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Initiating Digital Oil Field Application at Mature Offshore Oil Field in South East Sumatera, Indonesia

Lucky Bagus WaskitoPertamina Hulu Energi (PHE) OSES

Houston, 27th Aug 2019

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Agenda Field Introduction

Goals & Challenges

Current State

Future State

Transformation Roadmap

Quick Wins

Field Introduction

2018 - Now

Sumatera

Java

KalimantanSulawesi

PHEOSES

Massive ESP:

412 wellsLiquid rate:

1,804,792 BFPD

Oil Rate:

30,000BOPD

42 Oil Fields

87 Remote Platform

Power

consumption:

93 MW

Area:

11,046km2

Oil Rate (Cal. Day) bbl/d Water Cut % Wells Producing Oil wells

OSES Production History

Major decline due to unstable well production

14% Yearly decline rate during 2002 - 2011

6% Yearly decline rate during 2012 - 2019

300 Yearly well service during 2016 - 2019

Early development phase Development phase Decline (Mature) phase

Goals & Challenges

Problem Identification

Data

ManagementInefficient

Workflow

Rapid ESP

FailuresLack of Real-

Time Instrument

• Time wasters

• Late decision

• Repeatable Study

Acquiring, processing,

analyzing, and

interpreting data still

in silos

• High Opex

• Oil loss opportunity

during down time

period

• Data Accuracy

• Digital Oil Field needs

real-time data

The Idea

Real-time ESP

surveillanceAnalytical

dashboard

Seamless work

orders and

actions

Field

Automated

Operation

Minimize production

downtime through

early problem

detection and faster

action

Integrate high value

data and simplify

workflow between

functions

Collaborative well

planning to speed up

communication

between functions

Automation of PHE

OSES Oilfield Operations

Current State

Current State Workflow

EPTField Review Well recommendation

Reactivation

Pump Upsize

Choke up/down

Intermittent Production

BUWell Review

DHP

Liquid problem

Nodal Analysis Pump Request

Troubleshoot

DHP

Keep Running

ALESP Review

DHP ESP QC Installation Monitoring

Troubleshoot

DHP

Keep Running

Future State Identification Workshop

Areas Covered in Workshop

Design Preparation OperationMonitoring and

Troubleshooting

Process and Workflows

Roles and Responsibilities

Data and Technology

As-is Mapping

• Design

• Preparation• Operations

• Monitoring and Troubleshooting

Future State

Target State Mapping

EPTPVT, Log, core

Prodview

PetrelRes. map OFM

Prod History

Forecast

Excel

PDF

Word

Pptx

WellFlo

PHE OSES Real-Time Analytical Dashboard

BUSBHP, PBHP, TP,

CP, PBHT

Pipesim

Well DB

BFPD, BOPD, GOR, MCFD

Prodview

Well Remark, Nodal

AM/PM Report

Excel

PDF

Word

Pptx

Barge Schedule

ALPBHP, T, DP

Lotus NotesRunning Amper

Failure Data

ESP database

Excel

PDF

Prodview

Scada

AM/PM ReportLotus notes

EcoPlan

Barge NPV

Post-Job Evaluation

Excel

Merak

Real-time well data (liquid

rate, sbhp, pbhp, etc)

ESP Alarm & Suggest Potential Remedial Action

Dynamic data & prediction using machine learning

Automatic Reservoir Surveillance

Drilling & Well service economic evaluation, NPT

NPT

EDM

High Level Solution Architecture

Integration LayerData

Integration

Data

Sources

SurveillanceDiagnostic and

TroubelshootingDesign

Workflow Automation, Well Models, Business RulesWorkflow and

Algorithms

SCADA PRODVIEW OPENWELLSLIFTWATCHER DATA MART

Reporting

Transformation Roadmap

Digital transformation Road Map

Integrate & Simplify cross-function workflow

Build digital platforms & real-time dashboard: Integrate data & software, insert fuzzy logic algorithm, etc

Install SCADA for real-time monitoring in all active wells

Launching PHE OSES Intelligent Digital Oil Field

Develop subsurface algorithm to optimize RF & reserves added

Design advance production operation through field automation

2019

(On going)

2019

(Oct)

2020

(Nov)

2020

(Dec)

2021

(Jan)

2022

(Jan)

Phase 1 Phase 2 Phase 3 Phase 4

Prioritized Improvement InitiativesStep 1 (Pilot) Step 2 Step 3

• ESP Design

• ESP/ Well Surveillance

• Daily Production Reporting

• Diagnostics and Troubleshooting

• Management Reporting

• Increase Run Life (10-20%)

• Reduce Production Loss

• Improve Productivity

• Increase Recovery

• Improve Productivity

• Better Design + Run Life

• Reduce Production Loss

• Well Test Validation• Virtual Flow Rate • Well Review • Reservoir Surveillance

• Reduce Production Loss

• Lower Non-Productive Time

• Improved Productivity

• Barge Schedule Optimization

• SOP Automation Initiatives

Business

Value

Phase 2

• Management Reporting

• Daily Production Reporting

Pilot Roll Out• ESP Design

• ESP Well Surveillance

• ESP Diagnostics and Troubleshooting

2-3 Months 2-3 Months

Increased run-life Downtime Reduction

Faster ResponseSuccess

Criteria

4-6 Months

Pilot Execution Plan

Quick Wins

Quick Wins

Prolong

ESP Runlife

Average runlife OSES (Days) 460

Average oil / well (BOPD) 75

Oil Price (USD/bbl) 65

5% Runlife Incremental (Days) 23

Oil Gain Volume (Bbl) 1,725

Total Value Gain (USD) 112,125

10% Runlife Incremental (Days) 46

Oil Gain Volume (Bbl) 3,450

Total Value Gain (USD) 224,250

15% Runlife Incremental (Days) 69

Oil Gain Volume (Bbl) 5,175

Total Value Gain (USD) 336,375

Well Service

Cost Reduction

Well Service Yearly OSES (Job) 300

Average Well Service Cost (USD) 350,000

5% WS decrease (Job) 15

Total Cost Reduction (USD) 5,250,000

10% WS decrease (Job) 30

Total Cost Reduction (USD) 10,500,000

15% WS decrease (Job) 45

Total Cost Reduction (USD) 15,750,000

ESP Troubleshooting Trip reduction

Yearly (Trip) 300

Cost Reduction from other

related surveillance tools (USD)553,086

Potential Cost Reduction for

repeatable Subsurface Study

(USD/study)500,000

Surveillance Tools

Data Management

ESP Troubleshooting

Reduction to engineer surveillance

analysis time (Hrs/year) 416

Engineer Analysis

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