bluuebunny/crossref_metadata_2025_split huggingface dataset:
Well Integrity in the Times of ISO 13679 and Premium Connections: Experiences and Way Forward
Authors: Grijalva O.. , Perozo N.. , Holzmann J.. , Paz C.. , Oppelt J.. 
Published: October 2017

Abstract
Developments in OCTG connections defining well integrity and mechanical performance of oilfield tubulars are not something newas a continuous feedback between field challenges and theinnovative nature of the Industry is something derivated into newer, more intensive Full Scale Testing procedures and novel analytic tools for connection performance evaluation in the last decades. The relationship between all those factors has been condensed in the present paper which gives shape to a comprehensive "technical history" for Premium Connections, hidden and scattered so far in issued patents, manufacturer manuals, brochures and selected field cases generated between 1935 and 2017.
Design schools can be well defined by manufacturer and region;apart from this, theadvancements in testing and manufacturing made possible to adjust the connection to the technical constraints put fromthe field, namely a high need for gas tightness and enhanced torque capabilities. Last but not least, it was discovered that, among all oilfield equipment used during upstream operations, it was (next to advancements inSSSV's)the constant evolution of tubular connectiontechnologieswhat contributed to "crystallize" the modern concept of Well Integrity, especially after the big offshoredevelopments seen from 1971 on. As a corollary, the impact of current standardization protocols ISO 13679 / API 5C5 on well integrity in terms of metallic seal integrity will be assessed in the light of the tribological and mechanical evolution of the MTM seal during testing and validation.
Analysis and Optimization of Bubbly Oil Production in Heavy Oil Reservoirs
Authors: Temizel Cenk , Moreno Raul , Jia Bao , Alkouh Ahmad , Al-Otaibi Basel , Kyanpour Mohammad 
Published: October 2017

AbstractSome heavy oils reservoirs present an unusual behavior when put on production under significant drawdown conditions. In these reservoirs, the high formation depressurization increments the recovery factor and accelerates the production rates driven by a solution gas mechanism. Due to the chemical and physical properties of these oils they tend to stabilize the dispersion of gas bubbles, promoting the generation of foam in the oleic phase. This foamy oil when compared with conventional oils result in a more productive response at similar drawdown conditions. The foamy oil phase behavior is the result of a number of complex mechanisms and requires a good understanding on each of them to estimate the potential response of these reservoirs. In this work, the role of key factors that affect the bubbly oil production is summarized.To outline the significance of key variables on the performance, a commercial optimization and uncertainty analysis software coupled with a mechanistic simulator is used. The simulator allows a detailed modeling of the physics involved on the generation and behavior of the foamy oils, in which the foamy oil is modeled as a disperse phase of gas bubbles in the oleic phase, including small mobile gas bubbles and larger trapped gas bubbles flowing as discontinuous gas dispersion which affect foam viscosity, compressibility, mobility and relative permeability. Fluid properties used in this work are from Maini (1996).The sensitivity and optimization analysis performed in this work on key reservoir variables and well operational parameters shows the significance of each factor on the production response. The relative importance of each variable is reported in tornado diagrams. Results showed that a strong approach on handling the reservoir unknowns are as crucial as the control of operational parameters from reservoir management point of view.Nowadays the foamy oil behavior and its favorable production response are not totally well understood. Solutions have been proposed but they are still controversial and the use of horizontal wells introduces more complexity in the production operations. In this work is provided an in-depth optimization and uncertainty analysis to outline the role of each major parameter affecting the production response and the recovery efficiency in this type of reservoirs using horizontal wells.
Uncertainty Analysis and Design Optimization of Gas-Condensate Fields
Authors: Abdul-Latif Benson Lamidi , Fathi Elsharkawi Ahmed Mohammed , Daniel Edem Tsikplornu 
Published: October 2017

AbstractUnlike conventional reservoir development, uncertainty analysis and design optimization of unconventional reservoirs have caught less attention because of a general notion that oil field production data analysis and computational methodologies and techniques can be applicable to unconventional reservoir developments. In order to predict production profiles in unconventional reservoirs, it is essential to understand the uncertainties and performance of unconventional reservoirs. In this paper, the most relevant factors influencing the production of gas-condensate in a domain of real data from gas condensate fields is investigated and reviewed.To identify the major factors affecting the production of condensates from heterogeneous and ultra-low permeability reservoirs, third and fourth order factorial design (Box Behnken technique) were used on a domain of gas-condensate field data to perform the uncertainty analysis. A semi-analytical surrogate model for Monte Carlo analysis was also proposed in this paper.Condensate blockage radius, reservoir permeability, well spacing, reservoir thickness; compressibility, initial pressure; fracture spacing and initial condensate saturation were noted to be the most substantial parameters influencing condensate production. Validation of the results proved that the proposed surrogate models for gas-condensate reservoirs could reliably be used to forecast condensate values in heterogeneous and ultra-low permeability reservoirs.This paper also presents a semi-analytical model applicable to unconventional reservoirs to incorporate the effect of condensate banking in the design optimization of hydraulic fracturing. Analytical models for Darcy flow above and below the dew point pressures were considered whilst estimating the optimum fracture design in gas condensate reservoirs using Schechter's approach incorporating the effects of the condensate blockage radius.
A New Method of Backup Cutter Layout to Extend Bit Life Without Sacrificing Rate of Penetration
Authors: Chen Shilin , Khlefat Yazan , Cleboski Chris , Anderle Seth , Maouche Zakaria 
Published: October 2017

Abstract
This paper discusses a new and general method of backup cutter layout to extend bit life without sacrificing rate of penetration and two field case studies. This method includes the following aspects: Ensuring backup cutters do not cut or only partially cut when their primary cutters experience little to no wear and when the depth of cut of the bit does not exceed an expected value. This aspect is enabled by allowing backup cutters to have a minimal critical depth of cut that is greater than the depth of cut of the primary cutters.Ensuring backup cutters act as major cutters when the primary cutters' wear depth is equal to or greater than the underexposure of the backup cutters. This aspect is enabled by allowing each backup cutter be rotationally behind its primary cutter by approximately 180° or greater. The underexposure of each backup cutter relative to its primary cutter is carefully calculated based on the primary cutter's wear and drilling slope.
Real-Time Integration of Geo-Mechanics to Overcome Drilling Challenges and Low NPT
Authors: Al-Zankawi Omran , Belhouchet Mohamed , Abdessalem Abba 
Published: October 2017

Abstract
Most drilling-related incidents are caused by unstable boreholes, whether they are caused by lost circulation, packoff, or stuck BHA and/or casing. One of the main objectives of this study was reduction in drilling incidents and associated Non Productive time (NPT) while drilling wells in a particular area of Kuwait, where often extremely challenging environments were faced due to wellbore instability arising from tectonic stresses, associated faults, fractures, complex structures, and anomalous pore pressure. Additional challenges were presented by a complicated and highly deviated well design, where planes of weakness of the formation being drilled and their relative angle with respect to the well path become crucial factors in assessing stability of the borehole. Multiple failure mechanisms such as stress induced wellbore instability, invasion of drilling fluids into weak bedding / micro-fractures and osmotic sensitivity, were found to be the root cause of wellbore instability across reactive shale formations especially during drilling of highly deviated wells.
In lie of these challenges, a comprehensive study was conducted to overcome the wellbore stability issues and investigate feasibility of drilling Ahmadi wells of Kuwait at high deviation. Correct mud weight (MW) prediction was one key factor during the drilling stage to keep the wellbore stable and deliver good borehole geometry (Figure 1). The key objectives of the study were to define a safe MW program for the vertical and deviated sections of the planned well by conducting a wellbore stability study and to determine a real-time strategy to mitigate and-or manage wellbore instabiity problems as they arise.
The scope of work included root cause analysis of drilling events, development of mechanical earth models (MEM) for offset wells, integrating sections of the MEM from the offsets to the planned well trajectory, and a safe MW program for planned well.
The paper describes the process of optimizing the drilling practices based on geomechanical outputs, to overcome serious drilling hazards and application of real time geomechanical monitoring for successful drilling. This application promises to open the prospect of drilling similar wells without complications and reduce NPT in Kuwait.
Development and Field Trial of New Acid Soluble Drilling Fluids
Authors: Wagle Vikrant , Al-Yami Abdullah S. , Al-Bahrani Hussain , Awadh Abdulla 
Published: October 2017

Abstract
Stuck pipe, historically, has presented huge challenges to the worldwide oil industry. Stuck pipe has resulted in a great amount of nonproductive time, thereby causing huge monetary losses to the oil industry. A new drilling fluid has been designed, which employs a combination of two different weighting agents viz. barite and manganese tetroxide (Mn3O4) to overcome the problems linked with stuck pipe. Drilling fluids formulated with a combination of manganese tetroxide and barite as weighting agents are expected to have the following advantages: a) Better sag resistance, b) lower equivalent circulating density (ECD), c) lower fluid cost, and d) stuck pipe mitigation due to acid solubility of manganese tetroxide.
This paper describes the formulation of 100 pcf and 150 pcf drilling fluids formulated with a combination of barite and Mn3O4 as weighting materials and hot rolled at 270°F and 300°F, respectively. The experimental work involves measuring rheological properties and high temperature, high pressure (HTHP) fluid loss at the specified temperature. Barite sag measurements were also performed on 150 pcf drilling fluids to determine the sag resistance of the fluid. The paper describes results of using different organic acid based filter-cake breaker fluids for the partial dissolution of Mn3O4 based filter cake. The paper also describes the data obtained from the field trial of 100 pcf and 155 pcf fluids formulated with barite and Mn3O4 for wells with a BHST of 290°F.
The paper discusses the advantage of using such drilling fluids in mitigating stuck pipe issues and highlights their benefits in terms of better barite sag resistance and lower equivalent circulating density as compared to conventional drilling fluids formulated with barite as weighting agent. The 100 pcf and 150 pcf fluids showed superior rheology, thin filter cake and better sag resistance as compared to fluids formulated with only barite as the weighting agent. Different organic acids were able to partially dissolve the filter cake of drilling fluids formulated with barite and manganese tetroxide as weighting agents. This partial dissolution of filter cake is sufficient to free the pipe in the case of any stuck pipe event in the wellbore. The drilling fluids formulated with a combination of barite and manganese tetroxide showed good rheology, barite-sag resistance and resulted in successful drilling of wells having a BHST of 290°F.
Thermo-Mechanical Properties of Annular Sealants—A Path to Optimized Wellbore Integrity and Economics
Authors: Jimenez Walmy Cuello , Pang Xueyu , Urdaneta Javier A. , Sørensen Espen , Lende Gunnar , Nimane Sudhir 
Published: October 2017

Abstract
Understanding the heat transfer phenomena encountered in extreme oil and gas reservoir environments [i.e., thermal recovery, high-pressure/high-temperature (HP/HT), deepwater, etc.] and geothermal wells is important to enhance the exploration and production of subterranean energy resources. However, there can be a lack of information about thermal properties of current oilwell cement systems, which are key inputs for any cement sheath stress simulator that accounts for the thermal cycling effect on the integrity of the annular sealant. Having thermal data for multiple sealant systems is important to allow for risk reduction and production maximization by reducing wellbore construction uncertainty during the planning stage, therefore allowing operators to make well-informed decisions.
This paper discusses the thermal conductivity and thermal expansion of neat, foamed, and elastic oilwell cements. These properties were measured in hydrated and dehydrated states at ambient pressure and at temperatures ranging from 25 to 100°C (77 to 212°F). Both thermal conductivity and thermal expansion measured on dehydrated cement samples were less than hydrated samples, which is most likely attributed to the effect of evaporable water within the cement specimens. Mathematical relationships were derived for thermal and physical (i.e., density) properties of cement, thus allowing for approximate characterization of the thermal behavior of oilwell cements. The effect of the thermal properties of different cement systems on the integrity of a typical thermal recovery well was evaluated as a case study. Elastic properties of the aforementioned cement systems were also studied, yielding characteristic curves for each system. Moreover, the impact of cyclic loads on determining acceptable stress levels of annular sealants is also presented, along with its economic benefits. This allows for the optimal design of dependable sealants for long-term integrity during the planning stage.
How to Use Drill String Vibration Data to Reveal Geology Phenomena in Geosteering Jobs: An Application Sensor at the Bit
Authors: Sitinjak Eri Sarmantua , Kurniawan Baladika , Besol Yusuf 
Published: October 2017

Abstract
Drillstring vibration information can be used to define the geology of the well. Some geological phenomena in horizontal wells can be revealed from drill string vibration data. Examples include faults, exiting and entering the reservoir, different lithology and rock strength. In addition, uncontrolled vibrations can also limit the optimization of drilling performance, for instance increasing the possibility of stuck pipe, affecting wellbore stability, reducing drilling tool life, and causing tool failure. This paper aims to gather vibration data from drilled horizontal wells and classify them based on the geological and lithological environment in which they were observed. Three major kinds of vibrations are resulted from horizontal drilling; axial vibration, lateral vibration, and torsional vibration. Vibration data were collected and grouped together to correlate vibration behavior to the geology of the horizontal well. These vibrations data were compared in different geological situations; for example in clastic and carbonate environments, drilling through changing lithology, exiting the reservoir, and passing through a series of faults. The correlation can then be utilized in geo-steering application.
The objective of this paper is to enable engineers to characterize the vibration data according to potential risk factors that may be encountered during real-time geo-steering, and to take actions that optimize the drilling operation. Observations have revealed a strong correlation between vibration behavior and geological phenomena in drilling operations. These observations enable confirmation of various geological features from geo-steering modelling. Furthermore, adjusting drilling parameters and implementing good drilling practice would minimizes the tool exposure to excessive vibrations in order to avoid tool failure, and optimizes drilling operation. An understanding of the vibration data can also be used to help geo-steer and support the justification for any adjustment in the lateral section. This will not be a proactive adjustment but more of a reactive adjustment. An additional objective is to find the best tool configuration in certain horizontal well environments, thereby improving the drilling optimization and enabling optimum procedures by capturing the right downhole dynamics when encountering excessive vibrations. These findings will help drilling to control the well and contribute to the wellbore stability. This will be the first paper to characterize vibration behavior in relation to the geological phenomena and applying it in horizontal wells.
Water Control Management Utilizing Downhole Water Sink Technology: Application of a Reservoir in the Middle East
Authors: Al-Azmi Nasser H. , Aladwani Faisal A. , Kasaraneni Pruthvi R. 
Published: October 2017

Abstract
Produced Water is a major challenge in the oil and gas industry. Water production increases worldwide as more reservoirs depleted over time thus more resources needed to handle the unwanted produced water. Managing the subsurface water conformance maximizes hydrocarbon production and reduces operating cost that is mainly expected from the unwanted water production. It is important to identify the water source to solve any problem related to the unwanted excessive water production. Once the mechanism of the water production is understood, an effective strategy can be designed to detect and control the produced water. Different technologies and methods have been developed to control produced water. For example, Production Logging Tool (PLT) and Chan's WOR diagnostic plot are two common methods for determining the presence and causes of the unwanted excessive water production. In this study, Downhole Water Sink (DWS) completion technology is adapted to maximize reservoir recovery by reducing water cut with oil production, the excessive water is produced through a bottom completion and the oil is produced from the top completion. The design of a successful DWS requires detailed planning for the completion location and the production strategy. The aim of this study is to evaluate DWS technology performance in vertical oil wells located in Middle East Reservoir, which have severe water coning. In addition, economic analysis results were obtained by comparing the conventional wells with DWS wells to investigate the effect of DWS in reducing the operating cost. Results showed that the DWS completion minimized the water production by 18% and enhanced oil production by 26% compared to the conventional completions. In addition, several diagnostic tools applied to evaluate the water to enhance the proposed solution in which is applied to the candidate reservoir.
Making Water Injection Interventions Work: The Importance of Understanding Thermal Effects in Fractured Water Injectors
Authors: Duvivier G.. , Al-Naqi M.. , Ameen A. A. , Al-Enizi N.. , Al-Shati A.. , Rajan S.. , Clark R. A. 
Published: October 2017

AbstractStimulating water injectors successfully is critical to any waterflood and to successfully stimulate wells it is important to understand what technology works and what does not. An effective method of evaluating stimulation efficency is by monitoring the long term performance of the water injectors and how injection pressure and temperature varies over time.The primary source of injection water for Greater Burgan is produced water, which is collected through an extensive gathering system. Because this gathering system is so large, the resulting fluids drop to atmospheric temperature before they are available for injection. Average daily temperatures in Kuwait vary by more than 60°F annually. All of the injection wells are injecting above fracturing pressures and these temperature swings impact the size of fractures leading to observed changes in rate of up to 40%. These effects must be understood to evaluate the impact of injection fluid temperature upon stimulation.Monitoring this surface injection data has allowed the team to select a successful stimulation method for the injectors and added significantly to the field's injection rate.
Yield and Economic Potential of Spring‐Planted, Pea–Barley Forage in Short‐Season Corn Double‐Crop Systems
Authors: Raskin Daniel , Wells M. Scott , Grossman Julie M. , Coulter Jeffrey A. , Sheaffer Craig C. 
Published: October 2017

Core Ideas
Biomass yield is similar between sole‐crop grain corn forage–silage corn double‐crop systems.
Nitrogen fertilizer does not increase net economic return from forage–silage corn double‐crop systems.
Double‐cro pea–barley forage–silage corn is not a profitable alternative to sole‐crop corn in the upper Midwest.
Double cropping with forages can increase dry matter (DM) yield and N‐use efficiency over sole‐crop (SC) systems, but reductions in primary crop yield can limit economic return. This study assessed whether a double‐crop (DC) system coupling a legume–cereal biculture forage with early maturing corn can reduce fertilizer N input and compete economically with SC corn. Biomass yield, N uptake, residual soil NO3–N, and economic net return were measured in two DC and one SC systems in four experiments conducted in Minnesota between 2014 and 2016. In DC systems, a field pea (Pisum sativum L.)–barley (Hordeum vulgare L.) forage biculture was double cropped with a dual‐purpose hybrid (DP) or semidwarf (SD) corn (Zea mays L.) variety. In SC systems, full‐season hybrid corn (HC) was planted without preceding forage. Six fertilizer N rates (0–224 kg N ha−1) were applied to corn. Averaged across N rates, DP and SD corn yielded less (8.2 and 1.8 Mg DM ha−1, respectively) compared to SC (16.4 Mg DM ha−1). Total system DM yield was similar for the DC–DP and SC–HC systems, averaging 16.6 Mg ha−1. Economic return for the SC system was greater than that for the DC–DP system, and was maximized with 134 to 224 kg N ha−1, while return for the DC–DP system was unaffected by N rate. Due to low corn yield and greater production cost, double cropping spring forage with short‐season corn is not a profitable alternative to SC corn.