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TAMU - PemexOffshore Drilling
Lesson 11
Formation Testing
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Formation Testing
Downhole Test Equipment - valve
Slip Joints
Test String
Surface Test Equipment
T = H + wd
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Formation Testing
Exploration wells are drilled primarily for
information (not production):
from logs
drilled cuttings
cores
DSTs, etc.
Testing from floater is very expensive.Careful planning is therefore essential.
Appropriate selection of equipment for testing is essential. Order equipment early.
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Safety Precautions - Well Testing
1. Always set the test packer in the
casing or in the liner, never in the
open hole.
2. Perform testing in a liner or casing.
3. Use a test tree in the BOP stack.
Include an emergency downhole shut-off near the formation. Safety devices
will be discussed with the equipment.
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Safety Precautions
4. Stop the test if any of the following
danger signals occur:
a. Pressure approaches the pressure
rating of any of the equipment used.
b. Equipment becomes overloaded by
excessive production.
c.Annular pressure indicatescommunication between the annulus
and the test string.
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Safety Precautions
4. Danger signals, (continued)
d. Gases reach explosive levels incritical areas, or poison gases
are produced.
e. Vessel motion approaches
unsafe conditions.
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Safety Precautions
5. Commence flow during daylight
6. Release packer during daylight
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Test Valve
operated
by AnnulusPressure
Apply
Annulus
Pressure
2,000-2,500
psiApply 1,000-1,500 psi to start flow
Halliburton and Johnston both have test valves of this type. Below 1,000 psi valve is closed.
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Johnston MFE
(Multiple Flow Evaluator)
Valve is opened by reciprocation and
requires a full cycle before actuation.
When tool is first set down on packer, the test
valve will open after 3-5 minutes.
Picking up and setting down will shut off the
flow.
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Johnston MFE (contd)
Each alternate reciprocation cycle will open
or close the valve.
Valve can be opened or closed any numberof times.
Halliburton Hydraspring Tester isopened by compression; is closed when no
compression. Set for ~ 20,000 lbf.
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Slip Joint Safety Valve.
Top of Upper Most Slip Joint
Valve Mandrel ofSlip
Joint Safety Valve
Bottom of LowerSlip Joint
Seal and Port Section of
Safety Valve
Opens when in tension. Closed when in compression.
Shuts off flow. RUN below mud line.
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Figure8.3
Volume -
pressure
balancedslip joint.
Port to Tubing
Chamber for
Tubing Fluid
Chamber forAnnular Fluid
Port to Wellbore
Designed to eliminate pressure and flow surges resulting
from vessel heave. V = const (?)
{not needed with heave compensation system}
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Figure 8.4
Example ofseafloor
shut-in
equipment.
Shear-Blind
Rams Closed
Valves Closed
K&C Valves Open
- to monitor annulus
pressure
Pipe Rams Closed
Valves Open
Hang-off Joint
During Test
Annulus
Pressure
Control
Produced Fluids
to Surface
(a) During Test
Tree inside the BOP and Wellhead. Hydraulic pressure from surface holds valves open.
(b) Well Shut in.
Connections to
Surface Removed
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Space Out for Test Tools
The space out procedure can be as follows:
1. Land shoulder in wellhead and mark
pipe (only the large shoulder will land
in the wellhead).
2. Pick up at about 18 feet (shoulder about
4 feet above rams)3. Close rams & land shoulder by lowering
4 feet
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Space Out-continued
4. Mark Pipe
5. Open rams and pick up 20 feet
a. Lower slip joint stroke 12 feet
b. Tester open 2 feet
c. Packer set distance 1 foot
Half of upper slip joint 5 feet
6. Set Packer
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Space Out-continued
7. Lower handoff shoulder and hang off
on rams. When the packer is set, the
hang off point on the tool will be about
19 feet above the rams.
NOTE:A weight loss approximately equal
to the weight of the string below theupper slip joints will indicate that the
packer has been set.
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Subsea test tree
Test valve
Pressure recorder
Slip joints
Slip joints safety valves
Packer
Hydraulic line
Figure 8.5
Example test
string
arrangement
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Figure 8.6
Test string- flowing
position
Hydraulic Hose
for Test Tree
Mudline
Upper Test TreeShoulder Landed on
Pipe Rams
7 Casing
3 1/2 Tubing
20,000 lbs of
3 1/2 tubing
Packer
Perfs.
UpperSlip Joints
Reciprocal Tester (Open)
LowerSlip Joints
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Test Valve Procedure:
The test tree in the example (Table 8-1)
has the distance of eight feet between
the upper hang-off shoulder and the
lower hang-off shoulder. In this case,the procedure might be:
1. Land the tree in wellhead andmark pipe (only large shoulder will
land in the wellhead).
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Test Valve Procedure:
3. Close rams and land upper shoulder
by lowering string about 4 ft.
4. Mark pipe.
5. Open rams and pick up about 17 ft.
6. Set packer and lower string to about
10 ft. below the lower mark.
7. Close rams and land lower shoulderon the rams by lowering the string about
2 ft.
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Legend
SSV Surface Safety Value
SA Sample Connection
CI Chemical Injection
DWT Dead Weight TesterTI Temperature Indicator
HP High Pressure
LP Low Pressure
Figure 8.8
Schematic ofan oil well test
system.
1. Gas Oil Flushing
2. Water Flushing
3. Pressure Testing
4. Kill Line
Separator Separator
Heater
Flowline Manifold
Manifold
Tank Piston
Pump
Burner
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Horizontal Test Separator
OIL
WATER
GAS
Measure flow rates for of gas and oil. Record pressures and choke size. Do not overload.
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Gas Inlet
Atomizing
Gas/Air Inlet
Forward
WaterSpray
Heat Shield
WaterSpray
Oil Inlet
Isometric section of a 10,000 BOPD burner
Smokeless Incineration - i.e., complete combustion
Atomize the oil spray, add air or air/gas mixture. Ignited by pilot. Electric ignition. Heat shield
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(W = w (s
Consider a small section
of the anchor chain:
(T = ?
E
(T = (W sin E
Prove: T = H + wd
Along chain:
7F = 0
E
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(T = (W sin E
But,(
W = w(
sso, (T = w (s sin E
But, (s sin E = (h
so,(
T = w(
h
7 (T = 7 w (h = w 7 (h
(T = ?
E
Prove: T = H + wd
(h
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Prove: T = H + wd
(T = w (h
7 (T = 7 w (h = w 7 (h
T - H = wh
T = H + wd
QED
(T = ?
H
h
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Alternate Proof: T = H + wd
H
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)iv(0dx
dy0,xwhen
(iii)w
Hdy
(ii)tandxdy
(i)cosTH
!!
!
U!
U!
Alternate Proof: T = H + wd
H
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Prove: T = H + wd
:Catenaryof
H
xwcosh
w
Hy
!
(vi)
H
xwhsin
H
w
w
H
dx
dy
!@
(vii)H
xwsinhtan:(ii)Eqn.From
!U@
(v)
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Prove: H = H + wd
U!U!U
!2
c sT:(i). secHsecHFr
!U!
H
xwsinh1Htan1H:(vii)Eqn.From 22
!
!
HxwcoshcoshH 2 H
HxwT
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Prove: H =T- wd
wycosFrom !
!
H
xwh
w
wHT:(v)Eqn.
HwdFrom !
!
w
HdwT:(iii)Eqn.
wdHT !.e.i
( )
!
H
xwcosh
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NAVS
TAR GPS
NAVSTAR:
Navigation System withTime and Ranging
GPS: Global Positioning System
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Frequently Asked Questions
1. What is GPS?
2. How is GPS used?
3. Who uses GPS?
4. Whats the status of the GPS?
5. What is the Standard Positioning Service?
6. Where can I find courses on GPS?7. What is the status of Selective Availability (SA)?
8. What is GPS Rollover?
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NAVSTAR GPS
A space-based radio positioning system
designed to provide highly accurate,
continuous, world-wide positioning, velocity,and time information . . .
to an unlimited number of suitably equippedusers anywhere on or near the surface of the
earth.
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NAVSTAR GPS
System Components
Space (Transmitter)
Control
User (Receiver)
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Space Segments
Consists of a constellation
of24 satellites in six orbital planes
(inclined at 55 degrees)
orbiting at an altitude of10,900 miles.
Nominal period of orbit is 12 hrs.
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Control Segment
based at Falcon AFB, CO
1 - Master Control Station
2 - Monitor stations & ground antennasfor communications and control
Users
Vehicle tracking to surveyingHandheld to large vehicles
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Transmits continuously on the same
two L-band Frequencies
C/A-Code-Coarse Acquisition
(Civilian)
P-Code-Precision Code (Encrypted
Military)
NAVSTAR GPS
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Unknowns (4)
Knowns (4)
Satellites
n,U,U,U
NAVSTAR GPS
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Loran C/D
Ground based radio navigation
Coverage --- regional
Range --- 1,800 miles
Error 2-D --- 1,500 ft
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Omega
Eight very low frequency transmitters
ground based radio navigation
Coverage --- 98% of globe (night)
88% of globe (day)
Error 2-D --- 2-4 nautical miles
1,000 to 2,000 ft DN mode
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Transit
Five to eight satellite constellation low
altitude polar orbit
Space borne radio navigation system
Coverage --- global but intermittent 2-D
Error --- 1500 ft
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NAVSTAR GPS
C/A-Code-Coarse Acquisition (Civilian)
Coverage --- Global instantaneous
Error 2-D --- 330 ft
P-Code-Precision Code (EncryptedMilitary)
Error 2-D --- a few ft