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Real Time Production and Reservoir Management – Petrobras Vision
Manoel Feliciano - PetrobrasSthener Campos - Petrobras
Company Overview
Production
Distribuition
Refining & Petrochemical
Gas
ExplorationDrilling
Products
Energy
Transportation
Company Overview
Proved Reserves 10.5 billion boe (SPE)Oil & gas Production:
1.535 million boe/d1.6 billion scf/d
14 Refineries Processing Capacity:
1.8 million bpdPipelines: 14,267 km
Active Wells9,842 (852 offshore)
Production Platforms96 (74 fixed; 22 floating)
Fertilizers 2 PlantsAmmonia: 1,738 metric tons
Urea: 1,927 metric tons
Over 7.000 service stations(33% brazilian marketshare)
2002 DATA
Petrobras Employees
43.000RevenuesUS$ 22.6 billion
R&D Investiment US$ 197 million /year
Research & Development Center
Facilities• Total Area: 122,000 m2
• Constructed Area: 45,000 m2
• 137 Laboratories• 30 Pilot Units
Anual Production Capacity• 180 R&D projects• 20 Basic Egineering Projects • Over 1,800 Technical Support
2003
Expansion
S&T Afiliates: 13Universities and ResearchInstitutes agreements: 226
S&T Afiliates: 25Multiclient Projects: 52
Real Time Production and Reservoir Management
Figura de um campo offshore
FLOW & ARTIFICIAL LIFT
TECHNOLOGY
SUBSEA TECHNOLOGY
WELL TECHNOLOGY
- Subsea equipments-Data Transmission / actuators-Integration Reservoir-production
System Integration /Optimization / Production diagnostics
-Multiphase measurement
-Artificial Lift Automation -Integration Reservoir-production
- Intelligent Well Completion- Integration Reservoir-production
+
__________________
Real Time Field Management
RESERVOIR
TECHNOLOGY
- Reservoir Modeling - Integration Reservoir-production
+
+
- Loss of Setorial Identity
BASE OF VALUES
- Communication / Integrated Work
- Represented Decision
Associated Technologies on Intelligent Fields
Artificial Lift Automation Systems.Intelligent Well Completion.Real Time Reservoir Management.Downhole and Subsea Monitoring Systems.Decision-Making Support Systems.Processing and Integration Data Systems. Economic and Risk Analysis.
Heavy oil exploitationMature oil field managementWater injection managementMaintenance of economic production rate per wellApplication on new field developmentOperational excellence
Strategic Targets for Petrobras
Field Production Optimization
Agua
Crudo
Gas
MeasuredDisturbances
UnmeasuredDisturbances
Unmeasured Outputs
Measured Outputs
Reservoir Pressure: pres
Reservoir Saturations: So, Sw
Flow Impairment: S, Kr’s
Multiphase Flow: qo, qw, gq
Tubing Head Pressure: pTHP
Tubing Head Temperature: TTHT
Solid Production, Water Analysis
Solvent Injection
Gas Lift
ESP Speed
Water Injection
Heat Injection
Gas Injection
Flow Choke
Zone Control
Drainage Area: A
Manipulated Inputs
Controller
Feed forward path
Feed back path
Reservoir Rock HeterogeneityReservoir Fluid DistributionScheduling
BackpressureAmbient Temperature
Flow RestrictionsInjection Fluid Restriction
Well flowing Pressure: pwf
Zone Multiphase Flow: qo, qw, gq
M. Economides – 2004 ASME Gas lift Workshop
Production Optimization
Artificial Lift Automation
– Concept
Methodology of production in real time basedon identification, modeling and controlling of process variables that compose the severalartificial lift methods. Applied by programmingcontrol algorithms executed on PLCs.
– Challenges
1. Multiphase measurement in real time2. Instrumentation reliability3. Coupling Surface and downhole variables4. Operacional Skepticism
Artificial Lift Management Artificial Lift Management
Case 1 – UN-BSOL
GOR– 1000 m³/m³API – 40º- 45ºStrategy: DP Estimation on surfaceContact: Durval Florê[email protected]
Fully dependent on the ability to measure the production in real timePetrobras has different approaches on assets around Brazil.Solutions are dependent on regional management strategyLow cost - technology domain – operational excellence
Case 2 – UN-RNCE
GOR– 50 m³/m³API – 22º- 30ºProduction measurment: PwfContact: Edson [email protected]
Case 3 – UN-BA
GOR– 50 m³/m³API – 20º- 30ºStrategy: Operational Pattern IdentificationContact: Jose Franscisco [email protected]
Case 4 – UN-BC
GOR– 100 m³/m³API – 15º- 30ºStrategy: Pwf / multiphase meters / DPContact: Galileu [email protected]
Case 1 Case 1 –– UNUN--BSOL BSOL
Case 1 Case 1 –– UNUN--BSOL BSOL
Test InformationsTest Informations
AutomaçãoAutomação applied on applied on artificial artificial LiftLift
PVT - Oil Sitio NovoAPI API –– 25.56 25.56 Gas densityGas density –– 0.68810.6881Water Salinity Water Salinity = 0 = 0 ViscosityViscosity (40 (40 oCoC; ; 10kgf 10kgf //cmcm²²) ) –– 90 90 cP cP
(60 (60 oCoC; ; 10kgf 10kgf //cmcm²²) ) –– 50 50 cPcP
Investigation StrategyInvestigation Strategy
Construction of pilot in multiphase loopInstrument Validation – Loop running with gasTest with loop in bypass configuration – water and gasTest with loop in bypass - Óil + different gas fractionTeste with loop – Óleo + different gas fractionOptimization production simulation
Multiphase Loop TestMultiphase Loop Test
GAS VESSEL
MULTIPHASE LOOP
200 m x 6 “
Oil/EmulsionVesselSEPARATOR
MEASURELIQUIDBSW
DP EstimationUNBSOL
Bypass
ResulResultstsLoop in Bypass - Water + gas
Liquid variation for constant gas injection
0
100
200
300
400
500
600
700
800
900
14:4
7:53
14:5
2:05
14:5
6:26
15:0
0:37
15:0
4:50
15:0
9:02
15:1
3:15
15:1
7:27
15:2
1:39
15:2
5:52
15:3
0:04
15:3
4:15
15:3
8:28
15:4
2:40
15:4
6:52
Time
DP
In H
2O
0
5
10
15
20
25
30
35
40
Flow
rate
m3/
h
PDT-Jus InH2O
DP-Mont InH2O
Hw Gas injection
Q_oil Separator m3/h
Q_ Liq_Sitio m3/h
Fraction (%)
Oil = 1,6 // Water = 98,4 // Gas = 74,45
ResultResultss
Fractions(%)
Oil = 98 // Water = 1,2 // Gas = 90
Loop without Bypass - Oil+ Gas
0
100
200
300
400
500
600
700
Time
DP
- In
H2O
0
5
10
15
20
25
30
35
40
45
50
Flow
rate
m3/
h
PDT-Mont
Q_gasSitio
Q_oil Sitiom3/h
Q_oilSeparatorm3/h
11:47 16:2514:40
Case 2 Case 2 –– UNUN--RNCE RNCE
Hora da Aquisição06:00:0004:00:0002:00:0000:00:0022:00:0020:00:0018:00:0016:00:0014:00:0012:00:0010:00:0008:00:0006:00:00
100
95
90
85
80
75
70
65
60
55
50
45
40
35
30
25
20
15
10
5
0
Tubing head pressure [kgf/cm2]Ambient temperature [oC]Control valve Opening [%]Gas-lift injection rate [Mm3/d]
Casing head pressure [kgf/cm2]Gas-lift injection pressure [kgf/cm2]Bottom hole pressure [kgf/cm2]
Casing pressure set point [kgf/cm2]
PID action
Gas compressor shutdown
Gas compressor start-up
Reactivation algorithm
Case 4 Case 4 –– UNUN--BC BC
Gas Lift process Variable correlation
30
32
34
36
38
40
42
44
46
48
50
2:53:23 PM
3:11:09 PM
3:28:56 PM
3:46:42 PM
4:04:23 PM
4:22:04 PM
4:39:45 PM
4:57:26 PM
5:15:09 PM
5:49:10 PM
Time
Tem
pera
ture
oC
0
500
1000
1500
2000
2500
3000
3500
4000
4500
Gas
Lift
inje
ctio
n ra
te [m
3/h]
Q_oilt_oilQgi
Case 4 Case 4 –– UNUN--BC BC
0
10
20
30
40
50
60
2:53
:23
PM3:
00:2
4 PM
3:07
:26
PM3:
14:2
8 PM
3:21
:29
PM3:
28:3
1 PM
3:35
:34
PM3:
42:3
5 PM
3:49
:33
PM3:
56:3
4 PM
4:03
:33
PM4:
10:3
3 PM
4:17
:32
PM4:
24:3
1 PM
4:31
:30
PM4:
38:2
9 PM
4:45
:29
PM4:
52:2
8 PM
4:59
:28
PM5:
06:2
8 PM
5:13
:28
PM5:
36:4
3 PM
5:43
:44
PM5:
50:4
7 PM
5:57
:47
PM6:
04:4
7 PM
6:11
:48
PM6:
18:4
8 PM
6:25
:47
PM6:
32:4
7 PM
6:39
:47
PM6:
46:4
8 PM
6:53
:48
PM
Time
Flow
rate
[m3/
h]
35,5
36
36,5
37
37,5
38
38,5
39
39,5
40
40,5
41
Tem
pera
ture
[oC
]
Q_oilt_oil
Estabilization Period
based on Temperature
External Disturbance
Low Cost Downhole Measurements
Fiber Optic Technology – Pressure and Temperature– Monophase Flow – Multiple points (up to 12 – same
fiber)– Single cable – Focus on reliability
Intelligent Well
Case 1: Marlin Sul Field in the Campos BasinInjection Well: 8-MLS-67HA-RJSProduction Well : 4-RJS-382Water Depth : 1168 mUmbilical: 6 Km (tied back to P-40 floating productionvassel)Two reservoirs MLS-100 (with gas-oil contact) and MLS-200 (without gas-oil contact) The target : avoid increasing gas production of MLS-100 at production well by injection control in the two differentreservoirs at injection well.
Intelligent Well
Case 2: Roncador Field in the Campos Basin
Injection Well: 8-RO-35D-RJSWater Depth : 1890 mUmbilical: 15,5 Km (tied back to Brazil FPSO) Reservoir intervals: RO-410, RO-420 and RO-430The targets:
- increasing oil recovery fator by selectiveinjection in the three different intervals.- less number of interventions for injectivitytests.
Technological Gaps
Low cost multiphase individual well production measurementsUpdate of unmeasured reservoir variables for modeling validationDownhole measurement reliabilityOperational SkepticismArtificial lift methods with high intervention ratesMaximum distance between well head and production unitMultilateral wells (with selectivity) Horizontal well with sand control (drift restriction) Wet mateable fiber optic connector (x-tree and disconnection tool )
Discussions
How dynamic is a well process ?What is better semi-automatic systems or self-operated systems?Model validation for close loop reservoirTechnology frontiers for intelligent fieldsFlexibility of artificial lift methods due to reservoir management
Conclusions
Advantages– Reservoir Management Enhancement– Production optimization– Increase recovering factor– Reduce reservoir interventions– Reduce number of wells– Eliminate the interventions for data logging
Disadvantages– Cost per well is increased– More complicated wells – More interventions due to equipment– Very few experience with the Technology
Real Time Production and Resevoir Management
End
Thank you very muchThank you very much!!!!!!
Very good reasonVery good reason for for Well Automation DevelopmentWell Automation Development
