Intellectual oilfield SAP UFAM optimization and …...*) RC - reserve calculation, FS–feasibility...

PUBLIC

Sergey Frolov, SAP

April 26, 2018

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

2PUBLIC© 2018 SAP SE or an SAP affiliate company. All rights reserved. ǀ

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


GOALSHORIZONS OF

PLANNINGPERIOD DOCUMENT

Strategic horizon 1 – 100 years(till the FS* targets will be achieved)

RC FS FDP*

Medium-term horizon 2 - 5 years FDP

Yearly horizon 1 year

Month horizon 1 month

Operational level 1 day - hours

Excel files

*) RC - reserve calculation, FS– feasibility study of oil recovery factor, FDP - field development plan

Horizons of planning for oil and gas fields


Several iterations

normallyWithout accounting of

interferences and

influences of activities

on each other

Individually by

different departments

Functional plan AS IS

Initiation by

departments

Integrated

Planner

MT approval

Manual daily

update

Initiation and approval

with in department of

all types of operational

activities with proposed

execution day/duration

and required well

shutdowns

Arrange activities and

calculate deferments

and production profile

Monthly Integrated

Plan approval by

Management Team

As result of new input

(unscheduled activities,

execution delay,

extension, overdue, etc.)

Drawbacks of AS IS process:

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


Monthly operational plan on the first day of a month

Object Month

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

Well1

PL1

PSS1

WMU

MPPS1

0

5

10

15

Scheduled deferment Unscheduled deferment


Monthly operational plan vs. fact on the last day of a month

Object Month

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

Well1

PL1

PSS1

WMU

MPPS1

0

5

10

15

Scheduled deferment Unscheduled defermentFact


SAP UFAM Intelligent OilfieldIntegrated Operations Center

Collaboration

Real-time collaboration between

specialists in different functional areas.

Upstream Integrated PlanningCreation of a Integrated Operational Plan

for workovers, maintenance and repairs

including reservoirs, wells and field

gathering system.

Upstream Integrated Models

Use of integrated model to forecast operations

(production, downtime, etc.) given the

Integrated Operational Plan.

Upstream Integrated Analysis

Rapid Decision Making

Efficient management and coordination of

work during emergencies.

Comprehensive analysis of field

development and operations to identify

potential well and field optimization options.


✓ 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

SAP UFAM is a result of partnership between SAP and NV-ASUproject (OIS)

Upstream

Field

Activity

Management

✓ Investment

✓ Costs

✓ NPV

✓ Hydrocarbon Accounting

✓ Plant Maintenance program

✓ Asset Failure Statistics

✓ Economical model


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.

SAP UFAM INCLUDES 4 BLOCKS

Pool of Assets-Candidates for Treatment

Integrated Planning

Integrated Analysis

Integrated Modelling

Monitoring1

Integrated AnalysisComprehensive 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


Integrated Schedule of Activities


Integrated Planning

Integrated Analysis


Monitoring

2

Integrated PlanningGeneration 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




Planned Production based on Models of:

Reservoir / Well/ Infrastructure / Fluid

Integrated Planning

Integrated Analysis


Monitoring

Actual Status of Assets and Activities

3

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




Planned Production based on Models of:

Reservoir / Well/ Infrastructure / Fluid

Integrated Planning

Integrated Analysis


Monitoring

Actual Status of Assets and Activities4

MonitoringMonitoring 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

SAP UFAM

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

SAP UFAM – EXPERT SYSTEM AND OPERATES

WITH OTHER SOURCES OF DATA

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

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


SAP UFAM applies different models depending on data availibilityR

equir

ed d

ata

Data used for analysis

▪ Field development history

▪ 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

▪ Well history

▪ Initial reservoir pressure

Desir

ed d

ata

▪ Well Interventions cost

▪ 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

▪Well Test

▪PI

▪Skin-factor

▪Reservoir Pressure

▪Connectivity (interference test)

▪Logging

▪Casing leak

▪Emergencies

▪Logging - lithology

▪Porosity

▪Permeability

▪Saturation

▪Indicator surveys

▪Layers connectivity

▪Core analysis

▪Permeability curves

▪Laboratory analysis

▪Fluid density

▪Relaxation time

▪Shear index

▪Six components

analysis

Additio

nal data

based o

n W

ell

Tests

results


Well intervention justification

Analysis of the well № *** / 2Б10 Field «*******», ООО «***********» on 01.08.2017

Artificial lift: ESP-250-50, setting depth 3250 m, Runlife 70%, Probability of failure = 34%Liquid flowrate, m3/day / Oil flowrate, tn/day / BSW, %: 7.2 | 4.1 | 56,2Gross reservoir interval / Perforated, m: 15.1 (terrigenious) | 2.2 (performed on 05.10.2016)FBHP / Drawdown, bar, skin-factor: 145.1 | 25.2 | +5Last Well Intervention: Frac on 05.10.2016Last well surveillance: FBU on 02.11.2017

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 245.2 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 +1200. 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 +7200.Recommendation is FracOil gain +2 tn/day, risk 6800, NPV 2875 ths. RUR. Technological effect 17.2 ths. tn, duration 18 months.

Explanation of the recommended by Integrated Analysis activity


SAP UFAM supports complex approval processes for each type of activities


SAP UFAM is NOT system for

Strategic field development planning

Planning of new wells and sidetracking drilling

Interpretation of well logs and seismic data


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

Contact information:

Sergey Frolov

Head of SAP Center of Excellence in Oil and Gas Industry,

SAP CIS LLC

Email: [email protected]

Thank you!

mailto:[email protected]

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Intellectual oilfield SAP UFAM optimization and …...*) RC - reserve calculation, FS–feasibility...

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