Automated Approaches Determine Solids Content in Drilling and Completions Fluids

2021 ◽  
Vol 73 (11) ◽  
pp. 51-52
Author(s):  
Chris Carpenter
Keyword(s):  
Elevated Temperatures ◽  
Drilling Fluid ◽  
Technical Conference ◽  
Drilling Fluids ◽  
Test Results ◽  
University Of Texas ◽  
Safety Issues ◽  
Recommended Practices ◽  
Solids Content ◽  
The University

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 201368, “Automated Solids-Content Determination in Drilling and Completions Fluids,” by Sercan Gul, SPE, Ali Karimi Vajargah, and Eric van Oort, SPE, The University of Texas at Austin, et al., prepared for the 2020 SPE Annual Technical Conference and Exhibition, originally scheduled to be held in Denver, 5–7 October. The paper has not been peer reviewed. Monitoring of low- and high-gravity-solids (LGS and HGS) content and maintaining these at ideal levels is essential for optimal drilling fluid performance, efficient hole cleaning and equivalent-circulating-density management, and prevention of failures of surface and downhole equipment during drilling. LGS and HGS monitoring in the field is currently accomplished using the API retort-kit measurement, which has certain drawbacks and is difficult to automate. In the complete paper, two new approaches are investigated to automate the LGS and HGS content measurements of drilling fluids, which potentially can replace the retort test. Introduction The conventional way to characterize LGS and HGS in the field is by using a retort-kit measurement specified in API Recommended Practices 13B-1 and 13B-2. The longevity of these tests is testament to the effectiveness of the API standards and the tests themselves in providing useful and practical field guidance. Despite their evident success, however, various downsides exist in current solids-content-testing methods. Retort-kit measurements present the following issues: - Difficulty in obtaining accurate and repeatable test results - Safety issues associated with laboratory testing at elevated temperatures (over 930°F) - Interpretive bias issues associated with test results, including the potential for deliberate manipulation of these results - Difficulty in automating the retort test for improved efficiency and safety The authors’ opinion is that automating antiquated API test protocols is not a useful practice. They write that a clean-slate approach would be better, in which a determination is made whether solids-content information can be provided in a novel and meaningful way using methods that deviate from standard API recommended practices. In the complete paper, the authors investigate a machine-learning (ML) and data-analytics method for this purpose in combination with a novel inline X-ray fluorescence (XRF) measurement method.

Elevated-Temperature and -Pressure Tribology of Drilling Fluids Used in Oil and Gas Extended-Reach-Drilling Applications

SPE Journal ◽  
2018 ◽  
Vol 23 (06) ◽  
pp. 2339-2350 ◽  
Author(s):  
Pixiang Lan ◽  
Kyriaki Polychronopoulou ◽  
Larry L. Iaccino ◽  
Xiaoying Bao ◽  
Andreas A. Polycarpou
Keyword(s):  
Elevated Temperature ◽  
Photoelectron Spectroscopy ◽  
Oil And Gas ◽  
Elevated Temperatures ◽  
Drilling Fluid ◽  
Cost Effective ◽  
Chamber Pressure ◽  
Drilling Fluids ◽  
Slight Reduction ◽  
Extended Reach Drilling

Summary Extended-reach-drilling (ERD) wells are expensive and challenging; however, in special situations, compared with conventional drilling, ERD wells are more environmentally friendly and cost-effective. Application of drilling fluids with good lubrication for ERD is one of the most important methods to facilitate longer total depth (TD) of the wells. To better simulate the elevated-temperature environment in the borehole, this study proposes a method to perform tribological studies of drilling fluids at temperatures higher than 100°C by conducting experiments in a high-chamber-pressure environment, which can suppress the evaporation of the drilling fluid at high temperatures. Two lubricant additives were studied, and the results showed that, for the drilling fluid at elevated temperatures, a prototype additive (Additive A) reduced the coefficient of friction (COF) significantly by 44.8%, whereas a commercial additive (Additive B) caused only a slight reduction of the COF by 4%. After the tribological experiments, the wear mechanisms of the additives and abrasive particles were investigated with scanning electron microscopy (SEM) and X-ray photoelectron spectroscopy (XPS).

Application of modified starch in high-temperature-resistant colloidal gas aphron (CGA) drilling fluids

2021 ◽  
Vol 0 (0) ◽  
Author(s):  
Wenxi Zhu ◽  
Xiuhua Zheng
Keyword(s):  
High Temperature ◽  
High Temperatures ◽  
High Performance ◽  
Oil And Gas ◽  
Elevated Temperatures ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Modified Starch ◽  
Gas Reservoirs ◽  
Building Capability

Abstract Colloidal gas aphrons (CGA) are finding increasing application in depleted oil and gas reservoirs because of their distinctive characteristics. To overcome the limitations of its application in high-temperature drilling, a modified starch foams stabilizer WST with a temperature resistance of 160 °C was synthesized via radical polymerization. The chemical structure of WST was characterized by Fourier infrared spectroscopy and results showed that all three monomers acrylamide, 2-acrylamido-2-methyl-1-propane sulfonic acid, and N-vinylpyrrolidone have been grafted onto starch efficiently. Based on the microscopic observations, highly stable aphrons have been successfully generated in the WST-based CGA drilling fluids within 160 °C, and most aphrons lie in the range of 10–150 μm. WST can provide higher viscosity at high temperatures compared to xanthan gum, which helps to extend foam life and stability by enhancing the film strength and slowing down the gravity drainage. Results show that WST-CGA aged at elevated temperatures (120–160 °C) is a high-performance drilling fluid with excellent shear-thinning behavior, cutting carrying capacity, and filtration control ability. The significant improvement of filtration control and well-building capability at high temperatures is an important advantage of WST-CGA, which can be attributed to the enhancement of mud cake quality by WST.

scholarly journals Organic-Sulfonate Functionalized Graphene as a High Temperature Lubricant for Efficient Antifriction and Antiwear in Water-Based Drilling Fluid

2021 ◽  
Author(s):  
Xiao Tian ◽  
Ningning Song ◽  
Guangbin Yang ◽  
Changhua Zhou ◽  
Shengmao Zhang ◽  
...  
Keyword(s):  
High Temperature ◽  
Performance Test ◽  
Drilling Fluid ◽  
Sodium Dodecylbenzene Sulfonate ◽  
Drilling Fluids ◽  
Sulfonate Group ◽  
Test Results ◽  
Wear Properties ◽  
Dodecylbenzene Sulfonate ◽  
Deposited Film

Abstract The lubricity of drilling fluid resistant to high-temperature over 200℃ is still one of the technological breakthroughs. In this study, the graphene modified with sodium dodecylbenzene sulfonate (SDBS) was selected as a resistant to high-temperature lubricant. Our results show that the drilling fluids have high stability after aging at 240°C with the assistance of the SDBS/graphene. Excitingly, the tribological performance test results revealed that the SDBS/graphene exert excellent anti-friction and anti-wear properties. Compared with the base slurry, the friction coefficient and wear rate of the SDBS/graphene slurry are reduced by 76% and 59%, respectively. The deposited film composed of graphene, Al2O3, SiO2, Fe2O3, FeSO4 actualized the protection of the sliding contact zone, proving that the sulfonate group on the SDBS/graphene contributed to prompt the deposition of the graphene and bentonite and then enhanced tribological properties of the drilling fluids. Overall, the graphene modified with SDBS is expected to solve the difficulty to form effective deposited film and poor lubricity of the drilling fluid under high-temperature.

The Effect of Different Drilling Fluids on Borehole Mechanical Friction

2014 ◽  
Author(s):  
Ali Taghipour ◽  
Jan David Ytrehus ◽  
Bjørnar Lund ◽  
Arild Saasen
Keyword(s):  
Drilling Fluid ◽  
Drill String ◽  
Solid Particles ◽  
Drilling Fluids ◽  
Test Results ◽  
Friction Behavior ◽  
Basic Point ◽  
Oil Companies ◽  
Water Based ◽  
Extended Reach Drilling

Mechanical friction is one of the most important aspects in highly inclined wellbores such as extended reach drilling (ERD) and through tubing extended reach drilling (TTERD). Friction caused by the contact between the drill string and the well casing or borehole is dependent to the drilling weight and fluid properties. Drilling fluids play an important role on mechanical friction and using oil based drilling fluids with higher lubricity can reduce torque and drag and minimize stick and slip concerns. Reducing mechanical friction will improve drilling efficiency in general, and will in particular enable longer reach for ERD wells. This paper presents results from experimental laboratory tests where mechanical friction has been investigated in non-circular wellbore geometry. The experiments have been conducted as part of a research project in the tribology lab in Technical University of Luleå. The project was sponsored by the Research Council of Norway and four oil companies. Friction behavior has been investigated for two different drilling fluids; water based and oil based drilling fluids both with and without solid particles. A pin on disc setup was used for these experiments where a spherical steel pin was sliding on a rotational disc made of granite. Friction force has been measured in constant sliding speed and in presence of particles in wet condition. The test results show that mechanical friction is smaller with oil based than water based drilling fluids in the presence of solid particles. In addition, the friction coefficient depends to the particle types and is higher when solid particles were added to the lubricants. Such experiments in a tribology laboratory are important to identify the effect of drilling fluid on mechanical friction from a basic point of view isolated from the other wellbore parameters. Test results and the experimental approach could therefore be of value for any one working with drilling and well construction.

Investigation of Changes in the Structure of Clays During Hydrothermal Study of Drilling Fluids

1980 ◽  
Vol 20 (05) ◽  
pp. 385-390 ◽  
Author(s):  
Leroy L. Carney ◽  
Necip Guven
Keyword(s):  
Crystalline Phase ◽  
Elevated Temperatures ◽  
Drilling Fluid ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Hydrothermal Conditions ◽  
Cell Parameters ◽  
Temperature Levels ◽  
Almost All ◽  
Geothermal Drilling

Abstract The need for a drilling fluid that will exhibit its basic requirements at temperature levels high enough to be used for geothermal drilling has prompted studies of various systems. The temperature range of some of these studies has been between ambient temperature and 700 degrees F (370 degrees C). A system was developed that exhibited the desirable properties of a good drilling fluid system at elevated temperatures and pressures. A fluid that exhibited these desirable properties after being subjected to high temperature and pressure was unusual as compared with presently used fluids. Therefore, investigation into why these fluids were capable of exhibiting good rheology and fluid-loss control was conducted. It was found that certain mineralogical components of the drilling fluid undergo transformation after being subjected to high temperatures and pressures. The conversion is temperature dependent but also is affected by the presence of various salts as well as the presence of silica and calcium.The fluids under investigation contained the mineral sepiolite as the basic ingredient. The changes in the sepiolite are reported in this paper. Introduction A drilling fluid (350 mL) containing sepiolite (15 g), Wyoming bentonite (5 g), NaOH (0.5 g), and organic polymers (2.5 g) was heated at 700 degrees F (370 degrees C) for 16 hours in a cement consistometer. In this system, after the same hydrothermal treatment, almost all the sepiolite was destroyed along with the carbonates and the 12.3- Na-montmorillonite was converted to 13.3- montmorillonite. A new crystalline phase was formed, constituting about 10 to 15% of the solids in the drilling fluid. This new phase occurs as laths elongation along the b axis, with lengths of 2 to 3 microns (2 to 3 m) and widths of 0.1 to 0.7 microns (0.1 to 0.7 m). The laths generally form regular aggregates similar to cordwood. In many of these stacks, individual laths are arranged in a regular manner into single crystals or into polysynthetic twins; some of them exhibit a perfect morphology with 60 degrees interfacial angles. The selected area electron diffraction patterns of the new crystalline phase displays an A-centered lattice with the unit-cell parameters: b = 7.17 0.05, c = 14.6 0.1 and = 90 degrees 10' 10'. These lattice parameters and the morphological features of the new crystalline phase are similar to those of xonotlite, a hydrated cement mineral.After these tests were completed, further studies were conducted using sepiolite alone in water and sepiolite with various salts added under controlled conditions. The usefulness of sepiolite in drilling fluids under extreme conditions of temperature, pressure, and pH during deep-well drilling now is recognized. Commonly, these drilling fluids are contaminated with salts of Na, Ca, and Mg from the formation. Sometimes the salts or hydroxides are added purposely to the drilling fluids. Therefore, it is important to evaluate the effects of these salts and hydroxides on the sepiolite under hydrothermal conditions. SPEJ P. 385＾

First Use of Novel High Temperature Water-Based Reservoir Drilling Fluid to Access Depleted Deepwater Reserves

2021 ◽  
Author(s):  
Alexandra Clare Morrison ◽  
Conan King ◽  
Kevin Rodrigue
Keyword(s):  
High Temperature ◽  
Elevated Temperatures ◽  
Drilling Fluid ◽  
Synthetic Polymer ◽  
Wellbore Stability ◽  
Soluble Solids ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Flow Loop ◽  
Loss Control

Abstract A combination of divalent base brine and high wellbore temperature presents significant challenges for high density aqueous reservoir drilling fluids. Such systems traditionally use biopolymers as viscosifiers; however, they are subject to degradation at elevated temperatures. Non-aqueous drilling fluids are thermally stable but complete removal of the filtercake is challenging and this can lead to formation damage. This paper describes the qualification and first deepwater drilling application of a unique aqueous reservoir drilling fluid at temperatures above 320°F. A high-temperature divalent brine-based reservoir drilling fluid (HT-RDF) and a solids-free screen running fluid (SF-SRF) were designed, both utilizing the same novel synthetic polymer technology. Calcium bromide brine was selected for use to minimize the total amount of acid-soluble solids in the drilling fluid. A comprehensive qualification was undertaken examining parameters such as rheology performance across a range of temperatures, long-term stability, fluid loss under expected and stress conditions (16 hours at 356°F), production screen test (PST), and various fluid-fluid compatibility tests. Return permeability tests were conducted on the final formulations to validate their suitability for use. The synthetic polymer technology provided excellent rheology, suspension, and fluid loss control in the fluid systems designed in the laboratory. To prepare for field execution multiple yard mixes were performed to verify the laboratory results on a larger scale. Additionally, a flow loop system was utilized to evaluate fluid performance under simulated downhole temperature and pressure conditions before field deployment. The final high temperature drilling fluid as designed provided rheological properties that met the necessary equivalent circulating density (ECD) requirements while drilling the reservoir. The fluid loss remained extremely stable and there were no downhole losses despite the depleted nature of the wellbore. Production screens were run straight to total depth (TD) with no wellbore stability issues after a three-day logging campaign. High temperature aqueous reservoir drilling fluids have historically been limited by the lack of suitable viscosifiers and fluid loss control additives. This paper outlines the design, mixing and logistical considerations and field execution of a novel polymer-based reservoir drilling fluid.

Faktor – Faktor Yang Mempengaruhi Minat Berwirausaha Mahasiswa Program Studi Manajemen Fakultas Ekonomi Universitas Flores

Analisis ◽  
2020 ◽  
Vol 19 (1) ◽  
pp. 76-84
Author(s):  
Nasarius Aban ◽  
Gabriel Tanusi
Keyword(s):  
Emotional Intelligence ◽  
Regression Analysis ◽  
Family Environment ◽  
Linear Regression Analysis ◽  
Simple Random Sampling ◽  
Coefficient Of Determination ◽  
Test Results ◽  
Study Program ◽  
Management Study ◽  
The University

This study aims to determine the effect of emotional intelligence, independent attitude and family environment on the interest in entrepreneurship at the University of Flores Management Faculty of Economics. This research is an associative research. The population in this study were students of the Management Study Program of the Faculty of Economics of the University of Flores in the class of 2015-2016 who had passed the entrepreneurship courses of 170 people. Samples taken in this study were 105 respondents, with sampling techniques using simple random sampling. Data collection using questionnaires and interviews, while data analysis was performed using multiple linear regression analysis. The results of multiple regression analysis are Y = 1.060 + 0.594X1 + 0.114X2 + 0.421X3 + e. The coefficient of determination R2 for the variables X1, X2, X3 is 0.675, which means that entrepreneurial interest can be influenced by emotional intelligence, independent attitude and family environment by 67.50% and the remaining 32.50% is influenced by other factors including factors of education, skills, motivation and others. F test results show the value of Fcount> Ftable (28.442> 2.69) with a significant level of 0.000 <0.05 meaning that there is a positive and significant influence between emotional intelligence, independent attitude and family environment together on the entrepreneurial interest of the Faculty of Management Study Program Students The economy. Partial test results (t) show 1) Emotional intelligence factors have a positive and significant effect on entrepreneurial interest 2) Family environment factors have a positive and significant effect on entrepreneurial interest 3) Independent attitude factor has no positive and significant effect on entrepreneurial interest.

INTRODUCTION TO RISK AND SAFETY OF AIR NAVIGATION

2020 ◽  
Author(s):  
Fedja Netjasov
Keyword(s):  
Doctoral Students ◽  
Traffic Engineering ◽  
International Standards ◽  
Air Transport ◽  
Civil Aviation ◽  
Undergraduate Studies ◽  
Recommended Practices ◽  
The University ◽  
Navigation Safety

"Introduction to Risk and Safety of Air Navigation" is an authorized script compiled on the basis of the curriculum of the course "Introduction to Risk and Safety of Air Navigation" which is taught in undergraduate studies at the University of Belgrade - Faculty of Transport and Traffic Engineering. The scripts are primarily intended for students of undergraduate (bachelor) studies at the Department of Air Transport and Traffic at the University of Belgrade - Faculty of Transport and Traffic Engineering. Scripts can be useful to both master's and doctoral students at the University of Belgrade - Faculty of Transport and Traffic Engineering, especially those who have not completed undergraduate studies at the Department of Air Transport and Traffic. They can also be useful to air transport and aeronautical engineers in order to expand and update knowledge in the field of air navigation safety. The material presented in these scripts relates mainly to civil aviation and is largely based on international standards, recommended practices, regulations and documents which deal with issues related to air navigation safety. As these standards, regulations and documents are subject to frequent changes and alterations, users of these scripts are advised to also use the original (updated) documents, which are listed in the references, in order to take into account any changes that have occurred after the release of the scripts.

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