is discussed on the effect of steam state on oil productivity during the SAGD process. The injection wells are three parallel vertical wells and the production well is a horizontal well. The numerical method is adopted to reveal the physical aspect mechanisms. Some meaningful conclusions are listed below.
(a) The usefulness of superheated steam in heavy oil recovery lays in its chemical reactions with heavy oil and rock minerals. The effect of physical heating on oil recovery efficiency is weak. (b) The oil production rate at the starting stage, from 0 day to 30 day, is oscillating with time due to the fact that the preheating stage is neglected. The connectivity between injectors and producer is poor without a necessary step of preheating. (c) The direction of oil recovery is from well-bottom of the injector to the well-head and then to the places between the injectors. (d) Chemical reactions may play an important role in oil recovery efficiency if the final recovery efficiency by injecting steam with higher steam quality is several order of magnitude than that by injecting steam with lower steam quality.
We carried out the pilot study on the effect of steam state on heavy oil EOR during the SAGD process with several vertical injectors. More importantly, the pilot study conducted in this paper provide the very basis for the application of superheated steam for oil companies and following academic research in the field.
Pore Scale Simulation of Surfactant Flooding by Lattice Boltzmann Method
Authors: Wei Bei , Hou Jian , Wu Dejun , Wang Huiyu , Liu Hao 
Published: December 2018

Abstract
Surfactants play an important role in the widely used enhanced heavy oil recovery methods such as surfactant-polymer flooding and alkali-surfactant flooding. In this study, we focus on the effects of surfactant during surfactant flooding and provide a pore scale simulator of surfactant flooding based on the Lattice Boltzmann (LB) method.
We introduce a dipole to present the amphiphilic structure of surfactants in the Lattice Boltzmann model, and characterizes microscopic fluid interactions at the kinetic level. There are three velocity distribution functions to present the oil, water, and surfactant species, and every distribution follows the discrete Boltzmann-BGK equation. There is also an additional dipole vector representing the orientation of amphiphile, so that the interactions related with surfactants depend not only on particle relative distances but also on their dipolar orientations.
The simulation results show that surfactants can reduce the oil-water interfacial tension and recover more oil trapped by capillary force. Moreover, surfactants are able to emulsify the flooding system, forming O/W emulsions or bi-continuous micro-emulsions. Higher surfactant concentration leads to smaller oil droplets in emulsions. In addition, the phase distribution morphologies in porous media are much different in different wetting conditions. By associating the fluid-solid interfacial tension with the surfactants adsorption concentration on walls, we characterize the wettability alteration mechanism in LB model accurately. The oil recovery can be improved by changing the wettability from oil-wet to water wet, increasing the surfactant concentration, and enhancing the adhesion parameters. However, the adsorption onto walls leads to unnecessary waste and could decrease the surfactant concentration in bulk phase.
The study provides an effective pore scale tool to simulate the surfactant involved interfacial flows in porous media. In addition, we can use it to study the flow mechanisms and remaining oil distributions during surfactant flooding.