7/31/2019 Recent Advances in Complex Well Design
1/26
SPE DISTINGUISHED LECTURER SERIESis funded principally
through a grant of the
SPE FOUNDATION
The Society gratefully acknowledgesthose companies that support the program
by allowing their professionalsto participate as Lecturers.
And special thanks to The American Institute of Mining, Metallurgical,and Petroleum Engineers (AIME) for their contribution to the program.
7/31/2019 Recent Advances in Complex Well Design
2/26
7/31/2019 Recent Advances in Complex Well Design
3/26
7/31/2019 Recent Advances in Complex Well Design
4/26
Annular Pressure Build-up (APB)
7/31/2019 Recent Advances in Complex Well Design
5/26
5
Annular Pressure Buildup (APB)
Origin of APB loads
Mitigating APB
Principles and solution categories
Specific well construction tools
16 in. casing collapse from APBduring circulation
7/31/2019 Recent Advances in Complex Well Design
6/26
6
The origin of APB
What do we do aboutthis hydrocarbon
bearing zone?
20"
16"
Mud Line
TOC?
7/31/2019 Recent Advances in Complex Well Design
7/267
APB depends on
Mechanical and thermal properties of fluid
Flexibility of the confining boundary
Temperature increase
Considering the fluid component,
pC
TVVf
fff1
7/31/2019 Recent Advances in Complex Well Design
8/268
Mitigating APB
Brute Force
Thick-walled casing
Fluid Properties
Foam spacer
Fluids with low psi/F
Cement entire annulus
Control the Load
Vacuum Insulated Tubing (VIT)
Nitrogen blanket
Gelled brine
Connection leak integrity
Initial annulus pressure
Container Flexibility
Vent the annulus
Active path to surface
Relief mechanism
Formation fracture/TOC
Rupture disks
Grooved casing
Annulus communication
Syntactic foam
Avoid trapped pressures externalto annulus
7/31/2019 Recent Advances in Complex Well Design
9/269
Mitigating APB
Fluid Properties
Foam spacer
Fluids with lowpsi/F
Cement entireannulus
7/31/2019 Recent Advances in Complex Well Design
10/2610
Mitigating APB
Container Flexibility
Vent the annulus
Active path to surface
Relief mechanism
Formation fracture/TOC
Rupture disks
Grooved casing
Annulus communication Syntactic foam
Avoid trapped pressuresexternal to annulus
7/31/2019 Recent Advances in Complex Well Design
11/2611
Container Flexibility
Vent the annulus
Active path to surface
Relief mechanism
Formation fracture/TOC
Rupture disks
Grooved casing
Annulus communication Syntactic foam
Avoid trapped pressuresexternal to annulus
Mitigating APB
7/31/2019 Recent Advances in Complex Well Design
12/2612
Mitigating APB
Control the Load
Vacuum Insulated Tubing
Nitrogen blanket
Gelled brine
Connection leak integrity
Initial annulus pressure
5100
5150
5200
5250
5300
5350
5400
5450
5500
5550
5600
80 90 100 110 120 130 140
Temperature, Deg F
MeasuredDepth
,ft.
Gelled
Brine 2
Gelled
Brine 1
Connection
Outer Tube
Inner Tube
Vacuum Annulus
Tubing A Annulus
Weld
ConnectionConnection
Outer TubeOuter Tube
Inner Tube
Vacuum AnnulusVacuum Annulus
Tubing A AnnulusTubing A Annulus
Weld
7/31/2019 Recent Advances in Complex Well Design
13/2613
5100
5150
52005250
5300
5350
5400
5450
5500
5550
5600
80 90 100 110 120 130
Temperature, Deg F
Mea
suredDepth,
ft.
Gelled Brine 1
Gelled Brine 2
Mitigating APB Vacuum Insulated Tubing (VIT)
Connection
Outer Tube
Inner Tube
Vacuum Annulus
Tubing A Annulus
Weld
ConnectionConnection
Outer TubeOuter Tube
Inner Tube
Vacuum AnnulusVacuum Annulus
Tubing A AnnulusTubing A Annulus
Weld
7/31/2019 Recent Advances in Complex Well Design
14/26
Designing within wellbore limitations
7/31/2019 Recent Advances in Complex Well Design
15/2615
36"
22" (224.0 ppf X-
13-5/8" (88.20 p
9-7/8" (62.8 ppf
7" (38.0 ppf C-110
28"
11-7/8" (71.80 p
18" (117.0 ppf N-
16" (97.0 ppf P-11
RISK
DEPTH
36"
22"(Surface Casing)
13-5/8"(Deep Protective Casing)
9-7/8"(Production casing or tiebacks)
7"(Production Liners)
28"
11-7/8"(Drilling Liners)
18", 16"(Drilling Liners)
Deepwater HPHT wells, maintaining hole size
Geometric constraints
Minimum production tubulars,SSSV
Maximum 18-3/4 in. bore
Possible solutions
Riserless drilling
Managed pressure drilling
Designer muds
Revisit casing risk profile
Probability x consequence
Recovery
Empirical validation
Solid expandable liners
7/31/2019 Recent Advances in Complex Well Design
16/2616
Maintaining hole size - example
8-1/2 in. hole on bottom
Production tubulars with18,000+ psi internal yield
5-1/2 in. tubing
9-3/8 in. upper tieback drift(subsurface safety valve)
Clearance outside tiebackfor APB mitigation (syntacticfoam)
7/31/2019 Recent Advances in Complex Well Design
17/26
Extreme landing loads
7/31/2019 Recent Advances in Complex Well Design
18/2618
Landing strings and slip crushing
Landing string static loadsapproaching 1.5 mm lbs
Impulse load duringtripping
Heave induced excitation
Applicability of Reinhold-Spiri
To current systems?
To other slip problems?
7/31/2019 Recent Advances in Complex Well Design
19/26
19
Understanding slip systems
Strain gauged samplesindicate
Non-uniform loading
Worst loading may bebetween inserts
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
20000
22000
24000
0 0.01 0.02 0.03 0.04 0.05 0.06 0.07 0.08 0.09 0.1
w0, in.
pL,
lb/in
NUMBER OF LINE LOADS = 3
YOUNG'S MODULUS = 30x106 psiPOISSON'S RATIO = 0.3
YIELD POINT = 100,000 psiWALL THICKNESS = 0.5 in
MEAN RADIUS = 3.0 in
AXIAL TENSILE LOAD = 100,000 lb
AXIAL TENSILE LOAD = 300,000 lb
AXIAL TENSILE LOAD = 500,000 lb
AXIAL TENSILE LOAD = 700,000 lb
AXIAL TENSILE LOAD FOR PIPE YIELD (WITH pL = 0) = 942,500 lb
AXIAL TENSILE LOAD = 900,000 lb
7/31/2019 Recent Advances in Complex Well Design
20/26
Probabilistic design considerations
7/31/2019 Recent Advances in Complex Well Design
21/26
21
Detailed inspection data
7/31/2019 Recent Advances in Complex Well Design
22/26
22
Application calculation of cross-sectional area
7/31/2019 Recent Advances in Complex Well Design
23/26
23
Application detailed collapse prediction
Line pipe samples
X65, D/t 16-18+
Detailed input
Wall, diameter Axial, hoop s-e coupons
Residual stress
Full scale tests
Pressure with bending
Collapse, propagation
Excellent results (
7/31/2019 Recent Advances in Complex Well Design
24/26
24
Probabilistic advantage using rupture disks
Disk pressures have tight,controlled tolerances ( 5%on rupture pressure)
Contrast with 12.5% wall
tolerance and 10-30 ksitensile strength variation forcasing body
Wide uncertainty ofcasing rupture and
collapse pressures
Cannot count on outerstring failing first
7 Production Liner
Consider ifshoe plugs
ABC
Pipe Performance Uncertainty
16"MIYPRatin
9-7/8"Colllapse
Rating
9-7/8"High
CollapseRating
7,500 10,000 12,500 15,000 17,500
Pressure (psi)
16" Barlow
16" Rupture
9-7/8" API Collapse
9-7/8" Tamano Collapse
Pipe Performance Uncertainty
16"MIYPRatin
9-7/8"Colllapse
Rating
9-7/8"High
CollapseRating
7,500 10,000 12,500 15,000 17,500
Pressure (psi)
16" Barlow
16" Rupture
9-7/8" API Collapse
9-7/8" Tamano Collapse
7/31/2019 Recent Advances in Complex Well Design
25/26
25
ISO 10400 (New API 5C3)
Clause Subject Comments
1-5 Introduction, symbols
6 Triaxial yieldvon Mises yield
Axial yield, internal yield pressure
7 Ductile rupture All new
8-17Collapse, connections,
elongation, etc.
Identical to existing formulas
AnnexesDetails, derivations,property tables
Probabilistic properties (fromproduction data)
7/31/2019 Recent Advances in Complex Well Design
26/26
Conclusions
No lack of challenging problems
Continuing research on annular pressure mitigation
Rethinking old solutions
Design stretch via probability
Increasing support from standards
Top Related