This document provides information about cesium formate brine, including its uses, benefits, and the company that produces it. Specifically:
- Cesium formate brine is a high-density, non-toxic brine used for drilling, completing, and suspending deep gas wells. It can have densities up to 143 pcf.
- Using cesium formate brine improves economics by allowing faster drilling and completions while improving well safety. It also maximizes reservoir production and definition.
- Cabot Corporation produces cesium formate brine from pollucite ore in Canada. It has been used in over 250 deep gas wells worldwide since 1999.
The document discusses drilling fluids or mud, which are fluids circulated during drilling operations. There are several types of drilling fluids including water-based, oil-based, foam-based, and synthetic-based fluids. Drilling fluids serve various important functions including removing cuttings from the well, controlling formation pressure, maintaining wellbore stability, minimizing damage to the reservoir, and cooling and lubricating the drill bit. The appropriate type of drilling fluid depends on factors like the desired performance, environmental considerations, safety, cost, and availability. Water-based and oil/synthetic-based fluids are described in more detail. The document also outlines various properties and tests used to analyze the characteristics of drilling fluids.
This document discusses various aspects of well planning such as pore pressure and fracture gradient determination, casing depth selection, and well configuration. It describes the different types of well planning for exploration, development, and completion/workover. Key factors in well planning include interaction between drilling and other departments to optimize costs, and fully evaluating rig and well design options. Typical well casing includes conductor, surface, intermediate, and production casing. Formulas are provided for pore pressure prediction based on overburden stress, hydrostatic pressure, and compaction effects. Criteria for selecting casing setting depths include controlling formation pressures and preventing differential pressure sticking.
The document discusses the concept of skin factor in wellbore flow, which is a dimensionless quantity that describes flow efficiency. A positive skin factor indicates damage that restricts flow, while a negative skin indicates flow enhancement. Skin can result from various factors like partial completion, damage near the wellbore, hydraulic fracturing, or deviation of the well from vertical. Equations are provided to calculate the pressure drop and flow efficiency based on the skin factor. The total skin is the sum of individual skin components from different sources like damage, completion, deviation etc.
This document discusses drilling fluid systems and their functions. It describes the classification of drilling muds as water-based or oil-based. Water-based muds can be further broken down and include bentonite muds, polymer muds, and muds with additives like gypsum, lime, potassium/lime, and mixed metal hydroxide. Oil-based muds include invert emulsion and mineral/synthetic oil-based muds. Key functions of drilling fluids are cooling and lubricating the drill bit, carrying cuttings to the surface, controlling formation pressure, and maintaining wellbore stability. Common measurements of mud properties are also outlined.
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
This document discusses sustainable drilling fluid solutions. It begins with basic terminology used in drilling fluids like mud types, additives, and functions of mud. Water-based mud and oil-based mud are compared, noting that WBM is less toxic and can meet environmental issues but is not stable above 400°F, while OBM is stable above 400°F but more toxic. New developments in bio-polymers are discussed that can viscosify drilling fluids with less toxicity and better stability. In conclusion, water-based muds with bio-polymers are the most sustainable option while also addressing environmental concerns related to drilling fluids.
Complete Casing Design with types of casing, casing properties, casing functions, design criteria and properties used for designing and one numerical problem
The fifth presentation of a series of presentations on Operations Geology. Very basic, just to introduce beginners to operations geology. I hope the end users will find this and the following presentations very helpful.
This document discusses key properties of crude oil, including:
1) Oil is classified based on properties like specific gravity, viscosity, density, etc. with specific gravity and viscosity most commonly used. Specific gravity is represented by API gravity which ranges from 8 to 58 degrees.
2) Bubble point pressure is the pressure at which a small amount of gas is in equilibrium with oil. When pressure drops below this point, gas is liberated from the oil.
3) Other properties discussed include formation volume factor (ratio of reservoir to surface volumes), solution gas-oil ratio (amount of gas dissolved in oil), and compressibility (change in volume with pressure change).
That is my presentation for my grad research about reservoir geomechanics, hope you find it useful, and my source book was reservoir geomechanics for prof Mark Zoback, soon the PDF copy will be available as well.
Drilling operations can encounter various problems related to geological uncertainties, wellbore stability issues, and depletion effects. Some key risks include uncertainties in pore pressure-fracture gradient measurements, mud volcanoes causing landslides or weak formations, fault zones providing pathways for fluid flow, and maintaining wellbore integrity in low-pressure depleted zones. Operators address these challenges through careful planning, identifying potential hazard areas using seismic data, selecting appropriate drilling fluid properties, and employing wellbore strengthening techniques and lost circulation materials when needed to prevent fluid losses and wellbore collapse.
After drilling is completed, wells undergo completion procedures to prepare them for production. This involves setting production casing and cementing it through the target zone. Tubing is run inside the casing with a packer to isolate the production zone. A Christmas tree is installed to control flow. Completion types include open hole, liners, and perforated casing. Perforating creates holes through casing into the formation. Some formations require stimulation like acidizing to improve permeability or fracturing to create conductive fractures held open by proppant. This increases flow into the wellbore.
This document provides an overview of designing wells for high pressure high temperature (HPHT) environments. It discusses HPHT definitions, challenges, case studies, and recommendations for various well design aspects. Key points include defining three HPHT envelopes based on temperature and pressure limits, outlining completion, testing and data acquisition challenges, reviewing global HPHT fields and standards, analyzing an Indian HPHT case study, and providing recommendations for casing design, drilling fluids, cementing, and material selection tailored for HPHT wells.
The document discusses casing design considerations. It begins by outlining the general criteria considered in casing design, including loading conditions, formation strength, availability/cost of casing strings, and expected deterioration over time. It then describes how casing is designed to withstand burst, collapse, tension, and biaxial stresses using safety factors. Graphical and mathematical methods are presented for designing casing strings to meet differential pressure requirements at varying depths. Considerations like centralizer spacing and stretch are also covered. The document provides a detailed overview of the factors and calculations involved in optimizing casing design.
about 70 % of the existing reservoirs are impossible to reach with conventional drilling . MPD or managed pressure drilling is the best solution for HPHT and very deep reservoirs .
This document discusses various reservoir drive mechanisms used for oil recovery. It begins by defining reservoir drive mechanisms and categorizing recovery stages into primary, secondary, and tertiary. For primary recovery, the drive mechanisms described are solution gas drive, gas cap drive, water drive, and gravity drainage. Secondary recovery involves waterflooding and gasflooding to maintain pressure. Tertiary or EOR recovery discussed includes thermal methods using steam/hot fluids, chemical methods using polymers/surfactants, and miscible gas injection. Infill recovery occurs late in a reservoir's life through additional drilling.
Farida Ismayilova has over 3 years of experience working for BP in drilling geohazards and PPFG specialization. She has a Bachelor's and Master's degree in Petroleum Engineering from Azerbaijan State Oil and Industry University. The presentation provides an overview of PPFG terms and principles, and the role of PPFG in well planning. It discusses basics like pore pressure, fracture gradient, and the PPFG window. It also explains how a PPFG specialist incorporates data from nearby wells to estimate high, base, and low cases for safe well design and mud weight selection.
This document provides an overview of key concepts in drilling engineering related to pore pressure prediction and fracture gradient determination. It discusses how pore pressures are estimated based on geology, porosity logs, and seismic data. Formations can be normally or abnormally pressured depending on factors like compaction. Leak-off tests are used to directly measure fracture gradients and determine maximum safe mud weights. Understanding pore pressure and fracture gradients is essential for well planning activities like mud weight selection and casing design.
The document discusses the use of formate brines, specifically cesium formate brine, as drilling, completion and suspension fluids for deep, high pressure high temperature (HPHT) gas wells. Cesium formate brine provides benefits such as stability at high temperatures, compatibility with reservoirs, and less corrosion and damage compared to other brines. It has been used successfully in over 50 HPHT gas field developments worldwide, enabling improved well construction methods like open hole completions.
The document discusses the use of formate brines, specifically cesium formate brine, as drilling, completion and suspension fluids for deep, high pressure high temperature (HPHT) gas wells. Cesium formate brine provides benefits such as stability at high temperatures, compatibility with reservoirs, and less corrosion and damage compared to other brines. It has been used successfully in over 50 HPHT gas field developments worldwide, enabling improved well construction methods like open hole completions.
SPE 145562 - Life Without Barite: Ten Years of Drilling Deep HPHT Gas Wells ...John Downs
The tradition of using barite to increase the weight of drilling fluids dates back to the early-1920’s and, while it has been of great benefit to the oil industry over the past 90 years, it has also caused some chronic and persistent well construction problems along the way. These problems, which are very familiar to drillers, include well control difficulties, stuck pipe incidents and formation damage.
The oil industry has known since the 1970’s that replacing barite with suitable non-damaging solutes in reservoir drill-in fluids is an effective way of reducing formation damage, simplifying operations and eliminating the need for expensive formation damage by-pass operations. The development of brine-based drill-in fluids opened up the opportunity to connect more effectively with hydrocarbon reserves by allowing the construction of long high-angle reservoir sections completed in open hole. Despite the advantages on offer, the industry was unable to exploit this novel technology in deep HPHT gas field developments until the mid- to late-1990’s when drill-in fluids based on potassium and cesium formate brine became available in commercial volumes.
Cesium formate brine was first used as a reservoir drilling fluid in the Huldra gas/condensate field in the North Sea in January 2001, and has now been used to drill a total of 29 deep HPHT gas wells. The information presented and reviewed in this paper confirms that the use of potassium and cesium formates as the sole weighting agents in reservoir drill-in fluids has enabled operators to enjoy the full economic benefits of creating low-skin open-hole completions in deep high-angle HPHT gas wells. The review also concludes that the use of these heavy formate brines as drill-in fluids over the past 10 years has facilitated the safe and efficient development of deep HPHT gas reserves by:
• Virtually eliminating well control and stuck pipe incidents
• Enabling the drilling of long high-angle HPHT wells with narrow drilling windows
• Typically reducing offshore HPHT well completion times by 30 days or more
• Improving the definition and visualization of the reservoirs
• Eliminating the need for clean-ups, stimulation treatments or any other form of post-drilling well intervention to remove formation damage caused by the drilling fluid
This has all been made possible by the operators’ acceptance and adoption of the award-winning Chemical Leasing (ChL) and fluid management programmes that form the basis of their contracts with the sole producer of cesium formate brine. The use of the ChL model has played an important role in reducing the unnecessary consumption of what is a very rare and valuable chemical resource
SPE 165151 - The Long-term Production Performance of Deep HPHT Gas Condensat...John Downs
Formate brines have been in use since 1995 as non-damaging drill-in and completion fluids for deep HPHT gas condensate field developments. The number of HPHT fields developed using formate brines now totals more than 40, and includes some of the deepest, hottest and highly-pressured reservoirs in the North Sea. The well completions have been both open-hole and cased-hole.
An expectation from using formate brines as reservoir drill-in and completion fluids is that they will cause minimal damage to the reservoir and help wells to deliver their full productive potential over the life-time of the field. The validity of this expectation has been tested by examining the long-term hydrocarbon production profiles of eight HPHT gas condensate fields in the North Sea where only formate brines have been used as the well completion fluids. In five of these fields the wells were drilled with oil-based muds and completed by perforating in cased hole with high-density formate brines. In another two of the fields the wells were drilled with formate brines and completed with screens entirely in open hole using the same brines. The last of the eight fields was drilled with formate brine and the wells were then completed with same fluid in either open hole or cased hole.
The results of the production analysis provide a unique insight into the impact of a single type of specialist drill-in and completion fluid on the rate of recovery of hydrocarbon reserves from deeply-buried reservoirs in the North Sea
SPE 165151 The Long-Term Production Performance of Deep HPHT Gas Condensate ...jdowns
Maps and analyses the long-term production of eight HPHT gas and condensate fields in which formate brines were the last well construction fluids to contact the producing reservoirs
This document discusses the use of cesium formate brine as a drilling, completion, and workover fluid for high pressure, high temperature (HPHT) gas wells over the past 10 years. Some key points:
- Cesium formate brine is non-toxic, compatible with reservoirs, and less corrosive than other brines like bromide brines.
- It has been used successfully in over 40 HPHT gas fields worldwide, enabling improved well control and safer drilling operations compared to other fluids.
- Specific examples from the North Sea highlight its effectiveness as a combined drill-in and completion fluid, resulting in low skin factors and high well productivity.
This document summarizes a presentation on the use of formate brines for deep gas field development projects. It finds that formate brines provide operational efficiencies over conventional drilling fluids by providing a more stable wellbore, faster tripping speeds, and fewer well control incidents. These efficiencies can reduce well construction costs and times. The document also finds that fields developed using only formate brines were able to recover 90% of reserves within 7-8 years, indicating formate brines may enable more efficient production.
A review of the use of potassium formate brine weighted with Micromax as a high-density well drilling and completion fluid for HPHT wells. Advantages include improved production and improved well logging.
Open-hole sand-control completions using expandable sand screens (ESS) offer advantages over traditional cased-hole completions including improved production rates and lower installation costs. The documents discusses several case studies where formate brines and ESS were used together, setting world records for longest, hottest, and deepest ESS installations. This included projects by Shell in the Brigantine field in the UK North Sea and by Saudi Aramco in the K-field in Saudi Arabia, improving well economics in both cases.
This document provides information about Plasticon Composites International Contracting B.V., a company that produces fiberglass tanks and other products. Some key details:
- Plasticon has over 700 employees across 16 production facilities in 13 countries, with an annual production capacity of around 1.5 million hours and installation project capacity of 200,000 hours.
- Fiberglass products offer benefits like low maintenance, corrosion resistance, chemical resistance, and lifespan of up to 50 years.
- Plasticon produces a range of products including storage tanks up to 30 meters in diameter, silos, process equipment, piping systems, and more for industries like power, mining, and chemicals.
-
Innovative engineering design in circulating fluid bed technologyIgor Sidorenko
Sneyd, S., Sidorenko, I., Orth, A., & Laumann, M.-D. (2007) Innovative engineering design in circulating fluid bed technology. Paper presented at CHEMECA conference, Melbourne.
The document discusses the use of cesium formate brine as a drilling fluid for drilling deep high pressure, high temperature (HPHT) gas wells over the past 10 years. Some key points:
1) Cesium formate brine is an effective drill-in and completion fluid for HPHT gas wells that is non-toxic, compatible with reservoirs, and less corrosive than other brines.
2) Case studies show that cesium formate brine has been used successfully as a combined drill-in and completion fluid for open hole completions in over 40 HPHT gas fields worldwide.
3) Its first use as a combined drill-in and completion fluid was in 2001 in
The document discusses the use of cesium formate brine as a drilling fluid for drilling deep high pressure, high temperature (HPHT) gas wells over the past 10 years. Some key points:
1) Cesium formate brine is an effective drill-in and completion fluid for HPHT gas wells that is non-toxic, compatible with reservoirs, and less corrosive than other brines.
2) It has been used successfully in over 42 HPHT gas fields worldwide to drill and complete wells with maximum reservoir temperatures up to 320°F.
3) Specifically, cesium formate brine has enabled operators to construct high-angle open hole screen completions in HPHT reservoirs
The document summarizes the installation of an innovative "Capillary Conveyed" gas lift extension system in a well in Vietnam. The existing gas lift system was no longer effective due to declining reservoir pressures. The new system used a 0.75" diameter capillary string to extend the gas lift injection point deeper into the well. After installation, the well resumed production, flowing for 60 days at rates exceeding expectations before being placed on a production cycle. Cumulative production since was 43,000 barrels of oil, with an estimated payback of only 4 days for the installation. The installation demonstrated that the new technology can effectively reinstate production from wells with inefficient gas lift systems.
- Fishbones is a technology company that provides multilateral stimulation solutions like jetting and drilling to increase production from oil and gas wells.
- They have over 20 installations globally with proven results like increased and sustained production, improved injectivity, and reduced environmental impact.
- Case studies demonstrated Fishbones' ability to unlock tight reservoirs and increase production over 2x in some cases by accurately connecting the reservoir.
SPE 199286 - Profiling the Production Performance of Five HPHT Gas Condensate...John Downs
1. The document discusses production performance from five high-pressure, high-temperature gas condensate wells in the Kvitebjorn Field in the Norwegian North Sea that were drilled and completed using cesium formate drilling fluids.
2. Logging data obtained using cesium formate brine showed improved reservoir quality, leading to a 33% increase in estimated hydrocarbon reserves. Actual cumulative production from the field has matched or exceeded revised reserve estimates.
3. Cumulative production from the initial five wells after 14 years is now higher than the original reserves projection for the entire field, demonstrating the benefits of using cesium formate fluids for drilling and completion.
This document discusses the development of a low carbon cement binder using amorphous calcium aluminate. It aims to reduce the carbon footprint of cement by replacing clinker with supplementary cementitious materials (SCMs) like GGBS, limestone, and metakaolin. Test results show that adding 8% amorphous calcium aluminate significantly improves early strength development and shortens setting time, independently of the SCMs used. This allows for lower binder content while maintaining performance. The optimal blend developed is a stable, fast-setting binder with a reduced carbon footprint compared to traditional cement. Further studies are ongoing to apply this approach to other low-carbon binder systems.
This document discusses split-zone oxidation, a new oxidation technology that can facilitate the development of larger, more economical 5,000+ tonne per year automotive and industrial carbon fiber production lines. Split-zone oxidation uses two independently controlled temperature zones within an oxidation oven to potentially reduce oxidation cycle times by 10-25% and lower the cost of operating oxidation systems by up to 50%. The document outlines how split-zone oxidation could enable doubling the nameplate capacity of carbon fiber production lines within the same factory footprint, making larger scale automotive carbon fiber production more economically feasible. It proposes demonstration and validation trials of split-zone oxidation technology to prove its performance and cost savings.
Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fiel...Juan Diego Suarez Fromm
Two field examples will be presented, where after 50 years of development; fresh oil and gas were produced by changing some reservoir paradigms.
Upsides could be overlooked due to paradigms on field development. The successful one in terms of reserves and cost effective capital expenditure could be visualized as “finding the key for the field”. But as development takes place over many years (decades), the “key” should be a dynamic concept over time, correlated with technology availability, enabling us a better understanding of petroleum resources size, quality and distribution.
SPE 24973 35 mm slides in Powerpoint .pptxJohn Downs
Scanned copies of the original 35 mm slides used in the presentation of SPE paper 24973 by John Downs of Shell at the European Petroleum Conference held in Cannes, France, 16-18 November 1992
Single cell protein (SCP) from methane and methanol - publications from Shell...John Downs
The Fermentation and Microbiology (FMB) department of Shell Research Centre in Sittingbourne was a leader in the development of single cell protein (SCP) production from methane and methanol in the 1970's. This updated presentation lists virtually all of the publications from the Shell scientists engaged at that time in the development of a single cell protein production process using methane and methanol as the carbon feedstocks. Their main focus was growing Methylococcus capsulatus in continuous culture on methane.
A Walk Through Devon - Day 6 - Morchard Bishop to Five Crosses John Downs
Day 6 of an 8-day walk through Devon. An 8-mile walk from Morchard Bishop to Five Crosses on a route that could be used by Lands End to John O'Groats long distance walkers passing through the county
A Walk through Devon - Day 5 - Bondleigh Bridge to Morchard Bishop John Downs
Day 5 of an 8-day walk through Devon. An 8-mile walk from Bondleigh Bridge to Morchard Bishop on a route that could be used by Lands End to John O'Groats long distance walkers passing through the county
A Walk through Devon - Day 4 - Stockley Hamlet (Okehampton) to Bondleigh BridgeJohn Downs
Day 4 of an 8-day walk through Devon. An 8-mile walk from Stockley Hamlet to Bondleigh Bridge on a route that could be used by Lands End to John O'Groats long distance walkers passing through the county
Day 2 of a walk through Devon - From Lewdown to Bridestowe. The entire set of " A Walk through ..." walks currently covering the south-west of England from Lands End up into the Cotswolds could be used as a route guide by Lands End-John O'Groats (LEJOG) walkers
Day 1 of a walk through Devon - From Launceston on the Cornwall /Devon border to Lewdown in Devon. The entire set of " A Walk through ..." walks currently covering the south-west of England from Lands End up into the Cotswolds could be used as a guide by Lands End-John O'Groats (LEJOG) walkers
A Ramble through Cornwall - Day 8 - Bodmin to St Neot John Downs
A short (7 mile) walk from the outskirts of Bodmin east to St Neot, skirting the southern border of Bodmin Moor. Mostly walking in fog on this particular day
This document summarizes the key findings of a study on the effects of different well construction fluids on rig time savings. The study analyzed 89 North Sea wells and found that switching from oil-based muds to cesium or potassium formate fluids can save up to 26 days of rig time. Specifically, using formate fluids for open-hole standalone sand screen completions can save over 3.5 weeks compared to cased and perforated completions using oil-based muds. Formate fluids also significantly reduce completion times for both well construction techniques and increase drilling rates of penetration compared to oil-based muds.
DMK chose potassium formate brines over invert oil-based muds for drilling long horizontal wells in the abrasive Montney shales. They experienced significant cost and time savings from increased drilling rates of penetration (ROP), longer bit life, improved wellbore cleaning, and lower equivalent circulating densities (ECDs). Operators saw ROP improvements of 30-50% and bit runs twice as long as with oil-based muds. Using solids-free potassium formate brine allowed excellent horizontal wellbore cleaning without cuttings beds forming and reduced circulating pressures.
Cesium formate brine has been used as a completion and perforation fluid in 15 wells across 11 high-pressure, high-temperature (HPHT) gas fields in the UK sector of the North Sea since 1999. It was first used in Shell's Shearwater field and then Total's Elgin/Franklin field, the world's largest HPHT field. Since then it has been used in 12 additional HPHT wells in various fields. Production rates from wells completed with cesium formate brine have ranged from 1.6 to 2.6 million cubic meters per day. Some individual wells have achieved over 30,000 barrels of oil equivalent per day. Thirteen years after its first use, cesium
This document summarizes Cabot Specialty Fluids' (CSF) sustainable business model of leasing cesium formate brines and retaining ownership of the chemicals. This model encourages efficiency by charging clients based on time used rather than consumption. It also aligns incentives between CSF and clients to minimize waste. The model has proven successful, with CSF normally recovering 80-85% of leased brines. The document notes UNIDO's support for innovative concepts like CSF's model that reduce chemical consumption and waste. CSF was honored with a UNIDO award for its contributions to advancing chemical leasing programs.
The document discusses eco-efficiency analysis conducted by BASF to compare the eco-efficiency of formate brines and bromide brines. The analysis found that formate brines were significantly more eco-efficient than bromide brines. Formate brines scored better on costs, lower toxicity potential, and lower emissions. In particular, bromide brines produced large amounts of toxic waste that required special treatment. While formate brines required more salt overall, they offered a more sustainable solution for the scenario of completing a well in the North Sea. BASF concluded that formate brines were the most eco-efficient option based on both environmental and economic factors.
Use Cases & Benefits of RPA in Manufacturing in 2024.pptxSynapseIndia
SynapseIndia offers top-tier RPA software for the manufacturing industry, designed to automate workflows, enhance precision, and boost productivity. Experience the benefits of advanced robotic process automation in your manufacturing operations.
Using LLM Agents with Llama 3, LangGraph and MilvusZilliz
RAG systems are talked about in detail, but usually stick to the basics. In this talk, Stephen will show you how to build an Agentic RAG System using Langchain and Milvus.
TrustArc Webinar - 2024 Data Privacy Trends: A Mid-Year Check-InTrustArc
Six months into 2024, and it is clear the privacy ecosystem takes no days off!! Regulators continue to implement and enforce new regulations, businesses strive to meet requirements, and technology advances like AI have privacy professionals scratching their heads about managing risk.
What can we learn about the first six months of data privacy trends and events in 2024? How should this inform your privacy program management for the rest of the year?
Join TrustArc, Goodwin, and Snyk privacy experts as they discuss the changes we’ve seen in the first half of 2024 and gain insight into the concrete, actionable steps you can take to up-level your privacy program in the second half of the year.
This webinar will review:
- Key changes to privacy regulations in 2024
- Key themes in privacy and data governance in 2024
- How to maximize your privacy program in the second half of 2024
EuroPython 2024 - Streamlining Testing in a Large Python CodebaseJimmy Lai
Maintaining code quality through effective testing becomes increasingly challenging as codebases expand and developer teams grow. In our rapidly expanding codebase, we encountered common obstacles such as increasing test suite execution time, slow test coverage reporting and delayed test startup. By leveraging innovative strategies using open-source tools, we achieved remarkable enhancements in testing efficiency and code quality.
As a result, in the past year, our test case volume increased by 8000, test coverage was elevated to 85%, and Continuous Integration (CI) test duration was maintained under 15 minute
"Mastering Graphic Design: Essential Tips and Tricks for Beginners and Profes...Anant Gupta
Discover the art of graphic design with our comprehensive guide tailored for both beginners and seasoned professionals. Learn essential tips and tricks, explore the best design tools and software, and get inspired by creative design ideas. Whether you're just starting out or looking to refine your skills, this guide has everything you need to master the world of graphic design. Dive into topics ranging from basic principles to advanced techniques and stay ahead in the ever-evolving design industry.
Vulnerability Management: A Comprehensive OverviewSteven Carlson
This talk will break down a modern approach to vulnerability management. The main focus is to find the root cause of software risk that may expose your organization to reputation damage. The presentation will be broken down into 3 main area, potential risk, occurrence, and exploitable risk. Each segment will help professionals understand why vulnerability management programs are so important.
Ivanti’s Patch Tuesday breakdown goes beyond patching your applications and brings you the intelligence and guidance needed to prioritize where to focus your attention first. Catch early analysis on our Ivanti blog, then join industry expert Chris Goettl for the Patch Tuesday Webinar Event. There we’ll do a deep dive into each of the bulletins and give guidance on the risks associated with the newly-identified vulnerabilities.
BLOCKCHAIN TECHNOLOGY - Advantages and DisadvantagesSAI KAILASH R
Explore the advantages and disadvantages of blockchain technology in this comprehensive SlideShare presentation. Blockchain, the backbone of cryptocurrencies like Bitcoin, is revolutionizing various industries by offering enhanced security, transparency, and efficiency. However, it also comes with challenges such as scalability issues and energy consumption. This presentation provides an in-depth analysis of the key benefits and drawbacks of blockchain, helping you understand its potential impact on the future of technology and business.
Litestack talk at Brighton 2024 (Unleashing the power of SQLite for Ruby apps)Muhammad Ali
Exploring SQLite and the Litestack suite of SQLite based tools for Ruby and Rails applications. Litestack offers a SQL database, a cache store, a job queue, a pubsub engine, full text search and performance metrics for your Ruby/Ruby-on-Rails apps
Kief Morris rethinks the infrastructure code delivery lifecycle, advocating for a shift towards composable infrastructure systems. We should shift to designing around deployable components rather than code modules, use more useful levels of abstraction, and drive design and deployment from applications rather than bottom-up, monolithic architecture and delivery.
‘‘Figma AI’’ is one of the sophisticated Artificial Intelligence based digital design and prototyping tools which has transformed the way of designers shape and share the user interfaces and experience. In essence, Figma AI is a set of advanced AI technologies aimed at improving design operations’ productivity, innovation, and accuracy. Here’s a detailed exploration of what Figma AI offers:Here’s a detailed exploration of what Figma AI offers:
**Intelligent Design Assistance:**
Another form of AI used in Figma is Real-Time Collaboration and Suggestions that go further by providing the designers with improvements as they design. It utilizes design, layout, and user flow analysis algorithms that involve machine learning to give well-structured recommendations based on the site’s design and layout as well as other designs in the current market. Moreover, this capability not only brings advantages in the aspect of time; it also benefits from the viewpoints of homogeneity and practicability across the projects.
**Automated Prototyping:**
It is also noteworthy that Figma AI can autonomously work on creating prototypes. Designers can provide the core functionalities and limitations of a system and the AI engine forms hypotheses of the prototypes which can be animated and include features like buttons and sliders. This minimize hours of work, and enable designers to work on polishing interaction and user experience aspects rather than having to create prototypes from the ground.
**Adaptive Design Systems:**
Figma AI helps in using the design systems that automatically adapt to various optimal graphic sizes and contexts of the devices. From the users’ statistics and reviews, it can propose slight modifications of the design elements that work best on different devices. This makes the deliveries user-friendly for all consumers irrespective of how they come across the product.
**Natural Language Interface:**
Another great special inclusion in Figma AI is the incorporation of NLI, which incorporates natural language to come with designers in a plain language. Designers can state or explain what they want to design, ask about some principles in the design or even more ask to create a certain asset in design, while Figma AI answers with a related design suggestion or completes a given task.
**Collaborative Design Insights:**
Being an AI tool meant to help the design teams coordinate, Figma AI provides an insight into collaborative design choices and users’ feedback. It detects areas of possible design discrepancies, proposes changes based on amass data, and facilitates the quick redesign at the same time avoiding inefficiency of the design.
**Ethical Design Considerations:**
Acknowledging the hereby discussed problem of ethical design practices, Figma AI employs algorithms that bring attention to certain biases or accessorial concerns emerging from design decisions.
Integrating Kafka with MuleSoft 4 and usecaseshyamraj55
In this slides, the speaker shares their experiences in the IT industry, focusing on the integration of Apache Kafka with MuleSoft. They start by providing an overview of Kafka, detailing its pub-sub model, its ability to handle large volumes of data, and its role in real-time data pipelines and analytics. The speaker then explains Kafka's architecture, covering topics such as partitions, producers, consumers, brokers, and replication.
The discussion moves on to Kafka connector operations within MuleSoft, including publish, consume, commit, and seek, which are demonstrated in a practical demo. The speaker also emphasizes important design considerations like connector configuration, flow design, topic management, consumer group management, offset management, and logging. The session wraps up with a Q&A segment where various Kafka-related queries are addressed.
leewayhertz.com-AI agents for healthcare Applications benefits and implementa...alexjohnson7307
In recent years, the integration of artificial intelligence (AI) in various sectors has revolutionized traditional practices, and healthcare is no exception. AI agents for healthcare have emerged as powerful tools, enhancing the efficiency, accuracy, and accessibility of medical services. This article explores the multifaceted role of AI agents in healthcare, shedding light on their applications, benefits, and the future they herald.
For the full video of this presentation, please visit: https://www.edge-ai-vision.com/2024/07/deploying-large-language-models-on-a-raspberry-pi-a-presentation-from-useful-sensors/
Pete Warden, CEO of Useful Sensors, presents the “Deploying Large Language Models on a Raspberry Pi,” tutorial at the May 2024 Embedded Vision Summit.
In this presentation, Warden outlines the key steps required to implement a large language model (LLM) on a Raspberry Pi. He begins by outlining the motivations for running LLMs on the edge and exploring practical use cases for LLMs at the edge. Next, he provides some rules of thumb for selecting hardware to run an LLM.
Warden then walks through the steps needed to adapt an LLM for an application using prompt engineering and LoRA retraining. He demonstrates how to build and run an LLM from scratch on a Raspberry Pi. Finally, he shows how to integrate an LLM with other edge system building blocks, such as a speech recognition engine to enable spoken input and application logic to trigger actions.
4. Formate brine applications
Low-solids fluids for deep gas well constructions
• Reservoir drilling
• Completions
• Workovers
• Packer and long-term well suspensions
A mature field proven technology used in deep gas fields since
1995
5. Deep and/or HPHT gas fields developed using
formate brines, 1995-2009
Published information on 35 fields
Some deep and/or HPHT gas fields developed using formate brines
Country Fields Reservoir Description
Matrix
type
Depth, TVD
(metres)
Permeability
(mD)
Temperature
(oC)
Germany Walsrode,Sohlingen
Voelkersen,Idsingen
Sandstone 4,450-6,500 0.1-150 150-165
Hungary Mako Sandstone 5,692 - 235
Kazakhstan Kashagan Carbonate 4,595-5,088 - 100
Norway Huldra ,Njord
Kristin,Kvitebjoern
Tune, Valemon
Victoria
Sandstone 4,090-7,380 50-1,000 121-200
Pakistan Miano, Sawan Sandstone 3,400 10-5,000 175
Saudi Arabia Andar,Shedgum
Uthmaniyah
Hawiyah,Haradh
Tinat, Midrikah
Sandstone
and
carbonate
3,963-4,572 0.1-40 132-154
UK Braemar,Devenick
Dunbar,Elgin
Franklin,Glenelg
Judy, Jura, Kessog
Rhum, Shearwater
West Franklin
Sandstone 4,500-7,353 0.01-1,000 123-207
USA High Island Sandstone 4,833 - 177
6. Why oil companies like formate brines
They improve the profitability of HPHT gas field
developments
• Drill and complete faster and easier
• Improve well safety and reduce risk
• Maximise well performance
• Reduce the need for future well interventions
All simply from using a low-solids non-corrosive fluid
7. Low-solids fluids cut the costs of deep gas well
constructions by speeding up drilling operations
Cesium formate brine increases ROP by >100% in deep hard
rock drilling
Data from DOE Deep Trek project , see SPE 112731
Effect of Mud on Rate of Penetration
Carthage Marble with 7 Blade PDC Bit
0
10
20
30
40
50
0 5,000 10,000 15,000 20,000 25,000 30,000
Weight on Bit (lbf)
RateofPenetration(ft/hr)
Water
16ppg OBM
16ppg CsFm
16ppg OBM + Mn
8. Cesium formate brine
• Cesium formate dissolved in water
• Density up to 19.2 ppg/143 pcf
• Non-toxic
• Safe to handle, pH 9-10
• Little or no risk to the environment
• Non-corrosive
• Minimizes formation damage
Cesium formate
2.3 s.g.
9. • Cabot founded in 1882
• Headquarters in Boston, USA
• Operates 39 plants in 20 countries
• Approximately 4,200 employees
• 2008 sales of $ 3.2 billion
Cesium formate brine manufactured by a
division of Cabot Corporation
11. Cabot produces cesium formate brine at
Lake Bernic in Canada from pollucite ore
Pollucite ore
Cs0.7Na0.2Rb0.04Al0.9Si2.1O6·(H20)
• Mined at Bernic Lake, Manitoba
• Processed on site to Cs formate brine
• Cs formate brine production 700 bbl/month
• Brine stocks > 30,000 bbl
12. Cesium formate brines used in 253 deep HPHT
gas wells since 1999
Drilling, completion, workover and suspension fluids
• At densities up to SG 2.25 (18.7 ppg or 140.2 pcf)
• At BHST up to 235oC (450oF)
• For periods of up 2 years dowhole (well suspensions)
• In sandstone and carbonate reservoirs, 0.01 mD up to 4 Darcy
• Wide variety of completions – barefoot open hole, cased and
perforated, with sand screens and gravel packs
13. Cesium formate applications
253 jobs in 34 deep HPHT gas fields (see website for list)
• Drill-in - 35
• Completions - 130
- as a brine and in LSOBM formulations (98 pcf)
- outstanding as HPHT perforating kill pill (Visund, Braemar, Judy, Rhum)
• Workovers and miscellaneous – 88
Includes diverse uses:
- Long-term well suspension
- Well testing
- Stuck-pipe release pill (OBM drilling)
- Melting hydrate plugs
14. Cesium formate brine was first used in the world’s
largest HPHT gas field development – Elgin/Franklin
Also the deepest HPHT gas field in North Sea
B
Cesium formate brine used by TOTAL in
34 well construction operations in 8
deep gas fields in period 1999-2010
15. Use of cesium formate by TOTAL in the
Elgin/Franklin field November 1999 - present
18.2 ppg/136 pcf completion fluid in 8 wells
• UK North Sea
• World’s largest HPHT field
• Gas condensate reservoir
• 16,000 psi @ 20,000ft
• BHST 400oF
• 140,000 bbl/day of condensate
• 13 million m3 gas /day
• Brine left in wells for up to 24 months (well suspension)
16. Cost of renting 136 pcf Cs formate brine in
Elgin workovers
Elgin well
Total brine costs*
($, ’000)
G3 913
G4 830
G5 602
G6 879
G7 807
* Includes all brine rental, losses and reconditioning charges
17. Huldra field, HP/HT gas condensate
-BHST: 297oF
-TVD : 3,900 metres/12,795 ft
- Fluid density: 15.75 ppg/118 pcf
- 6 wells – 600 ft reservoir sections 5-7/8” at 45-55o
- 1–2,000 mD sandstone
-Open hole, wire wrapped screens
Justification for using formate
- Improve well control !
- Lower ECD
- Run completion in same fluid
- Low risk of screen plugging
- Shale stabilisation
- Lubricating
- Safe for crews
- Environmentally benign
2001 - Cesium formate brine first used by Statoil to drill
and complete 6 deep HPHT gas wells, offshore Norway
Operator had experienced kicks when using barite-weighted fluids
18. Economic benefits from the use of cesium formate
brine in deep gas field developments
“ a remarkable record of zero well control incidents in all 15
HPHT drilling operations and 20 HPHT completion operations”
Speed and safety
Better/safer drilling environment saves rig-time costs
- Stable hole: see LWD vs. WL calipers in shale
- Elimination of well control and stuck pipe incidents
- Good hydraulics, low ECD
- Good ROP in hard abrasive rocks
19. Economic benefits from use of cesium formate brine in
deep gas field developments
Speed and simplicity
Allowing faster and easier movements of tubulars and fluids
- Pipe and casing running speeds are faster
- Mud conditioning and flow-check times shorter
- Displacements simplified, and sometimes eliminated
(i.e. formate drilling fluid = formate completion fluid)
Quote by operator : “ Improved well economics by increasing trip speed”
20. Economic benefits from use of cesium formate brine in
deep gas field developments
Speed and simplicity. Getting it right first time
Faster completions
- Drill-in and completing with cesium
formate allows open hole completion
with screens
- Clean well bores mean no tool/seal
failures or blocked screens
- Completion time 50% lower than wells
drilled with OBM
Quote by operator : “ fastest HPHT completion operation ever performed in North Sea (12.7 days)”
21. Maximises well production - providing efficient delivery
of gas reserves (revenues)
Tune and Huldra fields – drilled and completed with formate brines
90% recovery of gas reserves (16-18 billion m3) produced in 7 to 8 years
0
10
20
30
40
50
60
70
80
90
100
0 5 10 15
RecoveryofGasReserves(%)
Time since start-up (years)
Huldra
Tune
Source : Norwegian Petroleum Directorate- Fact Pages - November 2009
22. Maximises well production - providing efficient delivery
of condensate reserves (revenues)
Tune and Huldra fields – drilled and completed with formate brines
90% recovery of condensate reserves (3-5 million m3) produced in 4 to 6 years
Source : Norwegian Petroleum Directorate- Fact Pages - November 2009
0
20
40
60
80
100
120
0 5 10
RecoveryofCondensateReserves
(%)
Time since start-up (years)
Huldra
Tune
23. Economic benefits from the use of cesium formate
brine in deep gas field developments
“Using photoelectric factor and bulk density data, combined with resistivity measurements from both
the LWD drill pass and the ream pass, produces a very reliable and consistent net reservoir
definition.”
Good reservoir definition in cesium formate brine
24. Economic benefits from the use of cesium formate
brine in deep gas field developments
“Applying a conductive drilling fluid in all production wells drilled in a field also provides the possibility of running
high quality resistivity image logs (FMI). Extensive use of such logs provides the geo-modelers with detailed
information regarding structural dip, depositional environment, sedimentary features, facies, and geological
correlations.”
Good reservoir definition in cesium formate brine
25. Why oil companies like cesium formate brine
Cesium formate brine improves the profitability of HPHT
gas field developments
• Drill and complete faster and easier
• Improve well safety and reduce risk
• Maximise well performance
• Reduce the need for future well interventions
• Precise definition of reservoir and fractures
26. Key information about cesium formate brine in
one slide ......
• High-density clear brine – 98 to 143 pcf
• Advanced drilling,completion and workover fluid for
deep gas wells – available though all mud companies
• Improves economics of deep gas field developments
- Faster, simpler and safer well constructions
- Accelerated production of recoverable reserves
- Enhanced reservoir definition and imaging
27. BRINEWISE
A Tool for Pricing the Full Operational Costs,
Waste and HSE Risk of Completion Fluids
Formate presentation to LUKSAR – December 2009
28. BrineWise calculates the full cost of owning and using
high-density completion fluids
Prices the full operational costs, waste costs and the cost of “incidents”
29. How BrineWise compares the true cost of
completion fluid options
Cost of using fluid
(waste, time,
handover to
production etc.)
Fluid costs
(price per bbl)
+ =
Operational
Costs related
to fluid choice
Operational
Costs
+
HSE related
costs
=
Overall
fluid related
cost for well
HSE costs
Consent &
Transport +
Cost of HSE risk
(scenario based)
=
HSE related
costs related
to fluid
choice
Cost of using fluid
(waste, time,
handover to
production etc.)
Fluid costs
(price per bbl)
+ =
Operational
Costs related
to fluid choice
Cost of using fluid
(waste, time,
handover to
production etc.)
Fluid costs
(price per bbl)
+ =
Operational
Costs related
to fluid choice
Operational
Costs
+
HSE related
costs
=
Overall
fluid related
cost for well
HSE costs
Consent &
Transport +
Cost of HSE risk
(scenario based)
=
HSE related
costs related
to fluid
choice
HSE costs
Consent &
Transport +
Cost of HSE risk
(scenario based)
=
HSE related
costs related
to fluid
choice
30. COMPARATIVE
NORMAL
OPERATIONAL
COSTS COST OF HSE
RELATED RISK
COMPARATIVE
AVERAGE COST
PER WELL (taking
into account the
HSE risk)
COSTS AT RISK
FOR THE
ALTERNATIVES
COMPARATIVE
FLUID COSTS
31. BrineWise calculates four cost scenarios
0
1 000 000
2 000 000
3 000 000
4 000 000
5 000 000
6 000 000
Fluid costs only Normal operation
costs
Costs of an
incident w ith
small to average
consequences
Costs of an
incident w ith
larger than
average
consequences
US$
Cesium Formate Zinc Bromide
32. BrineWise – Key management benefits
BrineWise allows systematic cost comparison of the
consequences of using particular completion fluids
• Systematic fluid evaluation and costing incorporating :
- Fluid cost
- Operational costs
- HSE costs
- Incident-related costs
• Shows costs for all operational departments - including cost
consequences for production
Best overall value (lowest cost) fluid option is clearly identified