Introduction
Background of study
Four oil producer wells will be drilled in Berlian East field. Few procedures are
designed to cover the well completion operations for the Berlian East oil
producers wells with maximum inclination of 90 degree.
Well objectives
To complete the well safely without harm to personnel, no damage to the
asset & environment.
To complete the oil producer wells in M2/3, M7/8, M9/14 zones.
-Primary objective: to provide drainage points for each zones
To install fit to purpose completion equipment & techniques to prolong well
design life.
To achieve an initial anticipated rate as per below for each wells.
Well A01=3200 stb/d
Well A07=2500 stb/d
Well A08=2300 stb/d
Well A11=1900 stb/d
1
SCOPE OF STUDY/DELIVERABLES
Nodal
Analysis
Completion
Design
Sand Control
Requirement
P-TECH
STUDY
Artificial Lift
Requirement
Material
Design
2
WELL COMPLETION OBJECTIVE
4 wells
1.
2.
3.
4.
5.
6.
To develop 3 prospective reservoirs:
-M2/3, M7/8 and M9/14
Deviated well, max angle 90°
9 5/8” casing set just above M2/3 sand
7” liner set across pay zones
Target Rate:
M2/3
M7/8
M9/14
Well A1
Well A7
Well A8
Well A11
Target rate
(stb/day)
3200
2500
2300
1900
Layers
M2/3 &
M7/8
M7/8
M7/8
M9/14
L-sand
Basem ent
3
NODAL ANALYSIS
Well A01 Performance Model
Well A07 Performance Model
Well A08 Performance Model
Well A11 Performance Model
A01
A01 Well Performance Model
A-01 producer
Nodal Analysis Input
Reservoir data
Pressure:
Temperature:
Net sand:
Porosity:
Permeability:
FTHP:
1800 psia
215 F
22 m (M2/3 & M7/8)
26% (average)
700 mD
450 psia
Fluid parameters
API:
Rsi:
GOR:
WC:
41.4
1400 scf/stb
1400 scf/stb
0%
Sensitivity analysis
GOR:
Tubing:
Pres:
1400,1600,1800 scf/stb
2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”
1800 ,1600,1400 psia
5
A01
Sensitivity of tubing size
2-3/8” tbg
2-7/8” tbg
3-1/2” tbg
4-1/2” tbg
Tubing size
2.375
2.875
3.5
4.5
Well A1
2163.6
3304.7
4832.8
7075
Oil rate (stb/day)
Well A7
Well A8
1887.9
1904.4
2789.5
2817.8
3901.4
3959.6
5291
5378.9
Well A11
1538.4
2163.5
2828.4
3516.6
2-7/8” & 3-1/2” capable to deliver target rate of 3200 bopd
6
A01
Tubing Performance Analysis: Operating rate vs GOR as Pres depleted
Reservoir
pressure (psig)
1800
1600
1400
GOR
1400
1600
1800
1400
1600
1800
1400
1600
1800
Oil rate (stb/day)
2.875
3.5
3304.7
4832.8
3483.5
5045.5
3467.8
4913.8
2493.9
3702.5
2718.6
3911.7
2829.1
4036.5
1655.3
2467.9
2008.5
2917
2150.3
3103.3
diff
% diff
1528.1
1562
1446
1208.6
1193.1
1207.4
812.6
908.5
953
31.61935
30.95828
29.42733
32.64281
30.50081
29.91205
32.92678
31.14501
30.70924
7
Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb
A01
Well Capacity vs Tubing Size
Reservoir
pressure
(psig)
1800
1600
1400
Oil rate (stb/day)
Water cut
0
10
20
0
10
20
0
10
20
2.875
3304.7
2905.2
2494.6
2493.9
2142.9
1778.3
1655.3
1336.5
924.1
3.5
4832.8
4235.7
3618.7
3702.5
3166.4
2600.4
2467.9
1974.6
1386.1
diff
% diff
1528.1
1330.5
1124.1
1208.6
1023.5
822.1
812.6
638.1
462
31.61935
31.41157
31.06364
32.64281
32.32377
31.61437
32.92678
32.31541
33.33093
@max THP = 450 psia
When WC = 0%
• 3-1/2” tubing gives 32%
higher rate then a 2-7/8”
tubing
When WC = 20%
• 3-1/2” tubing gives 31%
higher rate then a 2-7/8”
8
tubing
A07
A01 Well Performance Model
A-07 producer
Nodal Analysis Input
Reservoir data
Pressure:
Temperature:
Net sand:
Porosity:
Permeability:
FTHP:
1800 psia
215 F
10 m (M7/8)
25% (average)
800 mD
450 psia
Fluid parameters
API:
Rsi:
GOR:
WC:
41.4
1400 scf/stb
1400 scf/stb
0%
Sensitivity analysis
GOR:
Tubing:
Pres:
1400,1600,1800 scf/stb
2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”
1800 ,1600,1400 psia
9
A-07
Sensitivity of tubing size
2-3/8” tbg
2-7/8” tbg
3-1/2” tbg
4-1/2” tbg
Tubing size
2.375
2.875
3.5
4.5
Well A1
2163.6
3304.7
4832.8
7075
Oil rate (stb/day)
Well A7
Well A8
1887.9
1904.4
2789.5
2817.8
3901.4
3959.6
5291
5378.9
Well A11
1538.4
2163.5
2828.4
3516.6
2-7/8” & 3-1/2” capable to deliver target rate of 2500 bopd
10
A07
Tubing Performance Analysis: Operating rate vs GOR as Pres depleted
Reservoir
pressure (psig)
1800
1600
1400
GOR
1400
1600
1800
1400
1600
1800
1400
1600
1800
Oil rate (stb/day)
2.875
3.5
2598.8
3649.8
2772.1
3782.3
2855.3
3843.1
1885.8
2658
2162
2947.7
2296
3089.3
1113
1580.5
1541.9
2115.3
1717.2
2336.7
diff
% diff
1051
1010.2
987.8
772.2
785.7
793.3
467.5
573.4
619.5
28.7961
26.70862
25.70321
29.05192
26.65468
25.67896
29.57925
27.10727
26.51175
11
Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb
A07
Well Capacity vs Tubing Size
Reservoir
pressure
(psig)
1800
1600
1400
Oil rate (stb/day)
Water cut
0
10
20
0
10
20
0
10
2.875
2598.8
2262.3
1920.3
1885.8
1590.2
1262.7
1113
784.2
3.5
3649.8
3153.2
2637.6
2658
2213.4
1729.3
1580.5
1142.9
diff
% diff
1051
890.9
717.3
772.2
623.2
466.6
467.5
358.7
28.7961
28.25384
27.19518
29.05192
28.15578
26.98202
29.57925
31.38507
@max THP = 450 psia
When WC = 0%
• 3-1/2” tubing gives 29% higher rate
then a 2-7/8” tubing
When WC = 20%
• 3-1/2” tubing gives 27% higher rate
then a 2-7/8” tubing
12
A08
A01 Well Performance Model
A-08 producer
Nodal Analysis Input
Reservoir data
Pressure:
Temperature:
Net sand:
Porosity:
Permeability:
FTHP:
1800 psia
215 F
10 m (M7/8)
25% (average)
7800 mD
450 psia
Fluid parameters
API:
Rsi:
GOR:
WC:
41.4
1400 scf/stb
1400 scf/stb
0%
Sensitivity analysis
GOR:
Tubing:
Pres:
1400,1600,1800 scf/stb
2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”
1800 ,1600,1400 psia
13
A-08
Sensitivity of tubing size
2-3/8” tbg
2-7/8” tbg
3-1/2” tbg
4-1/2” tbg
Tubing size
2.375
2.875
3.5
4.5
Well A1
2163.6
3304.7
4832.8
7075
Oil rate (stb/day)
Well A7
Well A8
1887.9
1904.4
2789.5
2817.8
3901.4
3959.6
5291
5378.9
Well A11
1538.4
2163.5
2828.4
3516.6
2-7/8” & 3-1/2” capable to deliver target rate of 2300 bopd
14
Tubing Performance Analysis: Operating rate vs GOR as Pres depleted
Reservoir
pressure (psig)
1800
1600
1400
GOR
1400
1600
1800
1400
1600
1800
1400
1600
1800
Oil rate (stb/day)
2.875
3.5
2817.8
3959.6
3018
4144.8
2990.9
4005.9
2108.3
2989.7
2310.9
3124.3
2419.1
3237.7
1362.8
1904.9
1684.1
2290
1833.4
2480.8
diff
% diff
1141.8
1126.8
1015
881.4
813.4
818.6
542.1
605.9
647.4
28.83625
27.18587
25.33763
29.48122
26.03463
25.28338
28.45819
26.45852
26.09642
A08
Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb
15
A-08
Well Capacity vs Tubing Size
Reservoir
pressure
(psig)
1800
1600
1400
Oil rate (stb/day)
Water cut
0
10
20
0
10
20
0
10
20
2.875
2817.8
2455.7
2091.3
2108.3
1790.5
1453
1362.8
1041.9
592
3.5
3959.6
3426.6
2880.2
2989.7
2524
2005.8
1904.9
1455.1
849.4
diff
% diff
1141.8
970.9
788.9
881.4
733.5
552.8
542.1
413.2
257.4
28.83625
28.33421
27.39046
29.48122
29.06101
27.56008
28.45819
28.39667
30.30374
@max THP = 450 psia
When WC = 0%
• 3-1/2” tubing gives 29%
higher rate then a 2-7/8”
tubing
When WC = 20%
• 3-1/2” tubing gives 27%
higher rate then a 2-7/8”
tubing
16
A11
A01 Well Performance Model
A-11 producer
Nodal Analysis Input
Reservoir data
Pressure:
Temperature:
Net sand:
Porosity:
Permeability:
FTHP:
1800 psia
215 F
15 m (M9/14)
25% (average)
600 mD
450 psia
Fluid parameters
API:
Rsi:
GOR:
WC:
41.4
1400 scf/stb
1400 scf/stb
0%
Sensitivity analysis
GOR:
Tubing:
Pres:
1400,1600,1800 scf/stb
2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”
1800 ,1600,1400 psia
17
A-11
Sensitivity of tubing size
2-3/8” tbg
2-7/8” tbg
3-1/2” tbg
4-1/2” tbg
Tubing size
2.375
2.875
3.5
4.5
Well A1
2163.6
3304.7
4832.8
7075
Oil rate (stb/day)
Well A7
Well A8
1887.9
1904.4
2789.5
2817.8
3901.4
3959.6
5291
5378.9
Well A11
1538.4
2163.5
2828.4
3516.6
2-7/8” & 3-1/2” capable to deliver target rate of 2300 bopd
18
Tubing Performance Analysis: Operating rate vs GOR as Pres depleted
A11
Oil rate (stb/day)
Reservoir
pressure (psig)
1800
1600
1400
GOR
1400
1600
1800
1400
1600
1800
1400
1600
1800
2.875
2006.2
2194.5
2177.8
1401
1606.9
1716.7
649
1063.4
1227.8
3.5
2622.6
2765.4
2678.3
1815.3
1993.6
1815.3
859.2
1349.4
1556.2
diff
% diff
616.4
570.9
500.5
414.3
386.7
98.6
210.2
286
328.4
23.50339
20.64439
18.68723
22.82267
19.39707
5.431609
24.46462
21.19461
21.10269
19
Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb
A-11
Well Capacity vs Tubing Size
Reservoir
pressure
(psig)
1800
1600
1400
Oil rate (stb/day)
Water cut
0
10
20
0
10
20
0
10
20
2.875
2006.2
1715
1416.1
1401
1128.1
813
649
0
0
3.5
2622.6
2217.9
1789.5
1815.3
1451.9
1009.8
852.9
0
0
diff
% diff
616.4
502.9
373.4
414.3
323.8
196.8
203.9
0
0
23.50339
22.6746
20.86616
22.82267
22.30181
19.48901
23.90667
0
0
@max THP = 450 psia
When WC = 0%
• 3-1/2” tubing gives 26%
higher rate then a 2-7/8”
tubing
When WC = 20%
• 3-1/2” tubing gives 21%
higher rate then a 2-7/8”
tubing
20
Nodal Analysis - Conclusion
 All
zones present will be completed in 7” casing
2-7/8"
A-01
x
A-07
x
A-08
A-11
x
x
3-1/2"



x
4-1/2"
x
x
x
x
 3-1/2”
& 4-1/2” tubing can achieved overall target rate for A-01,A-07,A-08 & A-11
 4-1/2” tubing carry significant gain against 3-1/2”, thus provides fastest depletion
 Tubing size selection restricted by production casing size
 If all zones come in as planned, 3-1/2” tubing will be used as it provides the
flexibility
21
Artificial lift requirement
 No
critical requirement for GL, however string will be equipped with minimal GLM
to facilitate initial kickoff
NO GAS LIFT
NO FLOW!
22
WITH GAS LIFT
23
MATERIAL SELECTION
CO2
mole %
6.35
H2S
ppm
0
CO2 partial
pressure atm
7.73
H2S partial pressure
atm
0
Result:
The chart shows that required
material is 13Cr.
X
Proposed tubing
material: 13 Chrome
24
SAND CONTROL
No core data available for Berlian East field.
Based on the well test data conducted at BE-4 well in 1992, 4 pptb sand has been
identified.
Slotted liner will be used for all wells as a sand control mechanism
POSSIBLE PRODUCTION PROBLEM
Berlian East field shows high percentage of C02 and low percentage of
H2S. Possible corrosion problem might occur. Thus, reservoir surveillance
and monitoring should be frequently conducted by:
Caliper survey:
As and when required to determine the tubing corrosion.
25
DUAL STRING WELL COMPLETION SCHEMATIC
Well type: oil producer
Completion type: Dual string w/PDG
Artificial lift: Gas lift
Zone: M2/3 & M7/8
Tubing: 3-1/2’’, 13 Ch
Completion acc: 9 Cr
PDG: Electronic
Sand control: Slotted liner
Brine: 10ppg
Packer setting method: Drop ball & chase
26
SINGLE STRING WELL COMPLETION SCHEMATIC
Well type: Oil producer
Completion type: Single string w/PDG
Artificial lift: Gas lift
Zone: M7/8
Tubing: 3-1/2’’, 13 Ch
Completion acc: 9 Cr
PDG: Electronic
Sand control: Slotted liner
Brine: 10ppg
Packer setting method: Drop ball & chase
27
WELL COMPLETION PLAN
1.
2.
3.
4.
5.
6.
RIH scrapper. Well clean up & displace completion fluid. POOH.
RIH wireline gun. Correlate and fire guns. Kill well and POOH.
Retrieve wear bushing & clean THS. Change TPR & test BOP. Land dummy
hanger.
Run 3-1/2’’ single string completion. Displace packer fluid.
Tubing integrity test & inflow test. Set & test packer.
Install BPV. Nipple down BOP. Install tree. POOH BPV & install TWCV. Test
tree & retrieve TWCV.
WELLHEAD
Christmas tree: Solar Alert Block tree.
Wellhead: Compact wellhead from Solar Alert.
28
BACK-UP SLIDES
29
Gas lift design
Well A01
BEFORE INJECT (NO GAS
LIFT)
OIL RATE
WC (%)
(stb/day)
Well A07
AFTER INJECT (WITH GAS
LIFT)
OIL RATE
WC (%)
(stb/day)
BEFORE INJECT (NO
GAS LIFT)
AFTER INJECT (WITH
GAS LIFT)
WC(%) RATE(stb/day) WC(%) RATE(stb/day)
0
4832.8
0
5086.5
0
3649.8
0
3982.5
20
3618.7
20
4008.8
20
2637.6
20
3113.2
40
2315.3
40
2910.2
40
1543.2
40
2239.9
60
645.5
60
1820.5
60
0
60
1385.2
80
0
80
810.4
80
0
80
810.4
Well A08
BEFORE INJECT
(WITHOUT GAS LIFT)
WC(%) RATE(stb/day)
0
3033.8
20
2249
40
1399.8
60
0
80
0
AFTER INJECT (WITH
GAS LIFT)
WC(%) RATE(stb/day)
0
3307.9
20
2608.4
40
1908.8
60
1209.6
80
558.2
Well A11
BEFORE INJECT
(WITHOUT GAS LIFT)
AFTER INJECT (WITH
GAS LIFT)
WC(%) RATE(stb/day) WC(%) RATE(stb/day)
0
2302.3
0
2601
20
1645.7
20
2037
40
911.3
40
1481.3
60
0
60
933.8
80
0
80
429.730
GUN TYPE & DEPTH
Reservoir
Perforation
interval
M2/3, M7/8 &
M9/14
Gun type
Gun size
Shot density
Phasing
(degree)
wireline
2.825’’
6 spf
45/135
Fluid table
No
Type
Treatment
1
Completion fluid
10 ppg (Drillwater + Nacl + 3% KCL)
2
Packer fluid
10 ppg (Completion fluid + Bioxide +
Oxygen Scavenger + Corrosion
inhibitor)
Reservoir: 8.28 ppg
31
Perforation
Perforation type: Wireline
Correlation: GR/CCL
Gun type: 2.875’’ HSD gun
Charges: Powerjet NOVA
SPF: 6
Phasing: 45/135
OB/UB: PURE Dynamic underbalance
32