3. 3
OUTLINE
1. Thermal Recovery Technology overview in CNPC
2. Case study
3. Preliminary Study on Thermal Recovery for FNE
Field, in Block 6
4. Preliminary Study on Drilling and Oil Production
Engineering for Thermal Recovery in FNE Field
4. 4
Part-1 Thermal Recovery Technology
overview in CNPC
1. Status of Heavy Oil Development in China
2. Thermal Recovery Technology in CNPC
5. 5
1.1 Status of Heavy Oil Development in China
ā¢ UNITAR Definition of Heavy Oil
ā Heavy crude oil has a gas-free viscosity from
100 to 10,000 cp at original reservoir
temperature or a gravity from 200 to 100 API
ā Bitumen (Tar Sand) has a gas-free viscosity
greater than 10,000 cp at original reservoir
temperature or a gravity less than 100 API
6. 6
Noteļ¼The viscosity marked with * is measure under reservoir conditions, and
others are measured at reservoir temperature, dead oil
ā¢ Definition of Heavy Oil
CNPC Classification Criteria of Heavy Oil
1.1 Status of Heavy Oil Development in China
Classification Viscosity Density
ļ¼cpļ¼ 0API@20ā
Conventional
heavy oil
ā 50*(or100~10,000) 17.5<API<22.0
Sub-
class
ā ļ¼1 50* ~ 150*
ā ļ¼2 150*~10,000
Extra-heavy oil ā ” 10,000~50,000 12.9<API<17.5
Super-heavy oil ā ¢ ļ¾50,000 <12.9
7. 7
Y More than 70 oil fields developed in 12 basins
Y 4 Major heavy oil fields: Liaohe, Xinjiang, Shengli, and Henan
Y Recently, deep heavy oil resources ( 2200m-- 5000m) have been
found in Tuha and Tarim oil fields
ā¢
Karamay ā¢
ā¢
Shengli
ā¢
Liaohe
Henan
Tarim
Tuha
1.1 Status of Heavy Oil Development in China
8. 8
Y Heavy oil has played an important role in Chinaās oil industry.
Y Since the first Cyclic Steam Stimulation pilot test succeeded in
1982, the thermal technology has been widely applied in China.
Y From 1995, heavy oil production has been over 250Ć103 BOPD,
accounting for over 10% of the total of CNPC.
0
3 0 0
2 5 0
2 0 0
1 5 0
1 0 0
5 0
1 9 9 2 1 9 9 4 1 9 9 6 1 9 9 8 2 0 0 0 2 0 0 2 2 0 0 4
Daily
oil
rateļ¼MBBLļ¼
1.1 Status of Heavy Oil Development in China
Heavy oil Production in China
9. 9
D Techniques in commercial application
ā¢ Cyclic Steam Stimulation (CSS)
ā¢ Steam flooding
ā¢ Horizontal and multi-lateral wells
ā¢ Hot water flooding
D Techniques in field test
ā¢ Steam Assisted Gravity Drainage (SAGD)
ā¢ Water flooding with N2 and chemical agents
ā¢ Cold heavy oil production with sand (CHOPS)
ā¢ In-situ combustion
1.2 Thermal Recovery Technology in CNPC
10. 10
D Cyclic Steam Stimulation (CSS)
Also known as steam soak, or steam huff and puff
Production mechanisms
ļ¼1ļ¼V
Viscosity reduction
ļ¼2ļ¼Blocking removal
ļ¼3ļ¼Thermal expansion
of liquid and rock
ļ¼4ļ¼Formation
compaction 2000~4000t(CWE)
10~15days
2~7days Several months
1.2 Thermal Recovery Technology in CNPC
11. 11
Steam zone
Hot water zone
Cold oil zone
team Inj
S Soak ection
Oil Production
Process of CSS
1.2 Thermal Recovery Technology in CNPC
D Cyclic Steam Stimulation (CSS)
12. 12
Y Depth
Y Net pay
Y Oil viscosity
Y Net to gross ratio
Y Porosity
Y Permeability
Y Original oil saturation
ā¤1,700 m
ā„5 m
ā¤100,000 cp
ā„0.40
ā„20 %
ā„200 md
ā„50%
D Cyclic Steam Stimulation
Screening Criteria for CSS
1.2 Thermal Recovery Technology in CNPC
13. 13
Main Mechanisms
(
(1
1)
) Viscosity Reduction
(2) Steam Distillation
(3) Thermal Expansion
(4) Steam drive
(5) others
D Steamflooding Process
Steamflooding is based on well patterns. Steam is
injected from injectors and oil is produced from
producers continuously. The steam functions are to heat
the reservoir and to provide the reservoir energy for
viscosity reduction and oil enhancement.
Production
Fluid
1.2 Thermal Recovery Technology in CNPC
14. 14
Steam zone
Hot water Cold oil
The process of Steam Flooding
Injector Producer
Producer
1.2 Thermal Recovery Technology in CNPC
D Steam flooding Process
15. 15
D Steam flooding Process
Contribution of Steam flooding Mechanisms to Oil Recovery
1.2 Thermal Recovery Technology in CNPC
16. 16
1.2 Thermal Recovery Technology in CNPC
D Steam flooding Process
Screening Criteria for Steam flooding
Item parameter
Depth, m <1,400
Net Pay, m 7ļ½60
Net to gross Ratio > 0.5
Permeability, md > 200
Porosity, ļ¼ > 20
Oil saturation ļ¼ > 45
Viscosity, cp <10,000
Pressure, psi <725
17. 17
D Steam flooding Process
CSS vs Steam Flooding
ā¢ Advantages
ā Immediate Production Response
ā Quick Payout
ā Relatively Inexpensive
ā Fewer Facilities
ā¢ Disadvantage
ā Lower Recovery factor (15~25% vs 50~60%)
1.2 Thermal Recovery Technology in CNPC
18. 18
D The technique package applied in steam injection
1. Geological study and reservoir description
2. Reservoir engineering study and Injection/production
parameter optimization
3. High-efficiency steam injection
4. Separate layer injection/production in multi-layer
reservoirs
5. Artificial lifting (high temp., heating, chemicals)
6. Sand control under high temperatures ( up to 350ā)
7. Performance monitoring and testing
1.2 Thermal Recovery Technology in CNPC
19. 19
1.2 Thermal Recovery Technology in CNPC
D The technique package applied in steam injection
1) Geological study and
reservoir description
Top of structure
20. 20
Layer
1
Layer
3
Layer
5
Layer 7 Layer 9 Layer 11
Temperature distribution for Steam flooding
D The technique package applied in steam injection
2) Reservoir engineering study and Injection/production parameter
optimization
1.2 Thermal Recovery Technology in CNPC
21. (xs=50%) (xs=70%) (xs=80%)
steam chamber development in a horizontal well
21
1.2 Thermal Recovery Technology in CNPC
D The technique package applied in steam injection
2) Reservoir engineering study and Injection /production parameter
optimization
22. 22
Funnel heat loss
Steam
D The technique package applied in steam injection
3) High-efficiency steam injection technology
Steam generator
1.2 Thermal Recovery Technology in CNPC
Surface heat loss
Fuel burning
Y The steam generator is
automatically controlled.
Y The fuel can be saved 18%
and thermal efficiency
increased by 3-4%
23. We have got new insulating
materials as the jacket of the
surface pipelines for steam
injection to reduce heat loss.
The field tests showed that the
new insulating material can
reduce heat loss by 8% for
1000m of pipeline, and increase
wellhead steam quality by 14%
23.
D The technique package applied in steam injection
3) High-efficiency steam injection technology
1.2 Thermal Recovery Technology in CNPC
24. 24
D The technique package applied in steam injection
3) High-efficiency steam injection technology
Equal Steam Quality Allocation System
1.2 Thermal Recovery Technology in CNPC
25. 25
D The technique package applied in steam injection
3) High-efficiency steam injection technology
--Thermal wellhead for
steam injection
Used in steam injectors,
capable of realizing
non-killing operation.
Technical specifications:
rated work pressureļ¼3045psi
failure pressureļ¼ 6090psi
work temperatureļ¼ ā¤350 ā
nominated driftļ¼ Ī¦80mm
connection modeļ¼ flange
1.2 Thermal Recovery Technology in CNPC
26. 26
Thermal conductivity of the vacuum insulating
tubing is only 0.007 W/m. ā. It can reduce heat
loss in wellbore and maintain higher steam
quality downhole.
Formation
Vacuum
insulating tubing
Expansion
joint
Thermal
packer
Vacuum
insulating tubing
Heat insulating technology in wellbore
K331 heat-sensitive
metal expandable
packer
Vacuum heat insulating
tubing
1.2 Thermal Recovery Technology in CNPC
D The technique package applied in steam injection
3) High-efficiency steam injection technology
27. 27
Formation 1
Bull plug
D The technique package applied in steam injection
4) Separate Steam injection for a multi-zone reservoir
Insulated tubing
Extension joint
Thermal packer
Formation 2
Formation 1
Formation 2
1.2 Thermal Recovery Technology in CNPC
28. Pottery
pu
28
mp
D The technique package applied in steam injection
5) Lift techniques with Hi-temp.,
corrosion-resistant pump
Annular type pumpļ¼ā¤140ā
Metalic pump ļ¼140ļ½180ā
pottery pump ļ¼ ā„180ā
Suitable for different stages of
thermal recovery with longer
service life
1.2 Thermal Recovery Technology in CNPC
Annular type
pnmp
Metaiic
pump
29. 29
D The technique package applied in steam injection
6) Series of sand control
v"Inside gravel pack
v"Downhole filters
v"High temp. precoated sand
v"Combined sand control
1.2 Thermal Recovery Technology in CNPC
30. D The technique package applied in steam injection
7) On line testing technique for steam
injection
ā¢Steam injection profile testing
ā¢ Downhole steam sampling
ā¢High-temp. soaking pressure-drop
testing
ā¢High-temp. fluid production profile
testing
ā¢ High temp. long-term testing
ā¢Capillary separate layer pressure
testing
ā¢ Gas tracer monitoring
30
1.2 Thermal Recovery Technology in CNPC
31. D Thermal recovery technology mainly includes cyclic steam
stimulation, steam flooding, hot water flooding, Steam Assisted
Gravity Drainage (SAGD) and in-situ combustion.
D The technique package applied in steaming process are
composed of high efficiency steam injection, Hi-temp. artificial
lifting, Hi-temp. online testing, and Hi-temp. sand control, etc.
D Thermal recovery technology has been commercially applied in
different heavy oil reservoirs, and has become the
predominated one for heavy oil production in China.
31
Summary
1.2 Thermal Recovery Technology in CNPC
32. 32
OUTLINE
1. Thermal Recovery Technology overview in CNPC
2. Case study
3. Preliminary Study on Thermal Recovery for FNE
Field, in Block 6
4. Preliminary Study on Drilling and Oil Production
Engineering for Thermal Recovery in FNE Field
33. 33
2.1 Cases for CSS
D Block Gao3
D Block Du66
Thick massive reservoir , China
laminated reservoir , China
2. Cases for CSS + Steam Flooding
D Block Qi40, Liaohe Oilfield, China
D Block 9, Kalamay oilfiled, China
3. Cases for Steam Flooding
D K e r n River, U.S.A
D Duri Oilfield, Indonesia
Part-2 Case Study
34. ā¢ Original pressure: 2320 psi
ā¢ Original temprature: 53.5 ā
ā¢ Oil viscosity@ reservoir conditionļ¼518 cp
34
D Case 1: Block Gao3 , Liaohe Oilfield
ā¢ Thick massive reservoir with gas cap and bottom water
ā¢ Depthļ¼1500ļ¼1650m
2.1 Cases For Cyclic Steam Stimulation
ā¢ Net payļ¼68.9m
ā¢ Porosityļ¼24.0ļ¼
ā¢ Permeabilityļ¼2364 md
ā¢ GOR: 131 scf/b
Crosse Section of Gao3
35. 35
2.1 Cases For Cyclic Steam Stimulation
ā¢ Primary development: 1977 ~ 1982
ā¢ Primary & CSS : 1983 ~ 1985
ā¢ CSS : 1986 ~ Now
ā¢ Well Spacing: 210m, infilled to 150m 105m
This reservoir is the first thermal producing area in China.
It started with cyclic steam injection in 1982.
Development Results
D Case 1: Block Gao3 , Liaohe Oilfield
ā¢ RF of Primary development: 4.5%
ā¢ RF of CSS: 18.3%
ā¢ Total RF (Primary + CSS): 22.8%
ā¢ OSR of CSS: 0. 91
36. 5.0
0.0
1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000
36
Time (Year)
2.1 Cases For Cyclic Steam Stimulation
19.3
21.1 21.0
15.0
15.9
11.8
11.1
10.1 9.7 9.6
9.0 9.2
8.5 8.8
7.7
10.0
15.0
20.0
25.0
Daily
oil
rate
(MBOPD)
D Case 1: Block Gao3 , Liaohe Oilfield
Production history of Gao 3
37. 37
D Case 1: Block Gao3 , Liaohe Oilfield
Cyclic oil production vs cycles
0.0
5000.0
10000.0
15000.0
20000.0
25000.0
1 2 3 4 5 6 7 8
Cycle
Cycle
Oil
product
ion
ļ¼BBlļ¼
2.1 Cases For Cyclic Steam Stimulation
38. 38
2.1 Cases For Cyclic Steam Stimulation
1.60
Oil/steam ratio(OSR) vs cycles
1.40
1.20
1.00
0.80
0.60
0.40
0.20
8
Cycles
0.00
0 2 4 6 10
OSR
D Case 1: Block Gao3 , Liaohe Oilfield
ā OSR = Oil Produced/ Steam Injected , That means how many bbls of
oil can be produced by 1bbl of steam injected
39. 39
ā¢ Reservoir depth 875-1150 m
ā¢ Original reservoir pressure 9.4MPa
ā¢ Original reservoir temperature 51.2 ā
ā¢ Net pay 26.4 m
ā¢ Net to gross ratio 0.442
ā¢ Porosity 26.9ļ¼
ā¢ Permeability 882 md
ā¢ Original oil saturation 68ļ¼
ā¢ Dead oil viscosity @reservoir T 2000 cp
ā¢ Oil density 17.4 API
D Case 2: Block Du66 , Liaohe Oilfield
2.1 Cases For Cyclic Steam Stimulation
40. 13 40
1 2 3 4 5 6 7 8 9 10 11 12
Cycles
Cyclic
oil
pr
od.(B)
14000
12000
10000
8000
6000
4000
2000
0
16000
D Case 2: Block Du66 , Liaohe Oilfield
Cyclic oil production vs cycles
2.1 Cases For Cyclic Steam Stimulation
41. 6 7 8
Soak time: 3~10d 41
Cycle time vs cycles
400
300
200
100
0
500
0 1 2
Cycle time: 220~390d
3 4 5
Cycles
Cycle
time
(days)
Injection time: 10~15d
2.1 Cases For Cyclic Steam Stimulation
D Case 2: Block Du66 , Liaohe Oilfield
42. 42
OSR
10
Cycle
D Case 2: Block Du66 , Liaohe Oilfield
Oil/steam ratio(OSR) vs cycles
1.40
1.20
1.00
0.80
0.60
0.40
0.20
0.00
0 2 4 6 8 12 14
2.1 Cases For Cyclic Steam Stimulation
43. 43
2.1 Cases For Cyclic Steam Stimulation
ā¢ CSS : 1986 ~ Now ( not finished yet )
ā¢ Well Spacing: 200m, infilled to 140m 100
m
ā¢ RF of CSS
ā¢ OSR of CSS
20.1
%
0.68
D Case 2: Block Du66 , Liaohe Oilfield
CSS Development Results
44. 44
Block 6 Block 9
Karamay
Steam flood is
Successful in Block 9
D Case 1: Block 9, Karamay oilfield (Shallow Reservoir)
2.2 Cases For CSS+SF
45. D Case 1: Block 9, Karamay oilfield (Shallow Reservoir)
Reservoir Parameters of Qigu Formation in Block 9
2.2 Cases For CSS+SF
Reservoir Depth, m 240
Net pay m 13.9
Porosity, Fraction 0.30
Permeability, md 2630
Oil Density, API 17.5
Dead Oil Viscosity , cp 3000~10000
Reservoir Pressure, psi 360
Reservoir Temperature, ā 19
45
46. 46
D Case 1: Block 9, Karamay oilfield (Shallow Reservoir)
Production history
1984 ~ 1991ļ¼CSS periodļ¼recovery factor 18% ~ 25%.
1991 ~ 1996ļ¼Steam flood period at initial well pattern, well spacing
100Ć140m. recovery factor 3.6%
1996 ~ 1998ļ¼Infilled drilling wells
1998~Nowļ¼ Steam flood period with well spacing of 70Ć100m
2.2 Cases For CSS+SF
47. 47
D Case 1: Block 9, Karamay oilfield (Shallow Reservoir)
Steam flooding results in Block 9
2.2 Cases For CSS+SF
Block Cum Oil
production
ļ¼MMBļ¼
RF of CSS
ļ¼%ļ¼
Cum-OSR RF of
Steamflood
ļ¼%ļ¼
Cum-recovery
ļ¼%ļ¼
91-1 2.77 21.39 0.27 24.59 45.98
91-2 4.72 20.64 0.24 19.25 39.86
92 5.79 20.54 0.27 18.32 28.86
93 5.60 12.81 0.15 12.87 25.68
94 8.18 15.66 0.19 13.20 28.86
95 4.47 32.42 0.28 9.02 41.44
96 4.59 24.19 0.13 4.96 29.15
Average 19.69 14.4 34.09
48. 48
D Case 1: Block 9, Karamay oilfield (Shallow Reservoir)
ā¢ From Aug.1991 to Dec.2005, more than 600 well
groups converted to steam flooding, oil production
reached to 20Ć103 bopd
ā¢ Steam flooding has got commercial application in
shallow heavy oil reservoirs in China.
2.2 Cases For CSS+SF
49. 49
D Case 2: Block Qi40 , Liaohe Oilfield
ā¢ Middle to thick multi-layer reservoir
ā¢ D e p t hļ¼625~1050m (850m)
ā¢ Net pay ļ¼37.7m
ā¢ Net to gross ratioļ¼0.58
ā¢ Porosityļ¼30.0ļ¼
ā¢ Permeabilityļ¼2060 md
ā¢ Original oil saturation: 70%
ā¢ Dead oil viscosity(@50ā)ļ¼3127 cp
2.2 Cases For CSS+SF
W-E cross section
50. 50
2 . 6
1 1 . 5
1 0 . 5
7 . 8
1 6 . 4
8 . 0
1 3 . 5
1 2 . 2
1 2 . 3
1 5 . 0
1 4 . 8
1 4 . 7
1 5 . 6
1 2 . 8
1 6 . 8
1 3 . 3
1 0 . 2
1 1 . 3
0.0
2.0
4.0
8.0
6.0
10.0
12.0
14.0
20.0
18.0
16.0
1 9 8 7 1 9 8 9 1 9 9 1 1 9 9 3 1 9 9 5 1 9 9 7 1 9 9 9
T im e (year)
2 0 0 1 2 0 0 3
Daily
oil
rate
(MBBL)
D Case 2: Block Qi40 , Liaohe Oilfield
Production history of CSS in Qi40
2.2 Cases For CSS+SF
Y CSS started in 1987: well spacing 200m
Y Infilled in 1990: well spacing 141m
Y Infilled again in 1994: well spacing 100m
51. 51
D Case 2: Block Qi40 , Liaohe Oilfield
Oil production vs cycles
Y The oil rate per well was only 57bbl/d with conventional cold
recovery
Y For CSS, the average oil rate increased to 189bbl/d, and the cyclic
production could be as high as 35,450 bbl in early cycles.
40000 200
0
5000
10000
15000
20000
25000
30000
35000
1 2 3 4 5 Cycle6
0
40
80
120
160
C yclic production
O il rate
2.2 Cases For CSS+SF
52. Soak time: 3~10d
52
D Case 2: Block Qi40 , Liaohe Oilfield
Cycle time vs cycles
0
100
200
300
400
1 2 3 4
Cycle time: 180~360d
5 6 7 8 9
Injection time: 10~15d
10 1
1 12
C
ycles
C
y
c
l
e
ti
m
e
(d
a
y
s
)
2.2 Cases For CSS+SF
53. 53
2.2 Cases For CSS+SF
D Case 2: Block Qi40 , Liaohe Oilfield
Oil/steam ratio(OSR) vs cycles
1.87
1.56
1.50
1.18
0.88
0.55
0.50
0.00
2.50
2.06
1.00
2.00
1 2 3 4 5 6
Cycle
OS
R
54. 54
D Case 2: Block Qi40 , Liaohe Oilfield
Steam flooding Pilot Test in Block Qi40
D 4 Well patterns for Steam flooding
ā Inverted 9-spot well pattern with well
space of 70m
ā Total wells: 27
D Before steam floodingļ¼
ā CSS started in 1987
ā OSR (oil steam ratio): 1.1
ā Oil Recovery Factor of CSS: 24.0%
ā Oil Saturation before SF: 0.53
2.2 Cases For CSS+SF
ā¢ Injectors: 4
ā¢ Producers: 21
ā¢ Observation wells: 2
55. 2005 2006
55
10
100
1000
Steam
Breakthrough
Preheat Steam Drive Steam
Breakthrough
1997 1998 1999 2000 2001 2002 2003 2004
Oil
Rate,bbl/d
68
6800
Liquid Rate
Flooding
Oil Rate
D Case 2: Block Qi40 , Liaohe Oilfield
Production performance curve of pilot area in Qi40
2.2 Cases For CSS+SF
56. 56
D Case 2: Block Qi40 , Liaohe Oilfield
Steam flooding Pilot Test Results
Steam Flooding 1998.1ā2006.12
ā Cum. Oil Productionļ¼1.5 MMB
ā Cum. Liquid Productionļ¼7.16 MMB
ā Cum. Steam injectionļ¼8.62 MMB
ā Cum. OSRļ¼0.18
ā Recovery Factor (SF)ļ¼28.0%
ā Total Recovery Factor (CSS + SF)ļ¼52.0%
2.2 Cases For CSS+SF
57. 57
2.2 Cases For CSS+SF
D Case 2: Block Qi40 , Liaohe Oilfield
Development
results
ā¢ RF of CSS 28.5%
ā¢ Total RF of pilot test (CSS+SF) 52.0%
ā¢ Predicted RF of SF 24.7%
ā¢ Total RF predicted (CSS+SF) 53.2%
ā¢ OSR of CSS: 0.68
58. 58
Main parameters of Kern River
Case1ļ¼Kern River, U.S.A
2.3 Cases For Steamflooding
Reservoir Parameters Average
Depth, m 275
Temperatureļ¼ā 32
Thickness, m 18
porosity, % 31
permeability, md 2,000
Viscocity@32ā, cp 4,500
Oil Saturation before SF , % 45
Pressure before SF, psi 51
Pattern area: 2.5 acre
Producersļ¼ 8340
Injectorsļ¼ 1220
Obser. wellsļ¼ 660
59. 59
0
60,000
40,000
20,000
80,000
100,000
120,000
140,000
160,000
1900 1910 1920 1930 1940 1950 1960 1970 1980 1990 2000
Primary
Exploitation
CSS
SF
SF performance of Kern River
RF of Primary & CSS: 8%
Daily Oil Productionļ¼
Total Recovery Factorļ¼
Final Recovery Factorļ¼
100 MB
>70%(2003)
80ļ¼
2.3 Cases For Steamflooding
D Case1ļ¼Kern River, U.S.A
60. 60
2.3 Cases For Steamflooding
D Case2ļ¼Duri Oilfield, Indonesia
Main parameters of Duri Oilfield
ā¢ Many pilot tests such as
alkali waterflooding, in-situ
combustion, steam
flooding were conducted,
and finally steam flooding
was selected.
ā¢ RF of primary: 8%
Reservoir Parameters Average
Depth, m 150
Temperatureļ¼ā 38
Net pay, m 37
Porosity , % 34
Permeability, md 1,500
Viscosity@38ā, cp 150~500
Oil Saturation before SF, % 60
Pressure before SF, psi 101
61. 61
D Case 2ļ¼Duri Oilfield, Indonesia
OOIPļ¼ 5661 MMBBL
Total Blocks : 13
Steam flooding :10 Blocks
Well Pattern:
Well spacing:
Producersļ¼
Injectorsļ¼
Inverted 7& 9-spot
120~130 m
3400
1600
Observation Wellsļ¼ 300
Oil Rate ļ¼
OSR ļ¼
203.47 MB/d
0.19
Recovery Factorļ¼ 60ļ¼
2.3 Cases For Steamflooding
62. 62
OUTLINE
1. Thermal Recovery Technology overview in CNPC
2. Case study
3. Preliminary Study on Thermal Recovery for FNE
Field, in Block 6
4. Preliminary Study on Drilling and Oil Production
Engineering for Thermal Recovery in FNE Field
63. 63
1. Reservoir Characteristics of FNE
2. Thermal Recovery Tentative Plan for FNE
3. Suggestions for CSS Pilot Test
4. Plan forward for Thermal Recovery
5. Conclusions and recommendation
Part 3 Preliminary Study on Thermal
Recovery for Block FNE
64. 64
3.1 Reservoir Characteristics of FNE
Reservoir parameters of Bentiu Formation
Reservoir Parameters Bentiu
Area 10.12 km2
Depth 502~678 m
Net Pay 30 m
Porosity 32.0 %
Permeability 350~6050(4000) md
Oil Saturation 70 %
Density 15.9~17.9 ĀŗAPI
Pressure 595 psi
Temperature 43.5 ā
Dead oil Viscosity 2160 cp@43.5ā
OOIP 224.80MMB
Note Bottom Water
65. 65
D Compaction: fair to good , indicating point to point , and
concavo-convex contacts
D Sand cementation : poorly consolidated and unconsolidated,
fewer siderite, calcite and iron oxide cements
3.1 Reservoir Characteristics of FNE
66. 66
D Clay composition: kaolinite, chlorite, Illite and
smectite. (total content 15%- 40%)
Clay mineral composition from well Fula NE-2
3.1 Reservoir Characteristics of FNE
Sample
Depth (m)
Clay Minerals %
Kaolinite Smectite Illite Chlorite Illite/
smectite
521.0 89.40 2.20 5.10 2.10 1.20
526.5 15.7 74.9 6.95 2.36 0.00
579.4 90.9 0.00 0.00 4.12 4.92
Average 65.3 25.7 4.02 2.86 2.04
67. 67
30
25
20
15
10
5
0
Grain size,mm
Well FNE-2 sieve analysis (579.4m)
Weight,
%
grain size,mm
Well FNE-2 sieve analysis(579.4m)
100
80
60
40
20
0
10.00 1.00 0.01
0.10
cumulative,
%
50
40
30
20
10
0
Grain size,mm
Well FNE-2 sieve analysis (521m)
weigh,%
100
80
60
40
20
0
0.01
0.1
grain size,mm
1
10
cumulative
weight,%
d50=0.150mm
d50=0.436mm
Well FNE-2 sieve analysis(521m)
D Grain-size analysis: mainly in range of (0.09 mm-1.00mm) and fewer fine
grains (< 0.063mm) .
3.1 Reservoir Characteristics of FNE
68. 68
D Well test data
Well test result of FNE-1
Well test result of FNE-3
3.1 Reservoir Characteristics of FNE
Test
interval
(Bentiu)
m
Test
method
Test
date
(2005)
Daily production Survey
depth
(m)
conclusion
Choke
(mm)
Oil
b/d
wc Sand
cut
Flowing
press.
(psi)
536.0-544.0 PCP+
memory
gauge
04.27-
05.09
PCP/
72rpm
102 2% 0.02% / 540.67 Oil
Test interval
(Bentiu)
m
Test
method
Test
date
(2005)
Daily production Survey
depth
(m)
Test
conc.
Choke
(mm)
Oil
b/d
wc Sand
cut
Flowing
press.
(psi)
541-562m
Net pay of
10.1m
PCP 08.28-
09.04
/ 106 1% 0.01% / / Oil
69. 69
D Well test data
Well test result of FNE-8
3.1 Reservoir Characteristics of FNE
Date &Time Duration
(hr)
PCP
Speed
(rpm)
Tubing
Press
(MPa)
Production Rate Oil
Density
(API)
Sand
Cut
(%)
Water
Cut
(%)
Avg.
Flowing
Pressure
(psia)
Oil
(bbl/d)
Water
(bbl/d)
Mar.06, 2007-
Mar.18, 2007
294.0 160 0.5 351.35 0 15.9 2.0-
1.0
0 416.67
.Mar.29, 2007-
Apr.04, 2007
155.5 200 0.5 388.78 0 15.9 2.6-
1.0
0 386.63
70. 70
3.2 Thermal Recovery Tentative Plan for FNE
D Feasibility of Thermal Recovery on Block FNE
ā The formation and oil properties of FNE are
suitable for CSS and SF process.
Parameter Comparison
Item CSS
Criteria
SF
criteria
FNE
Depth, m ā¤1,700 <1,400 550
Net pay, m ā„5 7ļ½60 20ļ½30
Net Gross Ratio ā„0.4 >0.5 0.6
Permeability, md ā„200 >200 4000
Porosity, ļ¼ ā„20 >20 32
Oil Saturation, ļ¼ ā„50 >45 70
Viscosity, cp < 100,000 <10,000 2160
Pressure, psi <725 595
71. 71
D Feasibility of Thermal Recovery on Block FNE
ā Properties of FNE are similar to those of Block
Qi40
Parameters Comparison
3.2 Thermal Recovery Tentative Plan for FNE
Item Qi40 Kern River Duri FNE
Depth m 850 275 150 550
Net pay m 37.7 18 37 30
Permeability md 2060 2000 1,500 4000
Porosity ļ¼ 30 31 34 32
Oil Saturation ļ¼ 75 45 60 70
Viscosity cp 3,127 4,500 150~500 2,160
Temperature ā 37 32 38 43
Pressure psi 1232 51 101 595
72. 72
D Feasibility of Thermal Recovery on Block FNE
ā Properties of FNE are similar to those of Block Qi40
Results Comparison
3.2 Thermal Recovery Tentative Plan for FNE
Item Qi40 Kern River Duri
Well Pattern Inverted 9-spot 5-spot Inverted
7& 9-spot
Well Spacing m 70ļ“100 70 120~130
Oil Rate bopd 2060 2000 1,500
RF of primary % / 8.0 8.0
RF of CSS % 24.0 /
RF of SF % 31.0 >72.0 52.0
Total RF % 55 80 60
73. 73
3.2 Thermal Recovery Tentative Plan for FNE
D Feasibility of Thermal Recovery on FNE field
ā Low production rate with cold recovery, because of
high oil viscosity , formation damage;
ā¢ Drilling horizontal wells and applying thermal process
ā Water channeling and water coning by vertical
wells, because of bottom water
ā¢ Drilling horizontal wells in the upper part of the zone
74. D Thermal recovery tentative plan for FNE
ā Supposed that 85% of the oil bearing area will be
developed by horizontal wells with 85% of OOIP
ā Well spacing 100m
ā¢ 6 drilling platforms
ā¢ 36 horizontal wells
ā¢ horizontal sections: 500m for 28 wells; 300m for the
other 8 wells
74
3.2 Thermal Recovery Tentative Plan for FNE
75. 75
D Thermal recovery tentative plan for FNE
ā Using CSS process in horizontal wells
Horizontal section
ā¢ Steam Injection
300ļ½500m
6000ļ½10000m3/cycle
ā¢ The oil rate of a horizontal well will be 950ļ½1260b/d
predicted by JOSHI formula
ā Using CSS in vertical wells
ā¢ Perforated interval
ā¢ Steam Injection
ā¢ The oil rate predicted
25m 2000ļ½
3000m3/cycle 350 ļ½
500 b/d
3.2 Thermal Recovery Tentative Plan for FNE
76. 76
3.2 Thermal Recovery Tentative Plan for FNE
0
5000
10000
15000
D Thermal recovery tentative plan for FNE
The Production Profile for Thermal Recovery
25000
CSS SF
20000
1 2 3 4 5 6 7 8 9 10 11 12 13
Time,Year
D CSS: 4 years with RF of 10.8% , Oil Rate: 9000~18000b/d
D SF: 10 years with RF of 33.3% , Oil Rate: 8700~21000b/d
D Total RF: 44.1%
14
Oil
Rate,bbl/d
77. 77
3.2 Thermal Recovery Tentative Plan for FNE
Economic Evaluation on Thermal Recovery by
Horizontal Wells
Basic Parameters for Economic Evaluation
item value
Oil Price US$ 25.0/bbl or US$ 38.0/bbl
Discount Rate 12%
Transportation Cost US$ 4.0/bbl
Operation Cost US$ 4.0 /bbl
Drilling Cost Vertical Wellļ¼ US$ 780 M /well
Horizontal Well: US$2.00 MM/well
Surface Facility Cost US$ 780 M/well
Boiler Cost US$ 2.00 MM
Insulation Tubing Cost US$ 100 M /well
Steam Cost US$ 15/m3
78. Economic evaluation result
3.2 Thermal Recovery Tentative Plan for FNE
Item Oil priceļ¼
US$ 25.0/bbl
Oil priceļ¼
US$ 38.0/bbl
Total Investment MM$ 176 176
Total cost MM$ 1194 1194
Payback period Year 2.6 1.0
Cum. cash flow MM$ 49.2 138
NPV MM$ 21.8 67.6
IRR ļ¼ 19.2 39.7
Operation cost $/b 14.2 14.2 78
79. 79
3.3 Suggestion for CSS Pilot Test
D Objectives of CSS Pilot Test
ā Extended study on reservoir, confirming feasibility
of thermal recovery
ā Checking adaptability of injection and production
techniques and improving them
ā Providing preliminary results for optimization of
steam injection design
80. 80
D 2 wells recommended for CSS pilot test
ā Drilling a new vertical well, using thermal completion.
ā Drilling a new horizontal well, completed by using sand
control screen.
D Make a comparison of adaptability , productivity
between the horizontal well and vertical well in CSS
to provide basis for the whole block development by
thermal process.
3.3 Suggestion for CSS Pilot Test
81. 81
D Selecting proper well
locations for CSS test
ā A new vertical & a
horizontal well will be
drilled near well FNE-8
to conduct CSS.
3.3 Suggestion for CSS Pilot Test
82. 82
Log Interpretation Result of FNE-8
FNE-8ļ¼Net Pay of 51.8mļ¼Net Gross Ratioļ¼0.73ļ¼
7.0m of Claystone between pay zone and water zone.
3.3 Suggestion for CSS Pilot Test
BOTTO THICK GRO
M NESS SS NET VCL
m m m m %
473.5 2.5 2.5 2.5
15
519.5 4.5 4.5 4.5 10
563.5 42.0 42.0 42.0 5
566.5 1.5 1.5 1.5 12
585.5 18.1 18.1 3.8 13
609.5 17.0 3.6 0.0 10
625.0 10.1 9.1 0.0 15
629.9 4.1 4.1 0.0 35
635.5 4.5 3.5 0.0 25
648 7.6 6.8 0.0 10
656.5 4.7 3.7 0.0 30
672.3 5.1 4.6 0.0 40
Formati
on
Aradeib
NO. TOP POR Sw Result
m % %
a 17 471.0 27 50 oil
Bentiu 18 515.0 32 35 oil
19 521.5 34 20 oil
20 565.0 33 25 oil
21 567.4 33 55 oil
22 592.5 30 75 water
23 614.9 30 80 water
24 625.8 23 100 water
25 631 25 90 water
26 640.4 33 100 water
27 651.8 25 100 water
28 667.2 23 100 water
83. 83
D Requirement for CSS Pilot Test
ā Using thermal recovery completion, TOC to the
ground
ā Vacuum heat insulated tubing is used for steam
injection both in vertical and horizontal wells
ā Steam amount Injected to the vertical well 2000ļ½
3000m3/cycle
ā Steam Injection for the horizontal well 6000ļ½
10000m3/cycle
ā Using a skid-mounted boiler (23 t/h) ļ¼with outlet
steam quality > 80ļ¼
3.3 Suggestion for CSS Pilot Test
84. 84
D Monitoring Requirement for CSS pilot test
ā Steam injection parameters such as injection rate ,
pressure, temperature and steam quality must be
monitored during the whole CSS.
ā Measuring daily oil rate and water cut
ā Measuring bottom hole pressure periodically. After 3
cycles, if possible, do a pressure build-up test .
3.3 Suggestion for CSS Pilot Test
85. D Field Data Collection
ā Selecting appraisal wells to make zone-by-zone extended
production testļ¼to determine the energy of bottom water
D Lab Experiment
ā Oil displacement efficiency of water at different
temperatures
ā Oil displacement efficiency of steam
ā Thermal properties of formation rocks
D Make a Design for Thermal Recovery
ā Reservoir description
ā Analysis and evaluation on CSS test
ā Reservoir engineering study on Thermal Recovery
ā Steam injection and production engineering research
ā Optimization of Steam injection
85
3.4 Plan forward for Thermal Recovery
86. D FNE field is suitable for CSS and SF
D A good recovery performance can be obtained
ā CSS: 4 years with RF of 10.8%
ā SF: 10 years with RF of 33.3%
ā Oil production: 8700~22000b/d
ā Total RF: 44.1% (not including the primary phase)
D Recommend to conduct CSS tests with vertical
and horizontal wells to identify the productivity
D Make a design for thermal recovery based on CSS
test results
86
3.5 Conclusions and recommendation
87. 87
OUTLINE
1. Thermal Recovery Technology overview in CNPC
2. Case study
3. Preliminary Study on Thermal Recovery for FNE
Field, in Block 6
4. Preliminary Study on Drilling and Oil
Production Engineering for Thermal Recovery
in FNE Field
88. 88
1. Basic strategy of the reservoir development
2. Drilling technology for horizontal wells in
shallow reservoirs
3. PCP lift technology for horizontal wells
4. Sand control technology
5. Conclusions and suggestion
Part-4 Preliminary Study on Drilling and Oil
Production Engineering for Thermal Recovery
89. 4.1.1 Difficulties and solutions in drilling and production
engineering
Y Low production rate with cold recovery ,because of high oil
viscosity , formation damage, and quite lower formation temp.
ā¢ Employing thermal recovery method
ā¢ Employing horizontal wells to enhance production ,to relieve sanding,
and water coning
Y Severe formation damage caused by drilling, because of very low
reservoir pressure, and clay mineral composition
ā¢ Developing a proper drilling fluid system with low density and good
inhibition
ā¢ Designing advanced cement slurry and cementing program
Y Water channeling and water coning in vertical wells, because of
abundant bottom water
ā¢ Drilling horizontal wells in the upper part of the pay zone
89
4.1 Basic strategy of the reservoir development
90. 1.Difficulties and solutions in drilling and production
engineering
YSerious sanding problem due to poorly consolidated , high oil
viscosity and greater pressure drawdown
ā¢Using horizontal wells to reduce the drawdown
ā¢ Steam injection to reduce oil viscosity
ā¢ Optimizing sand control methods for different d50
YSerious wearing problem between rods and tubing and high temp.
problem in PCP for shallow horizontal wells
ā¢Optimal design for centralizer and selecting glass lining tubing to
reduce friction and wearing
ā¢ Developing a new type of centralizer and cardan joint
ā¢ Selecting metal to metal PCP with large volume rate at lower RPM
90
4.1 Basic strategy of the reservoir development
91. 91
4.1.2 Strategy summary
D The shallow reservoir in Block 6 is supposed to be
developed by horizontal wells
D Applying steam injection for higher production rate
D Optimizing PCP and rod/tubing structure to lift
heavy oil with sand and to reduce wearing
D Determining and executing sand control to keep
stable production for long run
4.1 Basic strategy of the reservoir development
92. 4.2.1 Key technologies in drilling
Drilling technology for horizontal wells in shallow layers includes
the following:
Optimum casing program &well profile plan
Hole t
tr
ra
ajje
ec
ct
to
or
ry
y c
co
on
nt
tr
ro
olllliin
ng
g &
&g
ge
eo
o-
-
-s
s
st
t
te
e
ee
e
er
r
ri
i
in
n
ng
g t
te
ec
ch
hn
no
ollo
og
gy
y
Water based, low solid drilling fluid for reservoir protection
Drag and friction reduction technology
Shallow horizontal well completion technology
92
4.2 Drilling technology for horizontal wells in shallow layers
93. Well bore trajectory schem
93 atic
KOP:
Below 120mļ¼170-230mļ¼
Wellbore profile ļ¼
Single-circular arc for build-
up section and angle- holding
to the reservoir top
186
A
B
221
60Āŗ
221
260.
5m
280
540.5m
6
6Āŗ
24Āŗ
2
7.
5
4.2 Drilling technology for horizontal wells in shallow layers
4.2.2 Optimum casing program &well profile plan
94. b. Improved casing program without
intermediate casing by drag-analyzing
and checkout
94
Surf. 273mmĆ150m
Bit 393mmĆ151m
a. Initial casing program with
intermediate casing ,used in the early
3 wells
4.2.2 Optimum casing program &well profile plan
TOP:surface
Prod. 139.7mmĆ927m
Bit 215mmĆ929m
Surf. 339.7mmĆ70m
Bit 445mmĆ71m
Interm. 244.5mmĆ445m,Dev. 60o
Bit 311mm Ć446m Prod. 139.7mm
Bit 215mm
TOC 200m
4.2 Drilling technology for horizontal wells in shallow layers
95. 95
4.2.3 Drilling fluid technology
ā¢ Mud system
Bentonite mud during the 1st spud
Low solid phase polymer drilling fluid system in the 2nd spud
ā¢ Drilling fluid property
4-grade solid control system
Solid content < 13%
Lubricant content >3%
Adding XC to the mud to enhance shearing force with good cutting-
carrying ability for cleaning up the wellbore effectively
Lubricant content & Lower solid content to decrease drag friction
coefficient to less than 0.1,meeting the requirement for drilling.
4.2 Drilling technology for horizontal wells in shallow layers
96. Screen completion
96
Perforating completion for thermal
recovery of heavy oil
4.2.4 Well completion technology
Completion modes
Bit 393.7mmĆSurf.273.1mmĆ150m
Build up rate
8~10o/30m
TOC : surface
Bit 241mmĆProd. 177.8mmĆpoint B
A B
TOC:surface
Bit 393.7mmĆSurf.273.1mmĆ150m
Prod. 177.8mmĆPoint A
Build up rate 8~10o/30m
Screen hanger 177.8mm
Screen 177.8mm from A to B
Bit 241.3mmĆB
Horizon. Sec. 200-300m
4.2 Drilling technology for horizontal wells in shallow layers
97. 97
Low-filtrate micro-expanding slurry performance
ļ¼1ļ¼Filtrateļ¼ļ¼ 50ml (30min,@7MPa, 51ā)
ļ¼2ļ¼Good fluidity ļ¼ļ¼ 220mmļ¼
ļ¼3ļ¼Micro-expansion rateļ¼ 0.02% (24h,@51ā,0.1MPa)
ļ¼4ļ¼Compressive strength ( required for fracturing )ļ¼ļ¼14MPa
(24h,@51ā, 0.1MPa)
4.2.4 well completion technology----- cementing
Slurry structure optimizing
Head slurry ( for vertical and build-up sections) ,
Tail slurry (micro-expansion & low loss for horizontal and higher-
angle sectionsļ¼
Application in the field
ā¢ 54 wells has been successfully operated
ā¢ With a up-to-standard rate of almost 100% (54 wells)
ā¢ High quality rate of 94.4% (51 wells)
4.2 Drilling technology for horizontal wells in shallow layers
98. 98
4.2.5 Typical, shallow horizontal wells
Stepped horizontal well developing two thin oil
layers āā well FP10
A stepped horizontal well developing two thin oil layers
Pay zone 1
VD 435m
Pay zone 2
VD 438m
Wellbore configuration schematic of well FP10
4.2 Drilling technology for horizontal wells in shallow layers
99. 99
-100
0
100
200
300
400
Well FP 12 an
50
d
0
429.97
a(30)
436.37
b(30)
460.37
fc(
13
20)
9
ew 21.6m.
fp13
a(30)
b(30)
c(30)
fp12new
z14-054
z14-54
a(30)
b(30)
c(30)
d(30)
fp13
FP 13 well profile schematic
Vertical projection
Horizon.
projection
4.2.5 Typical,shallow horizontal wells
Shallow triaxial extended reach well
Cluster drilling
on the same
platform, for
respectively
developing quite
a lot of layers.
The minimal
distance is less
than 15m with
the max.
displacement of
4.2 Drilling technology for horizontal wells in shallow layers
Well No. TMD m Max. TVD
m
KOP m Max Dev.ang.
deg.
Horiz.disp.
m
Horiz.Sect.
m
Disp./ TVD
FP12 1242 460.22 190 95.54 921.6 673 2.00
FP13 1142.73 420.5 210 89.3 865.81 615.59 2.06
100. 100
6. Application summary
ā¢ 54 horizontal wells in shallow layers successfully drilled
and completed in a similar oil field in China from 2004 to
2006
ā¢ VD 388.8-476.8m and MD 766-1245m
ā¢ Maximal horizontal displacement 921.6mļ¼well FP12ļ¼
ā¢ Maximal horizontal section 673mļ¼well FP 12 ļ¼
ā¢ Water-base drilling fluid employed
ā¢ Common drilling rigs used (ZJ15ćtruck-mounted 20ļ¼
ā¢ Average drilling cycle of 9.2dļ¼and well cycle of 13.06d
ā¢ Up-to-standard rate of Wellbore quality close to 100%
ā¢ Horizontal well production rate 3-5 times of that in adjacent
vertical wells.
4.2 Drilling technology for horizontal wells in shallow layers
101. 101
PCP Application Range
* Requires Special Analysis
Typical Range Maximum*
Operating Depth
1,000ā ā 5,000ā TVD
330 ā 1,550 m TVD
9,800ā TVD
3,000 m TVD
Operating Volume
5 ā 2,500 BPD
1 ā 400 m3/day
5,000 BPD
800 m3/day
WeOh
pe
a
ra
v
tie
ng got rod pump75
aā
n
1
d
70P
Ā°C
F P
Temperature 24 ā 77 Ā°C
752 Ā°F
400Ā°C
hi
W
g
eh
llbo
s
re
aD
n
ed
viat
c
io
u
nt and high N
p
/A
rod.
Dogleg Severity less
than 15Ā°/100 feet
15Ā°/30m
Colri
rf
ot
sio
h
ne
H
a
an
v
dy
ling
oil with sand
Ex
!cellent (regarding pump)
Gas Handling Good
Solids Handling Excellent
Fluid Gravity
Below 45 Ā°API (highly dependable on aromatics
content)
Servicing and Repair Requires Workover or Pulling Rig
Prime Mover Type Electric Motor or Internal Combustion Engine
Offshore Application Good
System Efficiency 50% to 75% (up to 90%)
4.3 PCP lift technology for horizontal wells
for lifting heavy oil. Because of
Rate, PCP is the best choice to
102. 102
4.3 PCP lift technology for horizontal wells
Challenges and solutions in PCP applied for thermal
recovery in FNE field
Y High temperature in thermal process
PCM has developed a revolutionary all-metal pump to
withstand a temp. as high as 400ā( 7500F) ,which has
been successfully used in CSS and SAGD processes.
Y High wearing rate problem in horizontal wells
ā¢ Design optimization for pump type, rpm, the
centralizer quantity and space out by a computer
program.
ā¢ Employing new type of centralizer and cardon
joint.
ā¢ Selecting a kind of glass-lining tubing.
103. 103
Conventional centralizer
with vertical slots
Rotation centralizer
with vertical slots
Disadvantageļ¼
Suffering a unilateral wearing,
greater flow resistance
new type of centralizer
rib
New rotational type of centralizer
lining
Rotational centralizers
with low friction lining
1ćSelecting a low friction material with a
10-time service life of conventional nylon
centralizer.
2ćWith spiral slots to keep equal gap
between the tubing and centralizer ribs for
4.3 PCP lift technology for horizontal wells
uniform wearing.
104. of rods when
104
Relieving bending stress of rods,
moment resistance and tangent wearing
reducing the bending
rotating in highly deviated sections.
Bending
moment
resistance
4.3 PCP lift technology for horizontal wells
a new type of cardan joint
105. Great difference existed between using and no using centralizers. The
wearing rate without centralizers is as 5 times as that with centralizers.
105
6
5
4
3
2
1
0
0 100 200 300 400 500
35
30
25
20
15
10
5
0
dogleg
centr.
Dev.
Centralizer distribution in well E32-251
Typical well examples (well E32-251)
4.3 PCP lift technology for horizontal wells
50
40
30
20
10
0
0
3
7
6
7
1
1
3
1
4
3
1
7
4
2
1
2
2
5
0
2
8
8
MD,m
W
e
a
r
i
n
g
r
a
t
e
,
%
/
a
with
without
Wearing rate comparison
with/without using centralizers
106. 106
Application scale and result
4.3 PCP lift technology for horizontal wells
Since April, 2004, among the total 564 PCP wells,
the longest production time has been up to more
than 700 days ,and the maximum deviation angle at
pump location is up to 60 deg.
field name FU MT XM YT tota
l
deviated
or
horizont
al
484 39 39 2 564
107. 107
Main sand control methods
Gravel pack Sand filters
4.4 Sand control technology
tubin
cross.
sub
packer
holes
Firing
head
gun
g
Combined perf.
Chemical
Frac & pack
108. 108
Sand filter for steaming horizontal wells
Sand control schematic for steaming horizontal wells
4.4 Sand control technology
Casing Prod. packer Steam packer Metal fiber filter Bull plug
Fish top Perfs. Arti. bottom
109. 109
4.5 Conclusions and suggestion
1. Drilling technologies for shallow horizontal wells are successfully
applied in quite a few oil fields in China
2. PCP technology can be effectively used by selecting high
temperature, large volume rate pump at lower RPM, designing the
optimal parameters, using a new type of centralizer and cardan
joint to control wearing rate
3. It is sure that sanding problems would happen, so sand control
completion should be taken for most oil wells, and downhole filter
should be one of the important candidates for most horizontal
wells
4. In order to fully develop the heavy oil reservoir in Sudan, it is
suggested that all the technologies mentioned above should be
pilot tested first in selected well groups, especially with a couple
of horizontal wells
110. 110
technology will be successfully
applied in heavy oil reservoirs in
Sudan!
Thank you !
We hope that the thermal recovery