ct drilling
TRANSCRIPT
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© 2002 Weatherford International, Inc. All Rights Reserved
Coiled Tubing Drilling
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Methology
Drill well to producing sands with conventional drilling•
rig
Build curve and run liner•
Run completion tubing (Monobore)•
Move rig off location•
Rig up Coiled Tubing, Pumps, Nitrogen Units and•
Separators for Underbalanced Drilling
Drill horizontal section•
Rig down equipment and test well•
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Advantages of Drilling Horizontal
Section in Underbalanced Mode
Drastically reduce formation damage•
Eliminate differential sticking•
Produce well while drilling•
Increment in rate of penetration•
Well is under control at all times•
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Disadvantages of Drilling in
Underbalanced Mode
Increase in cost of equipment•
Instability of formation during drilling•
Use of Electromagnetic tools•
Well Control•
Corrosion•
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Advantages for drilling with
Coiled Tubing
Lower cost and HSE risk •
Steady State system since there is continous flow and no•
stopping of pumps to make connections minimizing
stuck pipe exposure
Minizes trip times•
Minor environmental impact (small location, close•
ciruit)
Reliable and fast data transmission to surface with•
Electric Line tools.
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c
Prototype Well Diagram
9-5/8”
7”
4-1/2” Tbg
ID=3.92”
4-1/2” Liner
ID=3.92”
SSSV – 1000’ ID=4.52”
(5 ½” nominal)
800’
33’
TD = 11,000’ MD
Hueco de 3 3/4”
Shoe 10,200’ MD
Open Hol e
completion Bottom Temp =
290 °F Gas Well
Bottom Pressure = 2,543 Psi
Permeability = 40 – 180 MDTVD = 9,200’
Eq. Dens fluid: 5,03 ppg
Fluid Base: Oil
Gaseous Base: Nitrogen
Production
Sands
Monobore
Completion
Section Drilled with
Conventional Drilling
Section Drilled with
Underbalance CT
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Surface Equipment
BOOSTERS
NITROGEN
MEMBRANE
COMPRESSORS
WATER & OIL
MEASUREMENT
OIL / WATER
PROCESSING
FACILITIES
GAS
MEASUREMENT
DRILL CUTTINGS DISPOSAL
RETURN MUD to PITS
DRILL CUTTINGS PROCESSING
UBD
CHOKE
MANIFOLD
4 PHASE
SEPARTOR
DATA RECORDING POINTS
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On Location Nitrogen Generating System
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PrimaryCompressors
Quincy, type QSS 850-200, 850 pcm at 200lppc.
Underbalance OperationsEquipment
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Nitrogen Generating Unit -WolfPack
Cost effective solution•On site nitrogen•generation capabilitySuitable for land and•offshore useSmall footprint – no•need for cryo-tanks onlocation
Underbalance OperationsEquipment
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4,000 psiBooster
Booster JoyWB11 @ 4,000PSI
Underbalance OperationsEquipment
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Four Phase separator •
permits the separation
of drilling returns.
Solids.
Gases.
Oil.
Drilling Fluid or H2O.
Underbalanced Operations Equipment
4 Phase Separator
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Data Acquisition System
System gathers all injection and• production information in realtime.
Gas Injection. –
Fluid Injection. –
Gas Production. –
Gas & Crude Production. –
All Temperatures and pressures of – equipment and flow to surface.
Volume of fluid in tanks. –
Produces reports of losses and• gains in real time.
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Coiled Tubing Equipment
Injector Head SS-1100•
Tension = 110 Klbs
Inyec = 40 Klbs
Reel capabilities:•
14.000’ of 2 3/8” tubing
BOP’s and Stripper•
ID = 4 1/16 ; 10 Mpsi WP
Rams (Blind, Shear, slip, Annular)
BOP,s Auxiliar
Data acquisition system:•
CTES – Orion Software
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Coiled Tubing Characteristics
OD = 2 3/8” ; ID = 2.063”; EP = .156” ; 13,500’ long•
Hydraulic Line: OD = .250” (ID = .18”)•
Diameter of 3 conductor Electric Line = 5 /16”•
Ly = 97,880 lbs•
Grade = HS – 90 ; 90,000 psi Overpull•
Resistant to high concentrations of H2S•
Working Pressure = 9,200 psi ; Collapsing Pressure = 9,000 psi•
Weight of tubing with capillary, E-line and Hyd lines = 4.0412 #/pie•
WOB available @ TD = 5,000 lbs•
Overpull available @ TD = 30,000 lbs•
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Directional Drilling Tools
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Measuring and Orienting
Weatherford 2 7/8” or 3 1/8”•
Requires 2 3/8” OD Hibrid Coil with:•
Electric Line to send to surface real time•
drilling data (Inclination, azimuth, gamma
ray, downhole pressure)
Two hydraulic lines to operate orienting•
tool and operate hydraulic releasemechanism
Tubing 2” 3/8
Hydraulic
Lines
Electric Line
Capillary
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BHA Schematic
CT 2 3/8” Hibrid
(1 E-line & 2 Hyd lines)Downhole Motor
w/ Bent Housing
PDC Bit
3 3/4”
Hydraulic
Orienting Tool
MWD (GR, Pressure, D&I) Hydraulic
Disconnect
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CT Directional BHA Specifications
Supplier: Bakke Oil Tools through Dalen Drilling Services
BHA Size: 3-1/8” or 2-7/8”
Electronics: Full Directional Suite (Russell Probe) and Gamma Ray & Pressure
Wireline: 7/16” hepta cable rated for 175oC
Capillaries: 1/4” or 3/8” stainless steel annular
Features: Circulation Sub
Orienter: 400 degree rotation, 1330 ft-lbs torque
Hydraulic and Flow Activated Release Tools
Upper and Lower Dual Flapper Check Valves
Deployment Quick Connect
Hydraulic Orienting Tool
c/w Circulating SubCT Connector c/w
DF Check Sub Hydraulic Disconnect Quick Connect
Internal /
External
Pressure Sub
Non-mag Collar c/w
Directional Package and
Gamma Ray DF Check SubPositive Displacement
Mud Motor c/w SABHDrill
Bit
Total BHA Length ~13m
2 Stainless Steel Capillary Tubes for Orienting tool operation
1 Multi-conductor Wireline for Steering Tool / Gamma operation
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The CTD™Motor
Elevated WOB Loads•Load Sharing bearing assembly provides for elevated WOB – and jarring capacity
Elevated Side Load Capabilities•High strength materials and CTD™ design allow for – extended periods in high side load environments.
Elevated Overpull Loads•Balanced connections throughout the design provide for – elevated safe overpull and jarring capacity
Sealed Bearings•Critical in UBD service –
Maximum Torque Output•Power sections that minimize stalls –
CTD™ Downhole Motor
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CTD ™ Motor Issues/Contingencies
Power section designed and testing for high N2 and•temperature applications.
Testing of mud/elastomer interaction can be conducted at•Weatherford facilities in Houston
CTD™ Downhole Motor
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Surface Equipment
Worksite Trailer
Driller’s Display
Remote Display
Interface Box
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Publications/Experience
Experience in the drilling of 25 underbalanced wells
with Coiled Tubing
SPE 72373 - Underbalanced Coiled-Tubing Drilling in a
Thin Gas Storage Reservoir: A Case Study
SPE - Coiled Tubing Underbalanced Drilling from aFloating Production Vessel in the North Sea
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Case Histories
Well BP Courson BuchanAlpha
NAL09-29 PCP 10-12 ParaRainbow
ParaRainbow
TVD (ft) 3458 9186 4110 4668 836 721
Hole Size (in) 4-3/4 3-1/2 4-3/4 4-3/4 3-7/8 3-7/8
Distance Drilled (ft) 374 1295 278 131 492 597
Hours in Hole 17 360 32 6 20 43
Annular Pressure (psi) 710 2103 1450 1624 188 188
Q Liq/Gas (gal/scft) 40/1059 147 66/882 198 l/min
Crude
31/423 66/176
Formation dolomite Sandstone Carbonate Carbonate Sand Sand
ROP (ft/hr) 16 13 – 39 98 32 98 45
Max DLS (deg/100 ft) 35 35 29 15.5 15 11
H2S (%) 100 0 trace 90 ppm/CO2
INJ
200 200
Temperature (deg F) 89 185 167 130
Failures See attached 1-pressure
Sub
None None None None
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Well 49-1W5M Penn 4621 Penn 4621st 77-18W4M 76-18W4M 76-18W4M
TVD (ft) 4895 2952 2952 1312 1312 1312
Hole Size (in) 3-7/8 4-3/4 4-3/4 3-7/8 3-7/8 3-7/8
Distance Drilled (ft) 196 278 836 229 547 777
Hours in Hole 61 44 111 60 42 29
Annular Pressure (psi) 870 435 652 217 188 217
Q Liq/Gas (gal/scft) 33/475 105/282 105/459 52/423 66/353 66/353
Formation Glauconite Sandstone Sandstone Nisku Nisku Nisku
ROP (f/hr) 26 19 23 13 - 49 13 - 65 13 – 65
Max DLS (deg/100 ft) 52 33 27 5 5 5
H2S (%) 0 0 0 0 0 0
Temperature (deg F) 140 90 90 75 75 75
Failures 1 - gamma none None -collector None None
Case Histories
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Well Thunder 15-
34
Murphy C-66
TVD (ft) 3635 9186
Hole Size (in) 6-1/8 6-1/8
Distance Drilled (ft) 754 229
Hours in Hole 90 46
Annular Pressure (psi) 754
Q Liq/Gas (gal/scft) 192/494 132/1306
Formation Sand
ROP (ft/hr) 13 16
Max DLS (deg/100 ft) 15 1
H2S (%) 0
Temperature (deg F)
Failures none none
Case Histories
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Risk Assesment
Risk Controlling Factors
Coiled Tubing Getting Stuck Do not stop pumps
Keep tubing moving
If it is necessary to stop pumping, move CT to safe
location
Follow procedure for disconnecting BHA
Identify the stuck mode/location (Annular pressure,
Orienter, Reactive torque)
Use different fluids (viscous gel, nitrogen)
Have fishing tools on location
Side Track in open hole
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Risk
Directional tools fail holeExcessive Vibrations: Changes in Parameters
Weight on Bit
Size of tool
Type of Bit ( PDC, Diamond, Tri-cone)
Change fluid mix (gas/liquid) and flow rates
Intgrity of BOP Operational inspection and testing
Spare parts
Test CT interal pressure Pre-Operational Inspection
Depth Control Operational procedure for depth correlation
Depth correlation with shoe
BOP Pre-operational planning
Use of combination rams
Hole Cleaning Planning with good annular velocity
Inspection of cuttings and CT weight
Risk Assesment
Controlling Factors
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Future Projects
Well optimization (Drilling 9-5/8” from surface)
Re-Entry of existing wells (80% of experience is in Re-
Entries)
Larger Underbalanced hole with 4-1/8” OD BHA
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Re-Entries with TT Whipstock
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Multi-Laterales
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Pre-Milled Windows
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