This document discusses solid chemical sticks used to optimize gas production. It describes the benefits of chemical sticks being cost effective and reducing man hours. It provides steps for dropping chemical sticks down a wellbore and explains how they work to dissolve and increase surface pressure. Finally, it outlines various types of chemical sticks and key factors to consider like fluid height, chlorides, hydrocarbons, and tubing size to determine the proper chemical stick for an application.
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
Managed Pressure Drilling (MPD) is a drilling tool that is increasingly being recognised by operators and regulators as it is able to enhance safety, efficiency and lower cost. MPD aims to resolve chronic drilling problems that contribute to non-productive time. These problems include:
Well Stability
Stuck Pipe
Lost Circulation
Well Control Incidents
When MPD is executed correctly, it is as safe as, or safer than, current conventional drilling techniques. The objective of this 5-day course is to help you understand and apply the fundamentals of MPD, starting from candidate assessment and selection through to implementation. The aim is to provide you with the knowledge required to identify prospective MPD candidate wells in their operations through a rigorous candidate screening process, evaluate the appropriate approach to most economically and safely drill the well and, if the approach selected is MPD, to ensure that the appropriate equipment, procedures, assessment and mitigation of risks are applied.
Course Structure
The course, which follows the structure of the Gulf Publishing Company’s textbook “Managed Pressure Drilling”, supplemented with latest technology developments and case studies, will, amongst others, cover the following important topics:
The basic principles of MPD – how it works
How MPD addresses NPT problems
Overview of MPD methods
Selection of the appropriate MPD method
MPD well design, including mud system and mud weight selection
MPD Equipment and equipment selection
MPD control systems
Application of screening criteria for MPD and candidate selection
Risk analysis
Project economics
What will you learn?
During the course, current MPD methods are described, highlighting advantages and disadvantages of each. By the end of the course, you will be able to determine which MPD method is most suitable for a particular application or well section.
In summary, you will be in a position to do the following after the course:
Screen their own candidate wells using criteria for MPD candidate selection
Apply specific design principles for selected MPD wells/methods
Determine operating parameters for safe MPD operations
Prepare a MPD based drilling program
Evaluate project risks
Evaluate project economics.
We will use case studies and worked exercises to reinforce learning.
This slide would teach the well control method during drilling operations, and the shut-in procedure in case of a kick. Please note that shut-in procedure may vary from site to site depending on the equipment available and the site regulations but whatever the situation, this is the general procedure for well control during drilling. Enjoy!
Selection of the best artificial lift systems for the well depend on location, depth, estimated production, reservoir properties, and many other factors. Here is an overview on selection criteria for the best results
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
Managed Pressure Drilling (MPD) is a drilling tool that is increasingly being recognised by operators and regulators as it is able to enhance safety, efficiency and lower cost. MPD aims to resolve chronic drilling problems that contribute to non-productive time. These problems include:
Well Stability
Stuck Pipe
Lost Circulation
Well Control Incidents
When MPD is executed correctly, it is as safe as, or safer than, current conventional drilling techniques. The objective of this 5-day course is to help you understand and apply the fundamentals of MPD, starting from candidate assessment and selection through to implementation. The aim is to provide you with the knowledge required to identify prospective MPD candidate wells in their operations through a rigorous candidate screening process, evaluate the appropriate approach to most economically and safely drill the well and, if the approach selected is MPD, to ensure that the appropriate equipment, procedures, assessment and mitigation of risks are applied.
Course Structure
The course, which follows the structure of the Gulf Publishing Company’s textbook “Managed Pressure Drilling”, supplemented with latest technology developments and case studies, will, amongst others, cover the following important topics:
The basic principles of MPD – how it works
How MPD addresses NPT problems
Overview of MPD methods
Selection of the appropriate MPD method
MPD well design, including mud system and mud weight selection
MPD Equipment and equipment selection
MPD control systems
Application of screening criteria for MPD and candidate selection
Risk analysis
Project economics
What will you learn?
During the course, current MPD methods are described, highlighting advantages and disadvantages of each. By the end of the course, you will be able to determine which MPD method is most suitable for a particular application or well section.
In summary, you will be in a position to do the following after the course:
Screen their own candidate wells using criteria for MPD candidate selection
Apply specific design principles for selected MPD wells/methods
Determine operating parameters for safe MPD operations
Prepare a MPD based drilling program
Evaluate project risks
Evaluate project economics.
We will use case studies and worked exercises to reinforce learning.
This slide would teach the well control method during drilling operations, and the shut-in procedure in case of a kick. Please note that shut-in procedure may vary from site to site depending on the equipment available and the site regulations but whatever the situation, this is the general procedure for well control during drilling. Enjoy!
Selection of the best artificial lift systems for the well depend on location, depth, estimated production, reservoir properties, and many other factors. Here is an overview on selection criteria for the best results
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Author: Robbie Edward Sayers
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1. Solid Chemical Stick Applications
For OPTIMIZATION Of Gas
Production
Select Industries, INC.
2. Benefits of Solid Chemical
Sticks
Cost effective.
Increase of production.
When used with automatic soap stick
launchers, decreases man-hours of oil and
gas producers.
No liquid chemicals, bulk tank, or
containment.
3. How Soap Sticks Work
Dropping the
Soap Sticks
Step 1
-Insure Both Valves are
Closed
4. How Soap Sticks Work
Dropping the
Soap Sticks
Step 2
-Open top valve and
release pressure in
lubricator
5. How Soap Sticks Work
Dropping the
Soap Sticks
Step 3
-Insert Soap Stick
through top valve
6. How Soap Sticks Work
Dropping the
Soap Sticks
Step 4
Close Top Valve
7. How Soap Sticks Work
Dropping the Soap
Sticks
Step 5
Open Bottom Valve and Let the
Soap Stick Fall Down the
Tubing
Close the Bottom Valve
8. Soap Stick Falling in a
Liquid Loaded Gas
Well
How Soap Sticks Work
9. Soap Stick Hitting
Fluid and Beginning
to Dissolve
How Soap Sticks Work
10. Soap Stick Continuing
to Fall and Dissolve
How Soap Sticks Work
11. Well Bore With Soap
Stick Almost or
Completely Dissolved
Notice surface
pressure increase
How Soap Sticks Work
12. Unloaded Gas Well
Well will slowly begin to
load with fluid again.
Soap Sticks need to be
dropped on a regular basis
to prevent loading.
How Soap Sticks Work
13. Types of Solid Chemical
Sticks
Soap sticks –
– Designed to foam the water in the tubing,
therefore lightening the fluid column and
allowing the formation pressure to unload the
fluid from the well.
– They are usually either a hard stick packaged in
a split cardboard tube or a removable bag,or a
soft stick or gel in a water soluble tube.
14. Types of Solid Chemical
Sticks
Oil foam stick.
– Same principle as soap stick.
– Used in wells that have a fluid column
composed of 75% condensate or greater.
15. Types of Solid Chemical
Sticks
Combination sticks.
– Typically one-half soap and one-half oil foam
stick.
– Used in wells where there are unknown
variables and wells that produce 25-75%
condensate.
16. Types of Solid Chemical
Sticks
Paraffin inhibitor sticks.
– Oil soluble sticks that release paraffin inhibitor to
prevent paraffin deposition from crude oil in production
system.
– They will not readily remove deposits already in place.
17. Types of Solid Chemical
Sticks
Acid stick.
– Primarily used in water
injection wells to
removed carbonate
scale and rust deposits
and also to lower
injection pressures.
– More economical than
conventional acid jobs.
18. Types of Solid Chemical
Sticks
Salt inhibitors.
– Chelating action to keep salt in solution.
– Prevents salt build-up in tubing and perforation of
a gas well.
Scale inhibitors.
– Developed to prevent carbonate types of scale
from developing down hole in oil and gas wells,
casing, tubing and flow lines.
19. Types of Solid Chemical
Sticks
Corrosion inhibitors.
– Oil or water soluble.
– Control common corrosion problems found in
producing oil and gas well systems.
– Controls breeding grounds of bacteria by
reducing under deposit corrosion.
20. Determination of Correct Solid
Chemical Stick for Your
Application
The key to your chemical stick programs
success is based on specific parameters.
Determination factors:
– Fluid column height.
– Chloride levels.
– Hydrocarbon content.
– Bottom hole pressure.
– Flow of well.
– Daily Production.
– Tubing size.
21. Fluid Column Height
Fluid column height is rarely known,
however a calculation of the surface
pressure can give you some type of
indication of the fluid column height.
Calculation of feet of fluid in column
Example form*
Normal flow pressure 1200 psi
Present flow pressure - 900 psi
Amount of drop in pressure 300 psi
Pressure drop per ft of depth of water is
.4330 psi
Pressure drop = feet of water in fluid column
psi per ft. of depth
300 = 693 feet of water in tubing
.4330
* This is a rough estimate. Other factors can
effect pressure loss between the formation
and the well head.
22. Example of fluid column
calculation
Bottom Hole Pressure = 1200 psi
Surface Pressure = 300 psi
Pressure drop = 900 psi
Pressure drop per ft of depth of water is .4330 psi
Pressure drop = ft of water in fluid column
psi per foot of depth
900 = 2079 feet of fluid in tubing
.4330
23. CALCULATION FOR THE NUMBER OF POUNDS OF
SOLID STICK CHEMICAL
Example form using 2 3/8 EUE tubing
Feet of water 333
2 3/8 EUE tubing 4BBLS/1000 ft.
333 (ft of water) divided by 1000
Amount of water = 4 X .3 = 1.2 BBLS
Gallons of water = 1.2 x 42 gals./ BBLS. = 50.4 gallons
Weight of water = 8.3 lbs/gallon
50.4 gallons x 8.3 lbs/ gallon. (ppm of salt is ignored) = 418.32
The initial slug usage of solid chemical sticks is often based on .005%
by weight of water in well.
418.32 x .005 (of stick) = 2.09 lbs of chemical stick needed
24. Addition EUE Factors
1” EUE tubing = 1.1 BBLS/1000 ft.
2” (2 3/8) EUE tubing = 4 BBLS/1000 ft.
2 ½’’(2 7/8 EUE tubing = 6 BBLS/1000 ft.
3 inch EUE tubing =9 BBLS/1000 ft.
3 ½” EUE tubing = 12 BBLS/1000 ft.
25. Chloride Analysis
Chemical foam sticks are formulated specifically
to perform best in a determined chloride range.
Various chemical foam sticks may foam in fresh
water, but may not foam in 50,000 ppm or higher
of Chlorides.
A water analysis is needed to determine what
formulation of chemical stick is needed. Chemical
foam sticks can be formulated to perform in levels
of Chlorides up to 200,000 ppm of salt.
26. Hydrocarbon Content
Hydrocarbon content in a fluid column will have
dramatic effects on the way a soap stick performs.
Hydrocarbon content is part of the analytical data
required by the producer in order to make the
efficient solid chemical stick selection.
Producers should provide oil to water ratio, to
calculate hydrocarbon content.
27. Bottom Hole Pressure
Bottom hole pressure if known, the psi at
the well head can be subtracted from the
bottom hole pressure to calculate the
approximate fluid column height.
28. Well Flow
If the well is not flowing, there most likely
is no fluid movement and foam sticks will
not be able to create foam. However fluid
may be present in a stagnate state.
If the well is dead then gas generating sticks
will be recommended for use in
combination with a recommended foam
stick.
29. Daily Production
Production rate is needed to determine not
only how many sticks will be required to
keep the well unloaded, but where
applicable, it also helps in determining how
often to set parameters of automatic soap
stick launchers.
30. Tubing Size
Tubing size will affect the volume of fluid
to be removed down hole versus the size
stick recommended.
Use the stick diameter size manufactured
that best matches up to the tubing size down
hole.
31. Summary
A large variety of chemical sticks are
available for different applications of oil
and gas wells.
Solid chemical sticks are cost effective.
Solid chemical sticks require no liquid
injection system, bulk tanks, or
containment.