The document discusses drilling fluids used in oil and gas drilling. It outlines the basic functions of drilling fluids, which include transporting cuttings to the surface, providing well control, preserving wellbore stability, minimizing formation damage, cooling and lubricating the drill string, and providing information about the wellbore. It also describes different types of drilling fluids, tests performed on drilling fluids, challenges related to drilling fluids like lost circulation and stuck pipe, and solids control and waste management techniques. The overall document provides a comprehensive overview of drilling fluids used in oil and gas drilling operations.
Drilling fluids are absolutely essential during the drilling process and considered the primary well control.
Know more now about such a very important component of the drilling process.
Formation Evaluation project (drill stem test DST)Gehad Alyazidy
What is DST?
DST Advantages and Disadvantages.
Explain the operations of a DST based on a labelled diagram including its pressure vs time plot.
By referring to a case study reported in open literature, explain the challenges facing the O&G companies to obtain reliable test results.
Drilling fluids are absolutely essential during the drilling process and considered the primary well control.
Know more now about such a very important component of the drilling process.
Formation Evaluation project (drill stem test DST)Gehad Alyazidy
What is DST?
DST Advantages and Disadvantages.
Explain the operations of a DST based on a labelled diagram including its pressure vs time plot.
By referring to a case study reported in open literature, explain the challenges facing the O&G companies to obtain reliable test results.
Industry studies show that mature fields currently account for over 70% of the world’s oil and gas production. Increasing production rates and ultimate recovery in these fields in order to maintain profitable operations, without increasing costs, is a common challenge.
This lecture addresses techniques to extract maximum value from historical production data using quick workflows based on common sense. Extensive in-depth reservoir studies are obviously very valuable, but not all situations require these, particularly in the case of brown fields where the cost of the study may outweigh the benefits of the resulting recommendations.
This lecture presents workflows based on Continuous Improvement/LEAN methodology which are flexible enough to apply to any mature asset for short and long term planning. A well published, low permeability brown oil field was selected to retroactively demonstrate the workflows, as it had an evident workover campaign in late 2010 with subsequent production increase. Using data as of mid-2010, approximately 40 wells were identified as under-performing due to formation damage or water production problems, based on three days of analyses. The actual performance of the field three years later was then revealed along with the actual interventions performed. The selection of wells is compared to the selection suggested by the workflow, and the results of the interventions are shown. The field's projected recovery factor was increased by 5%, representing a gain of 1.4 million barrels of oil.
DRILLING FLUIDS FOR THE HPHT ENVIRONMENTMohan Doshi
A BRIEF REVIEW OF THE DRILLING FLUIDS FOR DRILLING HPHT WELLS. HPHT WELLS ARE NOT BUSINESS AS USUAL AND THE SAME APPLIES TO HPHT DRILLING FLUIDS. THE FLUID CHEMISTRY AND THE FLUID COMPOSITION HAVE TO BE TAILORED TO MEET THE RIGORS OF THE HIGH TEMPERATURE ENVIRONMENT
The lifecycle of developed fields, onshore and offshore will go through different stages of production up to the decline into late field life. Effective reservoir engineering management will lead to prolonging the life of field if a cost effective processing surface facilities strategy is put in place. Factors that lead to the decline in oil production or increase in OPEX may include increased water production, solids handling and the need for relatively higher compression requirements for gas lift. In order to maintain productivity and profitability, an effective holistic engineering approach to optimizing the process surface facilities must be utilized. The challenges of Optimizing Mature Field Production are: 1. Reservoir understanding with potential definition of additional reserves 2. Complete re-appraisal of the operability issues in the production facilities 3. Develop confidence to invest to optimize the process handling capabilities and capacity 4. Low CAPEX simplification of the surface facilities infrastructure to meet challenges 5. An implementation plan that recognizes the ‘Brownfield’ complexities 6. Selection of suitable optimum technology, configuration and training 7. Optimum upgrade plan of the facilities with minimum production losses Successful operation of mature fields and their surface facilities requires successful change management to the new operating strategy. Using a holistic approach can maximize the full potential of mature processing facilities at a manageable CAPEX and OPEX.
Dr. Wally Georgie Dr. Wally Georgie has a B.Sc degree in Chemistry, M.Sc in Polymer Technology, M.Sc in Safety Engineering and PhD in Applied Chemistry with training courses in oil and gas process engineering, production, reservoir and corrosion engineering. He has worked for over 37 years in different areas of oil and gas production facilities, including corrosion control, flow assurance, fluid separation, separator design, gas handling and produced water. He started his career in oil and gas services sector in 1978 based in the UK and working globally with different production issues then joined Statoil as senior staff engineer and later as technical advisor in the Norwegian sector of the North Sea. Working as part of operation team on oil and gas production facilities key focus areas included optimization, operation trouble-shooting, de-bottlenecking, oil water separation, slug handling, process verification, and myriad other fluid and gas handling issues. He then started working in March 1999 as a consultant globally both offshore and onshore, conventional and unconventional in the area of separation trouble shooting, operation assurance, produced water management, gas handling problems, flow assurance, system integrities and production chemistry, with emphasis in dealing with mature facilities worldwide.
Analyzing Multi-zone completion using multilayer by IPR (PROSPER) Arez Luqman
The primary objective of any well drilled and completed is to produce Hydrocarbons; by loading the Hydrocarbon (i.e. Oil and Gas) contained within the well through a conduit of the well and start separating it with surface facilities depending on type and composition of the Hydrocarbon.
Producing oil is simultaneously contained with problems depending on the type and properties of the reservoir.
Furthermore, what makes the problems much more; is when oil and/or gas is produced from multi-zones at the same time, when accumulated problems from all the producer zones occurring at the same time.
To help analyze this problems we are going to use PROSPER software package IPR multilayer, in which helps in identifying the relationship between Flow rate and Reservoir pressure.
Your Score 1420Not bad. Your score means youre slightly bette.docxodiliagilby
Your Score: 14/20
Not bad. Your score means you're slightly better than the average at reading expressions. And research suggests that people can improve their emotion recognition skills with practice. So keep an eye out for our forthcoming empathy training tool, designed to boost your emotional intelligence. Sign upfor our e-newsletter for updates on it.
Drilling Engineering
Class 8
1
Casing
• What is casing?
• Pipe that is API certified for its specific application
• Why is casing set?
• Zonal Isolation when cemented in place
• Casing point selection
• Regulations
• Area Geology
• Formation Pressures
• As the operator, who decides on casing points?
2
Casing
• API casing is available in standard sizes from 4-1/2” to 20” OD
• Usually steel but can be aluminum, fiberglass, stainless steel,
plastic, titanium etc.
• One piece of casing pipe is referred to as a “joint” of casing
• Casing length is dependent on the “range” of pipe
• Range-1: 18-22ft
• Range-2: 27-30ft
• Range-3: 38-45ft
• Casing Threads are defined by the coupling type
• API Threads
• LTC: Long thread coupling
• STC: Short thread coupling
• BTC: Buttress thread coupling
• Semi & Premium Threads
• See VAM Presentation
3
Casing
• Casing Components
• Casing
• Size, Weight, Grade, Threads
• 9-5/8" 53.5# P-110 LTC Rg 3
• See Casing Data Chart
• What is Drift Diameter?
• Pup Joints
• Float Collars
• Float Shoe
• Guide Shoe
• Centralizers
• Baskets
• Scratchers/Scrapers
4
Casing
• Running Casing
• Bales/Elevators
• Power Tongs
• Torque Turn
• Calculate weight and Hookload HL
• Calculate collapse, how often should you fill the pipe?
• Is the pipe taking the proper amount of fluid to fill? CSGcap
• Is the proper amount of fluid coming back to the pits as the
casing is run in the hole? CSGcap & CSGdisp
• Once casing is landed, circulated mud. Calculate B/U
5
Casing
• Centralization
• Vertical Wells
• Never truly vertical, usually spiral
• Typically use bow spring type centralizers
• There are state regulations on centralizer placement
• The shoe is very important to be centralized
• Horizontal Wells
• Balance between too many and not enough centralizers
• Many types: rigid, floating, bow spring, bladed, spiral bladed, etc.
• Centralizer design software can model the well as drilled and suggest
centralizer placement
• High dogleg areas need more frequent centralizers to obtain
sufficient standoff
6
Casing
• Stand-off
• Pipe Stand-off is a major contributor to hole cleaning, mud
removal, and cement quality.
• % 𝑆𝑡𝑎𝑛𝑑𝑜𝑓𝑓 = ൗ𝑊𝑛 𝑅2−𝑅1 ∗ 100%
7
Casing
• Stand-off
• The Stand-off formula results a percentage, where 0% represents
the pipe in contact with the wellbore wall. 100% represents the
pipe is perfectly centered in the well.
• When the pipe is not centered, the wider portions will promote
flow due to less resistance. There can be pockets of cuttings or
mud in the tighter areas causing
Operation & maintenance aspects of a Water treatment plant.Home
Operation and maintenance of a treatment plant is task. This is done to expand the life time of the treatment plant. So its necessary to keep the water treatment plant with a good look after on the hand of operation and also in maintenance both simultaneously. The given slides show some operation and maintenance processes to carry out a water treatment plant.
Industry studies show that mature fields currently account for over 70% of the world’s oil and gas production. Increasing production rates and ultimate recovery in these fields in order to maintain profitable operations, without increasing costs, is a common challenge.
This lecture addresses techniques to extract maximum value from historical production data using quick workflows based on common sense. Extensive in-depth reservoir studies are obviously very valuable, but not all situations require these, particularly in the case of brown fields where the cost of the study may outweigh the benefits of the resulting recommendations.
This lecture presents workflows based on Continuous Improvement/LEAN methodology which are flexible enough to apply to any mature asset for short and long term planning. A well published, low permeability brown oil field was selected to retroactively demonstrate the workflows, as it had an evident workover campaign in late 2010 with subsequent production increase. Using data as of mid-2010, approximately 40 wells were identified as under-performing due to formation damage or water production problems, based on three days of analyses. The actual performance of the field three years later was then revealed along with the actual interventions performed. The selection of wells is compared to the selection suggested by the workflow, and the results of the interventions are shown. The field's projected recovery factor was increased by 5%, representing a gain of 1.4 million barrels of oil.
DRILLING FLUIDS FOR THE HPHT ENVIRONMENTMohan Doshi
A BRIEF REVIEW OF THE DRILLING FLUIDS FOR DRILLING HPHT WELLS. HPHT WELLS ARE NOT BUSINESS AS USUAL AND THE SAME APPLIES TO HPHT DRILLING FLUIDS. THE FLUID CHEMISTRY AND THE FLUID COMPOSITION HAVE TO BE TAILORED TO MEET THE RIGORS OF THE HIGH TEMPERATURE ENVIRONMENT
The lifecycle of developed fields, onshore and offshore will go through different stages of production up to the decline into late field life. Effective reservoir engineering management will lead to prolonging the life of field if a cost effective processing surface facilities strategy is put in place. Factors that lead to the decline in oil production or increase in OPEX may include increased water production, solids handling and the need for relatively higher compression requirements for gas lift. In order to maintain productivity and profitability, an effective holistic engineering approach to optimizing the process surface facilities must be utilized. The challenges of Optimizing Mature Field Production are: 1. Reservoir understanding with potential definition of additional reserves 2. Complete re-appraisal of the operability issues in the production facilities 3. Develop confidence to invest to optimize the process handling capabilities and capacity 4. Low CAPEX simplification of the surface facilities infrastructure to meet challenges 5. An implementation plan that recognizes the ‘Brownfield’ complexities 6. Selection of suitable optimum technology, configuration and training 7. Optimum upgrade plan of the facilities with minimum production losses Successful operation of mature fields and their surface facilities requires successful change management to the new operating strategy. Using a holistic approach can maximize the full potential of mature processing facilities at a manageable CAPEX and OPEX.
Dr. Wally Georgie Dr. Wally Georgie has a B.Sc degree in Chemistry, M.Sc in Polymer Technology, M.Sc in Safety Engineering and PhD in Applied Chemistry with training courses in oil and gas process engineering, production, reservoir and corrosion engineering. He has worked for over 37 years in different areas of oil and gas production facilities, including corrosion control, flow assurance, fluid separation, separator design, gas handling and produced water. He started his career in oil and gas services sector in 1978 based in the UK and working globally with different production issues then joined Statoil as senior staff engineer and later as technical advisor in the Norwegian sector of the North Sea. Working as part of operation team on oil and gas production facilities key focus areas included optimization, operation trouble-shooting, de-bottlenecking, oil water separation, slug handling, process verification, and myriad other fluid and gas handling issues. He then started working in March 1999 as a consultant globally both offshore and onshore, conventional and unconventional in the area of separation trouble shooting, operation assurance, produced water management, gas handling problems, flow assurance, system integrities and production chemistry, with emphasis in dealing with mature facilities worldwide.
Analyzing Multi-zone completion using multilayer by IPR (PROSPER) Arez Luqman
The primary objective of any well drilled and completed is to produce Hydrocarbons; by loading the Hydrocarbon (i.e. Oil and Gas) contained within the well through a conduit of the well and start separating it with surface facilities depending on type and composition of the Hydrocarbon.
Producing oil is simultaneously contained with problems depending on the type and properties of the reservoir.
Furthermore, what makes the problems much more; is when oil and/or gas is produced from multi-zones at the same time, when accumulated problems from all the producer zones occurring at the same time.
To help analyze this problems we are going to use PROSPER software package IPR multilayer, in which helps in identifying the relationship between Flow rate and Reservoir pressure.
Your Score 1420Not bad. Your score means youre slightly bette.docxodiliagilby
Your Score: 14/20
Not bad. Your score means you're slightly better than the average at reading expressions. And research suggests that people can improve their emotion recognition skills with practice. So keep an eye out for our forthcoming empathy training tool, designed to boost your emotional intelligence. Sign upfor our e-newsletter for updates on it.
Drilling Engineering
Class 8
1
Casing
• What is casing?
• Pipe that is API certified for its specific application
• Why is casing set?
• Zonal Isolation when cemented in place
• Casing point selection
• Regulations
• Area Geology
• Formation Pressures
• As the operator, who decides on casing points?
2
Casing
• API casing is available in standard sizes from 4-1/2” to 20” OD
• Usually steel but can be aluminum, fiberglass, stainless steel,
plastic, titanium etc.
• One piece of casing pipe is referred to as a “joint” of casing
• Casing length is dependent on the “range” of pipe
• Range-1: 18-22ft
• Range-2: 27-30ft
• Range-3: 38-45ft
• Casing Threads are defined by the coupling type
• API Threads
• LTC: Long thread coupling
• STC: Short thread coupling
• BTC: Buttress thread coupling
• Semi & Premium Threads
• See VAM Presentation
3
Casing
• Casing Components
• Casing
• Size, Weight, Grade, Threads
• 9-5/8" 53.5# P-110 LTC Rg 3
• See Casing Data Chart
• What is Drift Diameter?
• Pup Joints
• Float Collars
• Float Shoe
• Guide Shoe
• Centralizers
• Baskets
• Scratchers/Scrapers
4
Casing
• Running Casing
• Bales/Elevators
• Power Tongs
• Torque Turn
• Calculate weight and Hookload HL
• Calculate collapse, how often should you fill the pipe?
• Is the pipe taking the proper amount of fluid to fill? CSGcap
• Is the proper amount of fluid coming back to the pits as the
casing is run in the hole? CSGcap & CSGdisp
• Once casing is landed, circulated mud. Calculate B/U
5
Casing
• Centralization
• Vertical Wells
• Never truly vertical, usually spiral
• Typically use bow spring type centralizers
• There are state regulations on centralizer placement
• The shoe is very important to be centralized
• Horizontal Wells
• Balance between too many and not enough centralizers
• Many types: rigid, floating, bow spring, bladed, spiral bladed, etc.
• Centralizer design software can model the well as drilled and suggest
centralizer placement
• High dogleg areas need more frequent centralizers to obtain
sufficient standoff
6
Casing
• Stand-off
• Pipe Stand-off is a major contributor to hole cleaning, mud
removal, and cement quality.
• % 𝑆𝑡𝑎𝑛𝑑𝑜𝑓𝑓 = ൗ𝑊𝑛 𝑅2−𝑅1 ∗ 100%
7
Casing
• Stand-off
• The Stand-off formula results a percentage, where 0% represents
the pipe in contact with the wellbore wall. 100% represents the
pipe is perfectly centered in the well.
• When the pipe is not centered, the wider portions will promote
flow due to less resistance. There can be pockets of cuttings or
mud in the tighter areas causing
Operation & maintenance aspects of a Water treatment plant.Home
Operation and maintenance of a treatment plant is task. This is done to expand the life time of the treatment plant. So its necessary to keep the water treatment plant with a good look after on the hand of operation and also in maintenance both simultaneously. The given slides show some operation and maintenance processes to carry out a water treatment plant.
Exploring Career Paths in Cybersecurity for Technical CommunicatorsBen Woelk, CISSP, CPTC
Brief overview of career options in cybersecurity for technical communicators. Includes discussion of my career path, certification options, NICE and NIST resources.
The Impact of Artificial Intelligence on Modern Society.pdfssuser3e63fc
Just a game Assignment 3
1. What has made Louis Vuitton's business model successful in the Japanese luxury market?
2. What are the opportunities and challenges for Louis Vuitton in Japan?
3. What are the specifics of the Japanese fashion luxury market?
4. How did Louis Vuitton enter into the Japanese market originally? What were the other entry strategies it adopted later to strengthen its presence?
5. Will Louis Vuitton have any new challenges arise due to the global financial crisis? How does it overcome the new challenges?Assignment 3
1. What has made Louis Vuitton's business model successful in the Japanese luxury market?
2. What are the opportunities and challenges for Louis Vuitton in Japan?
3. What are the specifics of the Japanese fashion luxury market?
4. How did Louis Vuitton enter into the Japanese market originally? What were the other entry strategies it adopted later to strengthen its presence?
5. Will Louis Vuitton have any new challenges arise due to the global financial crisis? How does it overcome the new challenges?Assignment 3
1. What has made Louis Vuitton's business model successful in the Japanese luxury market?
2. What are the opportunities and challenges for Louis Vuitton in Japan?
3. What are the specifics of the Japanese fashion luxury market?
4. How did Louis Vuitton enter into the Japanese market originally? What were the other entry strategies it adopted later to strengthen its presence?
5. Will Louis Vuitton have any new challenges arise due to the global financial crisis? How does it overcome the new challenges?
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2. Outline
Introduction.
Basic Function of Drilling Fluids.
Types of Drilling Fluids.
Drilling Fluid Tests.
Challenges Related to Drilling Fluids.
Solids Control and Waste Management.
3. Introduction
• Drilling-fluid system commonly known as the Mud System.
• Drilling-fluid systems are designed and formulated to perform
efficiently under expected wellbore conditions.
• The Capacity of the surface system usually is determined by the rig
capacity which is determined by the well design.
4. Outline
Introduction.
Basic Function of Drilling Fluids.
Types of Drilling Fluids.
Drilling Fluid Tests.
Challenges Related to Drilling Fluids.
Solids Control and Waste Management.
5. Basic Functions of Drilling Fluids
1. Transport Cuttings to Surface.
2. Primary Well-Control Method.
3. Preserve Wellbore Stability.
4. Minimize Formation Damage.
6. Basic Functions of Drilling Fluids (Cont.)
5. Cool and Lubricate the Drill String.
6. Provide Information About the Wellbore (Mud Logging).
7. Outline
Introduction
Basic Function of Drilling Fluids
Types of Drilling Fluids
Drilling Fluid Tests
Challenges Related to Drilling Fluids
Solids Control and Waste Management
9. Outline
Introduction.
Basic Function of Drilling Fluids.
Types of Drilling Fluids.
Drilling Fluid Tests.
Challenges Related to Drilling Fluids.
Solids Control and Waste Management.
10. Drilling Fluid Tests
There are two types of tests:
Field Tests
The drilling-fluids specialist in the field
(Mud Engineer) conducts a number of tests
to determine the properties of the drilling-
fluid system and evaluate treatment needs.
Laboratory Tests
Extensive testing of fluid is performed in
the design of the fluid; either to achieve
fluid characteristics or to determine the
performance limitations of the fluid.
16. Outline
Introduction
Basic Function of Drilling Fluids
Types of Drilling Fluids
Drilling Fluid Tests
Challenges Related to Drilling Fluids
Solids Control and Waste Management
17. Challenges Related to Drilling Fluids
• All drilling challenges relate to the fundamental objective of
maintaining a workable wellbore throughout the well-construction
process.
• A workable wellbore can be drilled, logged, cased, cemented, and
completed with minimal nonproductive time.
• The design of the drilling-fluid system is central to achieving this
objective.
18. Challenges Related to Drilling Fluids (Cont.)
Loss of Circulation
• Lost circulation always causes nonproductive time that includes the cost
of rig time and all the services that support the drilling operation.
Solutions
Leak-off Test (LOT)
Formation Integrity Test (FIT)
19. Challenges Related to Drilling Fluids (Cont.)
Stuck Pipe
• Stuck pipe often is associated with well-control and lost-circulation events,
the two other costly disruptions to drilling operations, and is a significant
risk in high-angle and horizontal wells.
Reasons
Solutions
• Lubricants for WBFs
• Spotting Fluids
20. Challenges Related to Drilling Fluids (Cont.)
Barite Sag
• Barite or weight material sag is a problem of drilling mud
and it occurs when weighting materials separate from
liquid phase and settle down.
• Dangers
• Solutions
Light Mud
Heavy Mud
21. Outline
Introduction
Basic Function of Drilling Fluids
Types of Drilling Fluids
Drilling Fluid Tests
Challenges Related to Drilling Fluids
Solids Control and Waste Management
22. Solids Control and Waste Management
Fundamental Concepts:
• Contamination of drilling fluids is a signal if the rig either is not
making hole or soon will be stuck in the hole it is making.
• Before the mechanical solids-removal equipment, dilution was used
to control solids content in the drilling fluid.
• The typical dilution procedure calls for dumping a portion of the
active drilling-fluid volume to a waste pit and then diluting the solids
concentration in the remaining fluid by adding the appropriate base
fluid, such as water or synthetic oil.
23. Solids Control and Waste Management (Cont.)
1- Solids Concentration
• Increasing solids concentration in drilling fluid is a problem for the
operator, the drilling contractor, and the fluids provider.
• Increasing solids content in a drilling fluid leads to a lower ROP and
other problems such as:
• High viscosity and gel strength.
• High torque and drag.
• Stuck pipe caused by filtrate loss.
• Poor cement jobs caused by excessive filter cakes.
24. Solids Control and Waste Management (Cont.)
2- Particle Size and Surface Area
• Drilled solids vary in size from < 1 μm to 15,000 μm in average
particle diameter.
• Colloidal-sized particles are < 2 μm (average particle diameter)
and will not settle out under gravitational forces.
• Ultra-fines range from 2 to 44 μm and are unlikely to settle out of
a drilling fluid unless it is centrifuged.
25. Solids Control and Waste Management (Cont.)
2- Particle Size and Surface Area (Cont.)
• In bentonite particles, the exposed surfaces of fine drilled solids
contain charges that increase the viscosity and gel strengths of
the drilling fluid.
• The viscosity and fluid loss properties of a drilling fluid are difficult
to control with high concentrations of drilled solids that are < 20
μm.
• Today, fluid-technology advances have solved many of the
problems that contribute to fines buildup in drilling fluids.
26. Solids Control and Waste Management (Cont.)
3- Separation by Settling
• Hydro-cyclones, centrifuges, and settling tanks rely on settling
velocity to concentrate and separate solids from slurry.
• Settling velocity is described mathematically by Stokes’ law
which states that the settling velocity is inversely proportional to the
viscosity of the liquid or slurry.
• Stokes’ Low
Vs
d
ρp
ρl
g
η
the settling velocity because of G-force,
the particle diameter,
the density of the particle,
the density of the liquid, ∝
the acceleration or G-force,
the viscosity of the liquid
2( − )
27. Solids Control and Waste Management (Cont.)
4- Screen Selection
• Screens are the only solids-control devices that are changed to handle
changes in fluid properties or drilling conditions.
• Screens generate the bulk of drilling waste and reclaim the bulk of
the mud.
• Screens must be able to handle the full circulation rate.
• Screens are the only devices on a rig that separate solids on the basis
of size as mentioned before.
28. Solids Control and Waste Management (Cont.)
4- Waste Volumes
• The combined waste volume of cuttings that are created while drilling
and the excess or spent drilling fluid might be the best measure of
performance and cost savings offered by a fluids system.
• Minimizing the volume of spent mud and cuttings is the key to
effective waste management.
• The increase in volume of the wet cuttings stems only partly from the
added volume of cavings, washouts, or drilling a non-gauge hole.
29. Solids Control and Waste Management (Cont.)
Total Fluids Management
• This process design is the key to help improve the economics and
minimizing the environmental impact of drilling activities.
• The most important questions during the planning of the project
1. What equipment best suits the drilling-fluid program and
waste-disposal options?
2. What are the solids loading and liquid loading that the
equipment must handle?
3. How much time will it take to install equipment, and who will
install it?
4. Are pumps, piping, chutes, conveyors, etc., adequate for the
intended service?
30. Solids Control and Waste Management (Cont.)
Total Fluids Management (Cont.)
5. Is there enough power on the rig for the proposed equipment set?
6. Is the space available to install the proposed equipment set?
7. Can the drilling-fluid program be modified to assist the mud- and
cuttings-treatment system?
8. What information needs to be collected and reported?
9. What training needs to take place before startup?
10. What safety issues need to be addressed?
11. What environmental issues need to be addressed?
12. What contingency or emergency operations need to be planned?
31. Outline
Introduction.
Basic Function of Drilling Fluids.
Types of Drilling Fluids.
Drilling Fluid Tests.
Challenges Related to Drilling Fluids.
Solids Control and Waste Management.