A Practical Handbook for Drilling Fluids Processing (Gulf Drilling Guides)

Cover
A Practical Handbook for Drilling Fluids Processing
Copyright
Disclaimer
In Memoriam
Preface
	Book description
	Summary of the role of solids control in good drilling practices
	Economics of solids control
	Historical perspective
	1940s
	1950s
	1960s
	1970s
	1980s
	2000s
	Drilling fluid processing quiz
Section I: Drilling fluid treatment, properties, and functions
1. Rheology
	Introduction
	Drilling fluid rheology review
	Drilling fluid functions
	Viscosity dilemma
		How are these viscosities measured?
	Measuring drilling fluid properties
	Calculating viscosity
	Using the bingham plastic model
		What does PV indicate?
	Funnel viscosity
	Other rheological models
	Drilling fluid additives
	Drilling fluid measurements
	Mud weight
	Special note
	Gel strength
	Filtration rates
	Solids content
	Sand content
	Chemical measurements
	Electric stability
	Pilot testing
	Problems
		Problem 1.1
		Problem 1.2
2. Mud tank arrangements needed for safety
	Arrangement and equipment selection
	Suction section
		Mud tank volume
		Plugged bit method
		Cased hole method
		Kick contingency method
		Plumbing
		Agitation
		Slug tanks
		Mud weight increase guideline
		Trip tanks
		Pulling out of hole
		History
		Going in hole
		Plumbing required to properly use trip tanks
		Plumbing scenario #1
		Plumbing scenario #2
	Appendix 2.A
		Derivation of slug effectiveness
	Appendix 2.B
	Problems
		Problem 2.1
		Problem 2.2
		Problem 2.3
		Problem 2.4
3. Addition section
	Mud hoppers
	Mud hopper recommendations
	Mud guns
	Selecting nozzles and centrifugal pumps for mud guns
	Situation
		Find the head at each mud gun nozzle
		Find the mud gun nozzle sizes
		Calculating the head available at each nozzle
			First segment
			Second mud gun
			Third mud gun
			Fourth mud gun
			Fifth mud gun
		Summary
		Calculation of fluid flow through ¾″ nozzles
			First segment
			Second mud gun
			Third mud gun
			Fourth mud gun
			Fifth mud gun
	Proper application of mud guns
		Removal section
		Suction section
	Appendix 3.A
		Derivation of mud gun flow rate equation
4. Agitation
	Introduction
	Mixing and blending drilling fluid
	Mechanical agitators
	Motors
	Impellers
	Proprietary blades
		Installation
		Natural frequency determination
		Example
	Compartments
	Sizing agitators
	Turnover rate
		Example
	Mud guns
5. Drilled solids calculations
	Introduction
	Calculation of low gravity solids from retort data for a fresh-water drilling fluid
	Discussion
	Retorts
		Retort size required for accurate solids calculation
		Sensitivity to measurements
		Field measurement of specific gravity of drilled solids
	Validation of the equation
	Non-aqueous drilling fluids
	Special note about potassium chloride drilling fluids
	Calculation volume fraction of low gravity solids in non aqueous fluids
	Procedure for determining the low gravity solids in non-aqueous fluids
	Alternate method of calculating low gravity solids in an unweighted, water-based drilling fluid
	Problems
6. Cuttings transport
	Hole cleaning
	Empirical correlation for cleaning; vertical or near-vertical boreholes (up to 35 degrees)
	Historical perspective
	Empirical correlation
	Using the correlation
	Diagnostics
	Practical suggestions
	Comments
	Hole cleaning for highly deviated wells
	Suggestion
	Appendix 6.A
		Derivation of the effective viscosity term “K”
	Appendix 6.B
	Appendix 6.C
	Cuttings transport problems
		Problem 6.1
			Part 1
			Part 2
		Problem 6.2
		Problem 6.3
		Problem 6.4
		Problem 6.5
		Problem 6.6
		Problem 6.7
		Problem 6.8
		Problem 6.9
		Problem 6.10
7. Dilution
	Introduction
	True costs of drilling a well
	Dilution principles
	Application
	Problems
		Problem 7.1
		Problem 7.2
		Problem 7.3
		Problem 7.4
Section II: Drilling fluid processing – mechanical separation of solids
8. Surface drilling fluid systems
	Introduction
	Generic systems for unweighted drilling fluid
	Generic systems for weighted drilling fluid
	Alternate system
	By-pass troughs after the shale shakers
	Appendix 8.A
9. Removal section
	Introduction
	Unweighted drilling fluid
	Weighted drilling fluid
	Distribution chamber
10. Centrifugal pumps
	Introduction
	A centrifugal pump is a constant head device
	Pump description
	Pump curves
	Application of pump curves
	Sizing impellers
	Operating point
	Application for desilting drilling fluid
	Net positive suction head (NPSH)
	Atmospheric pressure
	Flow into a centrifugal pump
	Cavitation
	Practical operating guidelines
	Appendix 10.A
		Quiz solution
	Appendix 10.B
		Centrifugal pump head curves
	Problems
		Problem 10.1
		Problem 10.2
		Problem 10.3
		Problem 10.4
11. Fraction of drilling fluid processed
	Introduction
	Calculating drilling fluid process efficiency
	Summary
	Problems
		Problem 11.1
		Problem 11.2
		Problem 11.3
			Weevil
		Problem 11.4
		Problem 11.5
		Problem 11.6
		Problem 11.7
		Problem 11.8
		Problem 11.9
		Problem 11.10
		Problem 11.11
			Example rig #1
		Problem 11.12
			Example rig #2
		Problem 11.13
			Example rig #3
		Problem 11.14
		Problem 11.15
		Problem 11.16
12. Equipment solids removal efficiency
	Effect of equipment removal efficiency
	Reasons for drilled solids removal
	Diluting as a means for controlling drilled solids
	Chemical treatment
	Mechanical treatment
	Mechanical separation-basics
	Effect of solids removal system performance
	Relationship of solids removal efficiency to clean drilling fluid needed
	Five examples of the effect of equipment solids removal efficiency
	Solids removal efficiency for minimum volume of drilling fluid to dilute drilled solids
	Estimating equipment drilled solids removal efficiency for an unweighted drilling fluid from field data
	Estimating equipment drilled solids removal efficiency for a weighted drilling fluid
	Another method of calculating the dilution quantity
	API method
	Equipment solids removal efficiency problems
		Problem 12.1
		Problem 12.2
		Problem 12.3
		Problem 12.4
	General comments
13. Cut points
	Introduction
	Cut points of shale shakers
	Cut points of hydrocyclones
	Cut points of centrifuges
	Comment on particle size presentations
14. Operating guidelines for drilling fluid surface systems
	Objective
	Description of the surface drilling fluid system
	Design of the active surface processing system
		Flow line
		Removal section
			Shale shakers
			Rig up of shale shakers
			Operational guidelines for shale shakers
			Sand traps
			Rig up of sand traps
			Operating guidelines for sand traps
			Degassers
			Rig up of degassers
			Operational guidelines for degassers
			Hydrocyclones
			Rig up of hydrocyclones
			Operational guidelines for hydrocyclones
			Mud cleaners
			Rig up of mud cleaners
			Operational guidelines for mud cleaners
			Centrifuges
			Rig up of centrifuges
			Operational guidelines for centrifuges
		Addition section
			Rig up of the addition section
			Operational guidelines for additions compartment
		Suction section
			Rig up of the suction section
			Operating guidelines for the suction section
			Mud guns
			Rig up of mud guns
			Operating guidelines for mud guns
			Design of the trip tank system
			Design of the prehydration tank
			Design of the clean drilling fluid addition system
Section III: Solids control equipment
15. Drilled solids removal
	Introduction
		Economics of solids control
			Field example #1
			Field example #2
			Field example #3
			Example #4
	Roles of the drilling fluid processing system
	Drilled solids sizes
	Why control drilled solids?
		Visible NPT or trouble costs
	Stuck pipe
	Filter cakes in NADF
	Extra note
	Cement placement
	Surge and swab pressure
	Wear
	Disposal costs
	Lost circulation
		Invisible NPT or trouble costs
			Invisible NPT
	Log interpretation
	Formation damage
	Cementing
	Drilling performance
	Polycrystalline diamond compact bits
	Carrying capacity
	Summary
	Problems
		Problem 15.1
		Problem 15.2
16. Shale shakers
	Introduction
		Screens
	Panel screens
	Screen design
		Screening surfaces
	Screen weaves
		Plain square weave
		Rectangular weave
	Screen openings
	Conductance
	Screen labeling
	Equivalent aperture opening size
	How a shale shaker screens fluid
	Discussion of API RP13C
		API RP13C tutorial
			Summary
		Definitions
			Mesh
			D50 cut point
			D100 cut point
			API screen number
			Screen conductance
			Non-blanked area
	Background
	API screen number determination
	Comparison with RP13E
	Rig site performance
	Labeling requirements
	Putting the label to use
	Conclusion
	Frequently asked questions regarding RP13C
	Screen types and tensioning systems
		Screen types
	Gumbo and water-wet solids problems
	Blinding and plugging of screens
		Shale shaker history
	Shale shaker design
	Motion types
	Scalping shakers
	Fine screen shakers
	Shaker capacity
	Solids conveyance
	“G” factor determination
	Relationship of “G” factor to stroke and speed of rotation
	Dryer shakers
	Triple deck shakers
	Gumbo removal
	A shaker that doesn\'t shake
	Maintenance
	Power systems
	Cascade systems
	Summary
	Shaker users guide
		Installation
		Operation
		Maintenance
		Operating guidelines
	Summary
17. Sand traps
	Introduction
	Settling rates
	Bypassing shale shaker
18. Degassers and mud gas separators
	Introduction
	Effects of gas-cut drilling fluid
	For example
	Removing gas bubbles
	Installation
		Procedure for operation of degassers
	Mud/gas separators
19. Hydrocyclones
	Introduction
	Cut points
	Desanders
	Summary
	Desilters
	Maintenance
	Hydrocyclone tanks and arrangements
	Hydrocyclone operating tips
	Appendix 19.A
		The ten commandments for hydrocyclones
20. Mud cleaners
	Introduction
	Uses of mud cleaners
	Situations where mud cleaners may not be economical
	Location of mud cleaners in a drilling fluid system
	Operating mud cleaners
	Estimating ratio of low gravity solid volume and barite volume in mud cleaner screen discard
	Mud cleaner performance
	Mud cleaner economics
	Accuracy required for specific gravity of solids
	Heavy drilling fluids
	Operation guidelines
	Installation
	Non-oilfield usage of mud cleaners
	Appendix 20.A
		History of the development of mud cleaners
21. Centrifuges
	Introduction
	Centrifuging NADF
	Operating tips
	Summary
	Rotary mud separator
	Appendix 21.A
		Stokes\' law settling
	Problems
		Problem 21.1
		Problem 21.2
22. Solutions to chapter problems
	Preface quiz answers
	Chapter 1 Rheology solutions
		Problem 1.1 solution
			FLUID #1:
			FLUID #2:
			FLUID #3:
			FLUID #4:
			Comments about these fluids:
		Problem 1.2 solution
	Chapter 2 Mud tank arrangements solutions
		Problem 2.1 solution
		Problem 2.2 solution
		Problem 2.3 solution
		Problem 2.4 solution
	Chapter 5 Drilled solids calculations solutions
		Problem 5.1 solution
			Additional note:
		Problem 5.2 solution
		Problem 5.3 solution
	Chapter 6 Cuttings transport solutions
		Problem 6.1 solution
			Part 1
			Part 2
		Problem 6.2 solution
		Problem 6.3 solution
		Problem 6.4 solution
		Problem 6.5 solution
		Problem 6.6 solution
		Problem 6.7 solution
		Problem 6.8 solution
		Problem 6.9 solution
		Problem 6.10 solution
	Chapter 7 Dilution solutions
		Problem 7.1 solution
		Problem 7.2 solution
		Problem 7.3 solution
		Problem 7.4 solution
	Chapter 10 Centrifugal pumps solutions
		Problem 10.1 solution
		Problem 10.2 solution
			Solution A
			Solution B
		Problem 10.3 solution
		Problem 10.4 solution
	Chapter 11 Fraction of drilling fluid processed solutions
		Problem 11.1 solution
			Analysis
			Solution
		Problem 11.2 solution
		Problem 11.3 solution
			Analysis
			Solution
		Problem 11.4 solution
			Analysis
			Solution
		Problem 11.5 solution
			Analysis
			Solution
		Problem 11.6 solution
			Analysis
			Solution
		Problem 11.7 solution
			Analysis
			Solution
		Problem 11.8 solution
			Analysis
				First step: determine flow rates into and out of tanks
				Second step: calculate the fraction of fluid processed
			Conclusion
			Problem 11.8 solutions A–D
				Problem 11.8 solution A
					First step: calculate the removal efficiency
					Second step: calculate the fraction of fluid processed
				Problem 11.8 solution B
					Flow into tank 1 (the degasser suction)
						Degasser
				Problem 11.8 solution C
					Degasser
					Desander
					Desilter
				Problem 11.8 solution D
		Problem 11.9 solution
			Possible replumbing
		Problem 11.10 solution
			Analysis
		Problem 11.11 solution
			Example rig #1
		Problem 11.12 solution
			Analysis
			Solution
				Find fraction of fluid processed
				Desander
				Desilter
		Problem 11.13 solution
			Example rig #3
				Find fraction of fluid processed by desander and desilter
				Changes that need to be made to mud tank
		Problem 11.14 solution
			Analysis
			Backflow from #2 to #1
			What changes need to be made?
		Problem 11.15 solution
			Analysis
			Process sequentially
		Problem 11.16 solution
			Analysis
				Desilter
				Desander
			Solution
	Chapter 12 Equipment solids removal efficiency solutions
		Problem 12.1 solution
			Costs!!
		Problem 12.2 solution
		Problem 12.3 solution
		Problem 12.4 solution
	15 Control drilled solids solutions
		Problem 15.1 solution
			Issue #1
				Analysis of issue #1
			Issue #2
				Analysis of issue #2
			Issue #3
				Analysis of issue #3
			Issue #4
				Analysis of issue #4
		Problem 15.2 solution
			Solids removal efficiency
			How much excess drilling fluid was discarded to keep the pit levels constant?
			What should be the solids removal efficiency to eliminate generating the excess drilling fluid (i.e. the lowest cost remova ...
	Chapter 21 Centrifuge solutions
		Problem 21.1 solution
		Problem 21.2 solution
			Part 1
			Part 2
			Part 3
Appendices
	Appendix A
		pH changes with temperature
	Appendix B
		Drilling fluid suggestions
		Solids control suggestions and thoughts
	Appendix C
		Solids control
		Solids problem without an increase in solids content
	Appendix D
		Hole erosion
	Appendix E
		Significant figures
		Significant figure concept applied
	Appendix F
		Acceleration of gravity
	Appendix G
		Final thoughts or “the musings of a curmudgeon”
Bibliography
Index
	Index
	A
	B
	C
	D
	E
	F
	G
	H
	I
	J
	K
	L
	M
	N
	O
	P
	R
	S
	T
	U
	V
	W
	X
	Y
Back Cover