SPE DISTINGUISHED LECTURER SERIES is funded principally through a grant of the SPE FOUNDATION

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1 SPE DISTINGUISHED LECTURER SERIES is funded principally through a grant of the SPE FOUNDATION The Society gratefully acknowledges those companies that support the program by allowing their professionals to participate as Lecturers. And special thanks to The American Institute of Mining, Metallurgical, and Petroleum Engineers (AIME) for their contribution to the program.

2 Innovative Integrated Modeling Technology Michael Litvak Reservoir Engineering Advisor, BP

3 Innovative Integrated Modeling Technology Present innovative technology for Static reservoir modelling Model validation with 4-D 4 D seismic Integrated reservoir/facility modelling Field development optimization Demonstrate added business value

4 Main Messages Develop and apply powerful integrated modeling technology Save millions of dollars with the developed technology applications

5 Details in our SPE Publications Static Modeling and Model Validation with 4-D 4 Seismic SPE 90059, SPE Integrated Reservoir and Facility Modeling SPE 56621, SPE 48859, SPE Production Optimization and Uncertainty Estimations OTC 18526, SPE , SPE 90506, SPE 77643, SPE 77658, SPE 93146

6 Major Challenge Very difficult discover large conventional oil/gas reservoirs Improve recovery from existing fields

7 Integrated Modeling Workflow

8 Facies Modeling Technology

9 Facies Modeling Technology Sand/Shale 3-D Volume Derived from Seismic Geostatistical Facies 3-D Model Facies Well Logs

10 Advantages of Facies Modeling Technology Match well log/core data Constrain by sand/shale features derived from seismic Represent shale barriers which are below seismic resolution Consistent with depositional environment

11 Rock Property Modeling Technology

12 Correlations between Seismic Attributes and Rock Properties + >> Seismic Attributes Rock Properties Fluid Properties

13 Calibration of Correlations between Seismic Attributes and Rock Properties Effective Porosity Derived from Seismic and Well Logs Effective Porosity from Seismic Log Effective Porosity Statistically Good Correlation - Large Uncertainties

14 Facies Seismic Well Logs Rock Property Modeling Technology Effective Porosity Seismic- Rock Property

15 Advantages of Rock Property Modeling Technology Robust Static Model => Success in Field Development Optimization Match well data Consistent with seismic and depositional environment

16 Model Validation with 4-D Seismic

17 Model Validation with 4-D Seismic Incorporate fluid flow barriers based on 4-D 4 seismic Match fluid flow movements derived from 4-D D seismic Match measured and synthetic 4-D 4 D seismic

18 History Matching with Fluid Flow Barriers from 4-D Seismic WCT (Ratio) NoTun Tun Obs 0.8 Bottomhole Pressure Match BHP (PSI) NoTun Tun Obs /96 11/96 5/97 11/97 5/98 11/98 5/99 11/99 5/00 11/00 5/ Water Cut Match Fluid barriers from 4-D seismic /96 11/96 5/97 11/97 5/98 11/98 5/99 11/99 5/00 11/00 5/01

19 Matching Fluid Flow Movement from 4-D Seismic Original OWC New OWC Excellent Water Cut Match 0.5 Pre-production Oil-Water Contact (OWC) After Three Years Water Cut (Fraction) Water Cut Trend of Water Cut Time (Days)

20 Integrated Reservoir and Facility Modeling

21 Integration of Reservoir and Facility Models Gas Separators Oil Water Gas-Lift Gas Risers Well Tubing Pipelines Well 383-K2 Well 383-K1 Reservoir Model Oil/Gas Reservoir

22 Integration Objectives Robust Production Predictions from Facility and Reservoir Constraints Evaluations of Facility Modification Impacts on Oil/Gas Recovery Integration of All Full Field Models in Company

23 Examples for Gulf of Mexico (GOM) Oil Fields in USA

24 GOM Example: Added Business Value with Infill Drilling Remaining Oil Drill infill well between best two producers Base on predictions of remaining oil Impacts of fluid flow barriers derived from 4-D D seismic Increase oil reserves by 8%

25 GOM Example: Impacts of Electric Submersible Pump (ESP) on Recovery Oil Rates (STB/D) Oil Production Rate Increase Time (days) BHP (psi) Bottomhole Pressure Decrease Time (days) GOR (SCF/STB) Gas-oil Ratio Increase Time (days) Incremental Oil Recovery: from Well ~1,000 Water Cut (fraction) Water Cut Increase Time (days) 1,000 Mstb,, from Field ~300 Mstb

26 Field Production Optimization

27 Approaches Short Term Field Production Optimization E-Field Production Optimization System in Prudhoe Bay Oil Field (Alaska, USA) Long Term Field Development Planning Field Development Optimization in Giant Oil Field

28 Prudhoe Bay Oil Field Background Largest Oil Field in North America Original Oil In Place ~ 24,000,000 Mstb Production Start in 1977 Peak Oil Production ~ 1,400 Mstb/day Current Production ~ 400 Mstb/day >800 Wells

29 Prudhoe Bay Integrated Reservoir and Facility Model Low Pressure Flowlines High Pressure Flowlines Separator Banks Oil Well Pads Drill Sites Water Gas NGL Lean Gas Central Gas Facility Reservoir Miscible Injectant

30 Automation and Flexibility of Surface Pipeline Network

31 Prudhoe Bay E-Field Production Optimization System User-Friendly system for the optimization of well rates and choke setting well connections to headers and separator banks gas-lift rates Maximizing field oil production matching facility constraints

32 Production Optimization System Elements SCADA Data Acquisition and Historian System Data Preparation Procedure SETCIM User-Friendly Interface Simulation Display Control Results Integrated Model Running in Background Model TUNING OPTIMIZER

33 Automatic Tuning Procedure Compare simulation results with field measurements of pressure and rates Adjust model parameters Identify problems in simulation models and/or field measurements

34 Well Connection Optimization

35 Long Term Field Development Optimization Optimize drilling/infill-drilling program water/gas injection strategy facility modification program Maximizing some economic indicator Matching field development constraints

36 Field Development Optimization Procedure Multiple Reservoir Models Optimum Field Development Plan Yes No Converge? Field Development Rules Potential Field Development Options Determine Economic Indicator/Recoverable Reserves Optimizer Select Field Development Option Check Constraints Update and Run Prediction Reservoir Models

37 Field Development Optimization in Giant Oil Field Optimise: locations of 23 new wells drilling schedule water injection strategy number of water injectors, their locations and drilling schedule water injection rates locations and drilling schedule of sidetrack wells Maximizing Net Present Value

38 Field Development Optimization Benefits 37% Increase in NPV Optimum Case Base Case Generation NPV Changes in Optimization Procedure

39 Field Development Optimization Benefits 12% Additional Oil Recovery 5% Reduction in Water Injection 18.00% 15 Relative Incremental Oil Recovery (%) 16.00% 14.00% 12.00% 10.00% 8.00% 6.00% 4.00% 2.00% Incremental Water Injection (%) % Days Time (Days)

40 Proposals for Water Injection Base Case Optimization Optimum Case SouthWest Later Water Injection in Five Injectors SouthWest Early Water Injection in Five Injectors SouthEast SouthEast SouthCenter SouthCenter NorthWest NorthWest NorthEast NorthCenter NorthEast NorthCenter Move Two Water Injectors from South to North Drilling Time (Days from Start) Drilling Time (Days from Start)

41 Summary Develop Develop and apply innovative technology for Static reservoir modelling Model validation with 4-D 4 D seismic Integrated reservoir/facility modelling Field development optimization Add Add significant business value with the technology applications