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28 August 2019Footer text... 1Footer text...
Well Architecture Driven Transverse Shear Stresses - Engineering Challenges in ERD Well
HALLIBURTON LIFE 2019
1Sandeep Dhawan, Principal Well Engineer
EXTERNAL © 2019 Halliburton. All rights reserved.
DISCLAIMER 2019
The contents of this presentation are for informational purposes only. Halliburton** makes no representation or warranty about the accuracy or suitability of the information provided in this presentation and any related materials. Nothing in this presentation constitutes professional advice or consulting services. No contractual relationship with Halliburton is established by attending or viewing this presentation. No rights to intellectual property of Halliburton are granted through this presentation. The opinions expressed in this presentation are those of the author and do not necessarily represent the views of Halliburton. **Halliburton means Halliburton Energy Services, Inc., Landmark Graphics Corporation, and their affiliates.
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Introduction
Sketch - LIFE
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Launch Issue Fix Evolve
Well Overview
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o Extended reach Wello Location - Offshore Denmarko 23000 ft. well depth with 14500
ft. lateralo Lower cretaceous chalk (Marly)
(condensate rich gas)o Well Architecture -
o 10 ¾” Production Casingo Allows expandable liner
option.o 5 1/2” frac sleeve cemented
linero No tieback to surface.
Heel Toe
Job
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oFrac Sleeve completion / stimulation
o Used in North America land shale plays.
o Thousands of applications.
o Coil Tubing operated.
oFirst in Denmark (Offshore)
o Jointed drill pipe/ tubing work string planned
o Frac BHA
oSpecific differences
o Frac. thru tubing
o Under-displacement req. - reverse circulation
Challenge: Work string design for complex stimulation operation7
ChallengesFraccing
(Rates/Pressure)
Hydraulics
Rev./Fwd. Circ.
Mechanical
(Tensile capacity)
Torque
(ability to rotate)
Fishing
(inside 5 ½” Liner)
T/D – Quick Look
oWellPlan: Torque and Drag
o Normal analysis modes
oDefine String and Well components:
o W/String: 5 ½” Drill pipe x 3 ½” Tubing x 3 ½” Frac Assembly
o Dimensions, grade, material strength, capacities, ID’s etc.
oDefine Well Fluid:
o Heavy frac. fluid (13.60 ppg)
o Completion fluid (8.60 ppg)
oDefine Cased Hole Friction Factors:
o Sensitivities: Friction factor 0.10 – 0.20
o 0.25 Max. friction factor for detailed look into
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Key Observations
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Side Force Plot
“Needle Effect”
String depth ~ TD, Abnormally high side force occurred around the bend
Key Observations
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Torque/Drag Stresses Plot
Tr. Shear Stress Peak
Bending Stress PeakTri-axial Stress Peak
Technology Scouting
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WellPlan DrillScan
DrillPlanSysdrill
Software Capabilities
Modelling Accuracy
Simulation Sensitivity
Detailed Investigation
o Torque/Drag Model
o Stiff string algorithm
o Tortuosity model
o Offset/Analogues
o Random incl. dependent azimuth
o Run Parameters:
o Tripping In
o Slide drilling mode (non rotating) – 5.0 – 10.0 kips
o Torque/Drag analysis modes
o Normal analysis
o Drag chart
o 500.0 ft incremental in horizontal leg
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Analysis Parameters
oState of work string in worst case
o RIH and
o Slide Mode
oAssumptions
o Cased hole FF – 0.20/0.25
o Tortuosity Magnitude 1.43 – 1.93 (1.53)
oWork string travel – 14000 – 23000 ft. MD
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Max. Tr. Shear Max. VME
Max. Side Force Buckling/Lockup
Detailed Analysis
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Strin
g Travel
Detailed Analysis
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Strin
g Travel
Max. T/Shear Stresses
Joints of 3 ½” Tbg. - High
stresses
Heel
Detailed Analysis
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Strin
g Travel
Max. VME Stresses
Joints of 3 ½” Tbg. - High VME
stresses
Heel
Transverse Shear
Transverse Shear Stresses
oStress magnitude determined by = 2 x FN / As
o Not Torsional shear stress that acts circumferentially
o It’s perpendicular force – alike shear rams
oWhat is causing high Transverse shear stresses “Needle Effect”
o Needed to investigate further
oWhat is the Failure Limit and what Safety Factor should we use?
o API RP 7G = 0.577 x SMYS
o Safety factor 1.25 for 110 ksi SMYS Tubing
o Transverse Shear Stress limit = 0.5 x 0.8 x 110000 = 44000 psi
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Transverse Shear
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Stationary Knife (sharp edge)
Cake / Knife ExampleCompression generates point load
True Tension Plot: RIH and Slide mode
Solution / Fix
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o Tapered Well Architecture 10 ¾” x 7” x 5 ½”o Cased hole friction factor 0.15-0.20
o Yield failure can happen at high frictiono Design fluids with friction reducerso Calibrate friction factorso Real time Torque/Drag modelling
o Reduce horizontal leg < 21000o Min. Slack off @ frac. BHA < 10.0 kipso Control tortuosity in the horizontal leg –
geo-steering
Results – Tapered Scenario
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Significantly lesser side force
Results – Tapered Scenario
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Significantly reduced
transverse shear stresses
Results – Tapered Scenario
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VME Stresses reduce
significantly FF 0.10-0.20
Summary
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Solution/Fix
Taper down
10 ¾” x 7” x 5 ½”
Keep friction
low
Min. Slack off
Optimize
Lateral length
Scope / Evolve
Transverse shear failure limit
Based on API RP 7G
(torsional shear)
API TR 5C3 ?
Brittle behavior
Failure limit de-rate?
Due to Tension/Compression
Due to Temperature
With bending
What is the Safe operating limit
Tool joint limits same as pipe body?
No. of cycles (Reciprocal)
Shuffle heavy weights?
Around the well bend
Higher cross section area
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Thank You
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