How do we design a casing program when drilling and completing a well? What are the industry standards for casing? How do we design and perform a cementing job after running a casing string? How do we evaluate a casing and cementing job? Join PetroTeach webinar by Jerry Rusnak! In this webinar, Jerry will talk about casing and cementing job processes including design and related calculations.

1. World Class Training Solutions
Casing and Cementing

2. 2
Outline
• Brief Introduction to PetroTeach
• Biography of Distinguished Instructors Jerry Rusnak
• Webinar Presentation (45 - 60 min.)
• Course Agenda on “Casing and Cementing”
• Q&A (15 - 20 min.)

3. Introduction to PetroTeach
www.petro-teach.com
Reservoir............ 3
 Providing 150 training courses
 About 50 Distinguished Lecturers
 Online, Public and In-house Courses
 Download Our Catalogue !
 Follow us on Social Media!

4. 4
Tuesday 1th – 16:00 GMT
Nightmare of Hydrate Blockage
Professor Bahman Tohidi
Wednesday 9th – 16:00 GMT
Seismic Reservoir Characterization
Dr. Andrew Ross
Thursday 10th – 16:00 GMT
Hydraulic Fracturing
Jerry Rusnak
Monday 14th – 17:00 GMT
3D Printing: The Future of Geology
Dr. Franek Hasiuk and Dr. Sergey Ishutov
Free Webinars in September
Monday 21th – 17:00 GMT
Elements of Fiscal Regimes and Impact on
E&P Economics and Take Statistics
Professor Wumi Illedare
Thursday 3th – 16:00 GMT
Advanced Petrophysics
Mostafa Haggag

5. 5
Wednesday 7th – 16:00 GMT
Classic Measurement vs. Image Processing
Professor Reza Azin
Thursday 1th – 16:00 GMT
Casing and Cementing
Jerry Rusnak
Wednesday 14th – 16:00 GMT
Advanced Analysis of Carbonate System
Professor Maria Mutti
Monday 21th – 16:00 GMT
SAGD And Solvent-SAGD Design And Analysis
Dr. Mazda Irani
Free Webinars in October

6. Jerry Rusnak
PetroTeach
Distingushed Instructor
• Jerry Rusnak holds a Bachelor of Science degree in Ocean Engineering
from Florida Atlantic University.
• He has more than 40 years of oilfield experience. He has worked in all
phases of the industry including service, supply, operations, and
academia.
• He began his career as a Wireline field engineer. Then he worked for an
Independent Exploration and Production Company as a field engineer,
managing wellsite drilling, completion, and workover operations.
• Moving up he became the company’s Drilling and Completion Manager
in charge of multiple simultaneous drilling and completion operations
across US.
• He is an active member and past section president of the Society of
Petroleum Engineers (SPE), and holds or is eligible to hold most major
certifications required for wellsite work both onshore and offshore.

7. Casing and Cementing
Webinar
Jerry Rusnak
Instructor
CSG_CMT_WEB 7

8. Course Objectives
• What does the EIC need to know in order to properly Case and
Cement a well?
• The API standards for casing
• The number of casing strings required
• The setting depth (casing point) of each string
• The borehole (bit) size for each string
• The strength and metallurgy required for each string
• The primary cement job design for each string
• How to evaluate a primary cement job
• How to remediate an unsuccessful primary cement job
CSG_CMT_WEB 8

9. API Casing Standards
• Size (OD) 4 ½” – 36”
• Weight (lbs/ft) determines ID & wall thickness
• Grade (Letter & Number) determines metallurgy & YS (ksi)
• Length Range
• Range 1 (R-1): 16 – 25 ft
• Range 2 (R-2): 25 – 34 ft
• Range 3 (R-3): > 34 ft
• Type of connection
• STC-8RND
• LTC-8RND
• BTC
CSG_CMT_WEB 9

10. Connections
• Pressure seal can be interference between the threads or metal to
metal.
• The connection strength will normally be different than the pipe body
strength.
CSG_CMT_WEB 10

11. How Many Strings of Casing will you run?
11CSG_CMT_WEB

12. Purpose of Casing Strings
• Conductor – The casing string that is put into the well first.
• On land wells, to prevent the sides of the hole from caving
into the wellbore.
• This casing, sometimes called drive pipe, is generally a
short length and is sometimes driven into the ground.
• It is run because the shallow section of most wells
onshore is drilled in unconsolidated sediment or soil
rather than consolidated strata typically encountered
deeper.
• Offshore, the drive pipe or structural casing may be
installed prior to the conductor for similar reasons.
CSG_CMT_WEB 12

13. Purpose of Casing Strings
• Surface – Minimum depth often determined by Gov’t
regulations.
•Cover/protect freshwater zones.
•Cemented from total depth (TD) to surface.
•Must support the weight of all other casing strings.
•Fracture pressure (Pf)at shoe must exceed max
reservoir pressure (Pp) expected before next string
is run.
•The blowout preventer (BOP) is initially made up to
the surface casing head.
CSG_CMT_WEB 13

14. Purpose of Casing Strings
• Intermediate (I/M) – Optional but normally run if mud
weight (MW) required to overbalance Pp will exceed Pf below
previously run string.
• Sometimes used to isolate “troublesome” zones
encountered while drilling - Lost Circ, Differential sticking,
Sloughing shale, etc…
• TOC not normally to surface but often overlaps previous
casing.
CSG_CMT_WEB 14

15. Purpose of Casing Strings
• Production – The innermost casing run in the well.
•Size will be determined by production tubing size
requirement.
•This will determine size of all the other csg strings.
•Normally cemented across all zones capable of
producing fluids and/or to be used for injection.
CSG_CMT_WEB 15

16. Casing shoe depths and the number of
strings
•In conventional drilling operations, the
setting depths are determined principally
by the mud weight (ppg) and the fracture
gradient (psi/ft) at all depths (TVD) in the
well.
•Following determination of the setting
depths, drill bit and casing sizes, of
individual casing strings must be
determined.
16 CSG_CMT_WEB

17. What determines the setting depth (casing
point) of each string?
CSG_CMT_WEB 17

18. What determines the setting depth (casing
point) of each string?
CSG_CMT_WEB 18

19. 19
Casing size Vs. Bit size
CSG_CMT_WEB

20. 20
2 7/8” production tubing
5 ½” production casing
CSG_CMT_WEB

21. How to purchase the casing strings?
• Size – Weight – Grade – Range – Connection
• Number of joints for each string (allowance for thread loss)
• Logistics from factory to wellsite
• Particularly important for offshore
• Order the required accessories (matching size & connections)
• Float Equipment
• Centralizers
• Scratchers
• Stage tool
• Wellhead equipment
CSG_CMT_WEB 21

22. What are the different Well Conditions to
consider when designing the casing string(s)?
• Installation Conditions
• Axial Stresses – Weight, shock loads, over pull, etc…
• Pressure forces – Burst, Collapse
• Bending stresses if directional or “crooked” wellbore
• Cementing Conditions
• How will forces change while conditioning mud and pumping
cement – rotation & reciprocation
• Set Cement Conditions
• How will forces change after cement has “set”
CSG_CMT_WEB 22

23. What are the different Well Conditions to
consider when designing the casing string(s)?
• Completion Forces
•Is a major stimulation (acid or frac job) planned?
•Pressure Forces
•Temperature forces
• Production forces
•Tubing and packer forces
•Pressure depletion
•Temperature forces
CSG_CMT_WEB 23

24. Computer Design
• Run a Finite Element Analysis (FEA) for each of these
conditions.
• Determine the maximum stress on the casing and where it
will occur.
• Select pipe grade (YS) based on maximum stress.
• Select pipe grade (metallurgy) based on Corrosion, H2S,
etc…
• Select pipe weight (wall thickness) based on wear if
drilling inside casing will be done.
• Select design safety factor (SF) based on experience.
CSG_CMT_WEB 24

25. Casing Design Software
CDEx - A Better and Simple Way to Casing
Design (2:17)
• https://youtu.be/GlpPoMBqrfM
25
CSG_CMT_WEB

26. Where will I put centralizers?
• Design/placement critical for good primary cement
job.
• Proper “stand off” critical for mud removal/cement
coverage.
• Most computer programs will “optimize” centralizer
placement.
CSG_CMT_WEB 26

27. After Casing installation we are ready to
perform Primary Cement Job.
• Design cement job based on.
•Drilling mud removal.
•Pore pressure & Frac pressure (well control).
•TOC required.
•Strength of cement required.
CSG_CMT_WEB 27

28. Considerations while pumping Cement job
• Cementing
Equipment
• Cementing head
• Wiper plugs
• Scratchers
• Centralizers
• Float collar
• Float shoe
28CSG_CMT_WEB

29. Considerations while pumping Cement job
• Need to “condition” drilling mud prior to pumping
cement system.
• Need to consider “Rheology” of drilling mud, chemical
wash, spacer fluids and cement.
• Need to ensure compatibility of all fluids as some
contamination is unavoidable.
CSG_CMT_WEB 29

30. Major Cement Slurry Properties
•Water/Cement Ratios (gal/sk)
•Slurry Density (ppg)
•Fluid-Loss Control (ml/30s)
•Thickening Time (minutes)
•Slurry Rheology (µ, Yp, Nre)
30CSG_CMT_WEB

31. Cement Additives
•Accelerators
•Retarders
•Fluid Loss Additives
•Dispersants
•Extenders
•Weighting Agents
•Lost Circulation Materials
•Special Additives
31CSG_CMT_WEB

32. Rheology
•The study of flow and deformation of
fluids
•In well cementing, rheology affects:
•Cement slurry mixability and
pumpability
•Cement coverage (mud displacement)
•Friction pressure estimation (ECD)
•HHP requirements (P x Q)
32CSG_CMT_WEB

33. Flow Rate and Deformation
33CSG_CMT_WEB

34. Reynolds Number
•Prediction of type of flow pattern (plug,
laminar or turbulent) is defined as the
Reynolds Number
•Nre = ρvD/μ (Dimensionless)
•ρ = fluid density (lb/ft3 or kg/m3)
•v = average velocity (ft/s or m/s)
•D = diameter (ft or m)
•μ = fluid viscosity (lb/ft s or Pa s)
34CSG_CMT_WEB

35. Critical Reynolds Number
•NRe = ρvDe/μe > 3000 is often used to
determine the flowrate required to
achieve turbulent flow in the annulus.
•Empirical evidence shows that the best
regime for displacing mud in the annulus
is turbulent flow.
•Experience recommends a minimum
pump rate of 8 BPM.
35CSG_CMT_WEB

36. Rheology
• In the lab we can use
instruments to
measure shear stress
(Ꚍ) and shear rate (ꙋ)
of a fluid.
• A plot of this data will
give us an estimate of
the fluid viscosity
under pumping
conditions.
36CSG_CMT_WEB

37. Rheology
• A plot of this data will
give us an estimate of
the Yield Point of the
fluid under pumping
conditions.
• YP is the shear stress
at zero shear rate.
• It is a measure of the
amount of pressure
applied to the fluid
before it will move.
37CSG_CMT_WEB

38. Rheology
• The YP is a
measurement of a
fluids ability to
suspend solids.
• Lower the YP of the
mud as low as
practically possible
prior to pumping
cement job, but only
after the hole is
clean.
38CSG_CMT_WEB

39. Job Execution
•For successful job execution the Wellsite
Manager and the Cementing Crew
Wellsite Supervisor need to be involved in
the job planning.
•Communication is the key to a successful
job.
39CSG_CMT_WEB

40. Cement Job Evaluation
•Comparison of calculated job design
parameters with actual parameters
recorded during job execution.
•This includes pump rate, pump pressure
and slurry/liquid density at a minimum.
•Collect and preserve cement samples
collected during job.
•Do not remove free water from samples.
40CSG_CMT_WEB

41. Final Circulating Pressure (FCP)
41CSG_CMT_WEB

42. Volumes of cementing fluids pumped?
•Spacer and/or pre-flush fluids, and
cement slurries (lead and Tail) should
be as per the well specific cement
program
•Inventory all materials before and
after job (cement, additives, water).
42CSG_CMT_WEB

43. Flowline Returns During Job
•What was the flow rate of the flowline
returns compared to the pump rate?
•Were there any losses of returns during
the cement job?
•Where/When during job did these losses
occur?
•What was the density or change in
density of the fluid returns?
43CSG_CMT_WEB

44. 44
• Was the top plug Bumped?
• How did the actual displacement volume compare to
the calculated volume?
CSG_CMT_WEB

45. Did the float equipment work?
•Check float equipment as described in the
cementing job procedure.
•If the float equipment “leaks” shut the
well in at the surface (cementing head)
and wait till it sets to bleed of pump
pressure.
45CSG_CMT_WEB

46. CBL/VDL/GR/CCL
46CSG_CMT_WEB

47. If Primary Cement Job is “unsuccessful” how
do you plan Remedial cement job?
• High Pressure Squeeze – BHP > Pf
• Low Pressure Squeeze – BHP < Pf
• Re-cement above TOC of Primary Job
CSG_CMT_WEB 47

48. Radial-cement evaluation
48CSG_CMT_WEB

49. Setting Cement Plugs
• If Well is not salvageable because of failure of cement
job than the final cement job performed might be to
Set Cement Plug(s) & Abandon Well.
• You do not want to be the EIC of that!
49CSG_CMT_WEB

50. Casing and Cementing (online)
26 - 30 Oct. 2020
25 – 29 Jan. 2021
Register@petro-teach.com
• The course will introduce casing and cement job processes including design and related
calculations. Casing handling equipment and running procedures are covered. Cementing
surface equipment considerations are included. The course will include practical exercises and
evaluation of knowledge gained. Cementing materials and additives and their effects on cement
rheology will be explained. The course will provide examples of primary, remedial, plug back
and abandonment cementing designs. Cement job evaluation using job data, pressure testing
and wireline logs will be used.
• The learning objectives of the top-most level content of the course
are:
 To obtain a working knowledge of casing design
 To obtain a working knowledge of cementing procedures
 To learn the practical application of different types of cement
 To learn how to use additives to produce specific cement properties
 To learn the equipment, tools and techniques involved in casing and cementing a well
 To learn how to evaluate the success or failure of a cement job
Course price (Euro):
• Normal registration:1490+VAT
• 20% DISCOUNT for PhD students, Group (≥ 3 person) and early bird registrants (1 week before)
50CSG_CMT_WEB

51. Thank You
Any Questions ?

52. 52
Legal Disclaimer, General Access Terms & Conditions
This material and the information contained in it are directed to or intended for general education
propose. The information presented on this material is collected, maintained and provided purely
for the convenience of the reader. We have made every attempt to ensure that the information
contained in this material has been obtained from reliable sources and PetroTeach is not
responsible for any errors, decisions or omissions of the information. The information on this
material has been incorporated in good faith and it is only for the general education and training
purpose. It should not be relied upon for any specific purpose and no representation or warranty is
given for its accuracy or completeness.
By accessing this material, you agree that PetroTeach will not be liable for any loss incurred due
to the use of the information and the material contained.
The copyright for this material is solely belongs to the PetroTeach and Its Instructors.
Any access to it by the general public does not imply free license to any company/organization to
use it for any commercial education and projects unless it is inquired permission from PetroTeach.