Intellectual oilfield SAP UFAM optimization and actualization of operative plans of oilfield activities

Transcription

1 Intellectual oilfield SAP UFAM optimization and actualization of operative plans of oilfield activities Sergey Frolov, SAP April 26, 2018

2 A goal without a plan is just a wish Antoine de Saint-Exupéry 2

3 Horizons of planning for oil and gas fields GOALS HORIZONS OF PLANNING PERIOD DOCUMENT Strategic horizon years (till the FS* targets will be achieved) RC FS FDP* Medium-term horizon 2-5 years FDP Yearly horizon Month horizon Operational level 1 year 1 month 1 day - hours Excel files *) RC - reserve calculation, FS feasibility study of oil recovery factor, FDP - field development plan 3

4 Functional plan AS IS Individually by different departments Initiation by departments Initiation and approval with in department of all types of operational activities with proposed execution day/duration and required well shutdowns Without accounting of interferences and influences of activities on each other Integrated Planner Arrange activities and calculate deferments and production profile Several iterations normally MT approval Monthly Integrated Plan approval by Management Team Drawbacks of AS IS process: Manual daily update As result of new input (unscheduled activities, execution delay, extension, overdue, etc.) 1) Significant man power resources involved in the process 2) A lot of iterations 3) Time consuming process with low value added time 4) Forecast does not account interferences 5) Activities distribution is NOT optimal 4

5 Monthly operational plan on the first day of a month Object Month Well1 PL1 PSS1 WMU MPPS Scheduled deferment Unscheduled deferment 5

6 Monthly operational plan vs. fact on the last day of a month Object Month Well1 PL1 PSS1 WMU MPPS Fact Scheduled deferment Unscheduled deferment 6

7 SAP UFAM Intelligent Oilfield Integrated Operations Center Upstream Integrated Analysis Comprehensive analysis of field development and operations to identify potential well and field optimization options. Upstream Integrated Models Use of integrated model to forecast operations (production, downtime, etc.) given the Integrated Operational Plan. Collaboration Real-time collaboration between specialists in different functional areas. Upstream Integrated Planning Creation of a Integrated Operational Plan for workovers, maintenance and repairs including reservoirs, wells and field gathering system. Rapid Decision Making Efficient management and coordination of work during emergencies. 7

8 SAP UFAM is a result of partnership between SAP and NV-ASUproject (OIS) Investment Costs NPV Hydrocarbon Accounting Plant Maintenance program Asset Failure Statistics Economical model Upstream Field Activity Management Fast Reservoir model Wellbore model Gathering system model Artificial lift performance analysis System recommended activities based on performance analysis Self-learning automated schedule generation based on models 8

9 Management Cycle Identification of workover / repair activities by reservoir, well and pipeline section. Forecasting of equipment failure and deterioration. Analysis of potential and limitations of oilfield infrastructure. Full Engineering Model fast calculations. Accounts for production limitations due to: field gathering system capabilities; interference between wells. Automatic generation of optimal plan considering: system potential, interference between wells and other constraints / limitations; management priorities (production levels or profit). Optimization of costs. Real Time Performance tracking. Tracking of plan deviations and critical events. Critical (unplanned) event response plan. Learning and knowledge accumulation Plan optimization (compares planned results to actuals and adjusts) Improved modeling over the life of the field. 9

10 SAP UFAM INCLUDES 4 BLOCKS Integrated Planning Integrated Modelling Integrated Analysis Pool of Assets-Candidates for Treatment 1 Monitoring

11 Integrated Analysis Comprehensive analysis of field development and operations to identify potential well and field optimization options Analysis of Geology, Technology, Operational Performance, Equipment, Economical Efficiency Recommended pool of field Activities Forecasting of potential production after the activity Bottleneck analysis

12 SAP UFAM INCLUDES 4 BLOCKS Integrated Planning Integrated Schedule of Activities 2 Integrated Modelling Integrated Analysis Pool of Assets-Candidates for Treatment Monitoring

13 Integrated Planning Generation of integrated action schedules for assets with the specified goals, criteria and limitations Automated Generation of Activity schedule Deep learning algorithms to constantly create better plans and schedules based on multiple factors Multiple versions and What-If capability

14 SAP UFAM INCLUDES 4 BLOCKS Integrated Planning Integrated Schedule of Activities 3 Integrated Modelling Planned Production based on Models of: Reservoir / Well/ Infrastructure / Fluid Integrated Analysis Pool of Assets-Candidates for Treatment Monitoring Actual Status of Assets and Activities

15 Integrated Modelling Enables modelling of fluid flow processes for a formation, bottom-hole area, well, gathering system, and injection system Fast formation model for fast automatic re-calculations Economical model based on what-if scenarios All models are seamlessly integrated Mutual impact

16 SAP UFAM INCLUDES 4 BLOCKS Integrated Planning Integrated Schedule of Activities Integrated Modelling Planned Production based on Models of: Reservoir / Well/ Infrastructure / Fluid Integrated Analysis Pool of Assets-Candidates for Treatment 4 Monitoring Actual Status of Assets and Activities

17 Monitoring Monitoring asset events that lead to changes in production Visual graphics of the oil field with actual data Monitoring of all assets under treatment Gathering system performance Team progress against the schedule, display planned and actual performance

18 SAP UFAM EXPERT SYSTEM AND OPERATES WITH OTHER SOURCES OF DATA Production and Operational Systems Hydrocarbon Accounting and Production Monitoring Well Activity Planning & Reporting Well Surveillance Activity Planning & Reporting Field Asset Management (incl. well / downhole equipment) and performance monitoring Energy asset management and monitoring Pipeline asset management and monitoring Well Data Historians Well Logging data Well Construction and Drilling data GIS coordinates of objects (well head, perforation, formation, etc) Formation and fluid data Well data historian SAP UFAM SCADA and real-time data Well performance Artificial lift equipment performance data Pipeline data Gathering system objects data Commercial and technical meters Investment program Systems Budget Limits Accounting systems Financial accounting Controlling Contracts NPV

19 Required data Desired data Additional data based on Well Tests results SAP UFAM applies different models depending on data availibility Data used for analysis Field development history Well Interventions cost Well Test Current production data Cumulated production data Injection data Operating time data Well inclination, HUD Well Intervention history Perforation data DFL, FBHP, Reservoir pressure data Geology Productive layers data Top of the layers Bottom of the layers PVT Downtime data Contours and faults data Well construction Artificial lift data Layer intersection data Inclination Well head coordinated Initial reservoir pressure Geological reserves Recovery factor (for each prod. layer) OWC and GOC levels Reservoir temperature Logging PI Skin-factor Reservoir Pressure Connectivity (interference test) Casing leak Emergencies Logging - lithology Porosity Permeability Saturation Indicator surveys Core analysis Layers connectivity Laboratory analysis Fluid density Relaxation time Shear index Six components analysis Well history Permeability curves Initial reservoir pressure 19

20 Well intervention justification Explanation of the recommended by Integrated Analysis activity Analysis of the well *** / 2Б10 Field «*******», ООО «***********» on Artificial lift: ESP , setting depth 3250 m, Runlife 70%, Probability of failure = 34% Liquid flowrate, m3/day / Oil flowrate, tn/day / BSW, %: ,2 Gross reservoir interval / Perforated, m: 15.1 (terrigenious) 2.2 (performed on ) FBHP / Drawdown, bar, skin-factor: Last Well Intervention: Frac on Last well surveillance: FBU on Well surrounding is represented by 5 wells with average flowrate of 5tn/day (min: 3 tn/day, max: 8 tn/day), typical water cut for the patent is 56,2%. Current oil flowrate is 4 tn/day, that is 70% of well potential (6 tn/day). The 56% water cut level deviate from one 56% calculated on the model by 3%. Geological reserves calculated by volumetric method and related to the well is equal to 356 ths. tn, residual reserves 15,3 ths. tn. Cumulative oil production is ths. tn. Calculated target FBHP above current FBHP. Optimization is switched off in calculation parameters. Target FBHP is equal to current FBHP. Based on the existing data the well is not emergency. The absence of actual logging data risk is During last 3 years of filed development there are no new water breakthrough or they were eliminated by executed RIJ the well water cut is in alignment with model. Productive interval is fully perforated - there are no necessity for addtitional perforation. There are no constraints for Frac execution. Forecast flowrate is 8 tn/day (+2 tn/day) at 60% (+4%) water cut. Frac seems economically viable with NPV (2 875 ths. RUR) > 0 and PI (2,7) > 1 and sustainable within the interval of ±10%. Additional risk (+5000) in case of Frac execution is relative proximity (450m) of water front. Formation treatment is not recommended as soon as there are no critical calmatation of the near wellbore zone and well productivity is within acceptable deviation. There is no necessity for reperforation (the perforation of the productive interval was performed less than 5 years ago). Remaining reserves are 15,3 ths. tn., that is less than threshold for potential review of Sidetrack on the well. Maximum NPV (forecast flowrate and reserves) are expected in case of sidetrack drilling in the direction of the well 237. The analysis of DFL behavior does not show significant degradation of artificial lift performance. The probability of the ESP failure (34%) is less than threshold level of (35%), run life is (28 ths. hours) is less than threshold (30 ths. hours), thus, Artificial lift change out is not recommended. Among all recommendation the maximum NPV has Frac. Base risk which is based on the data quality and availability is 1800, additional risks for different activities: Frac +5000, FT +600, ST Recommendation is Frac Oil gain +2 tn/day, risk 6800, NPV 2875 ths. RUR. Technological effect 17.2 ths. tn, duration 18 months. 20

21 SAP UFAM supports complex approval processes for each type of activities 21

22 SAP UFAM is NOT system for Strategic field development planning Planning of new wells and sidetracking drilling Interpretation of well logs and seismic data 22

23 SAP UFAM is the system for: Creation of optimized short term Integrated Planning (daily, monthly and annual basis) Bottlenecking prediction based on «Choke model» Integration of different department in one virtual collaboration working environment Making operational activities more transparent and effective 23

24 Thank you! Contact information: Sergey Frolov Head of SAP Center of Excellence in Oil and Gas Industry, SAP CIS LLC

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