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Primary funding is provided by The SPE Foundation through member donations and a contribution from Offshore Europe The Society is grateful to those companies that allow their professionals to serve as lecturers Additional support provided by AIME Society of Petroleum Engineers Distinguished Lecturer Program www.spe.org/dl 1

Production Optimisation of Conventional & Unconventional Wells with ESP Real Time Data Lawrence CAMILLERI Production Optimization Advisor Artificial Lift Domain Head lcamilleri@slb.com Society of Petroleum Engineers Distinguished Lecturer Program www.spe.org/dl 2

Unconventional Well Case Studies: • Additional case studies for unconventional wells are not included in this slide deck, however they can be viewed via skype upon request to the author, who can be reached at lcamilleri@slb.com. • The skype session can also enable a more detailed Q&A where required. 3

The Digital Transformation Is Growing Fast Global Digital Oilfield Market ($bn) Enablers: ▪ Declining costs of sensors and data storage ▪ Rapid progress in advanced analytics (e.g. machine learning) ▪ Greater connectivity of people and devices ▪ Faster & cheaper data transmission Global Digital Oilfield Market 2017-2021 Technavio.com 4

Why ESP Production Optimisation? VSD ▪ 940,000 producing wells worldwide ▪ 125,000 (13%) of these wells lifted by ESP ▪ More than 54% of artificial lift global spend is on ESP (4.8 B$ out of 8.8B$ in Power Cable Pump 2017) with all other types representing less than 23% each. ▪ More than 30% of production lifted by Gas Separator Motor Seal ESP as it is the lift type with the highest rate Pump Intake Gauge ➔ ESP optimization has the biggest Motor impact on both production and AL Perforations expenditure 5

Operator’s View BP Rossneft Technology Outlook: 2015 SPE 112238, Real Time Optimisation Approach for 15,000 ESP Wells ▪ BP Believes that digital “ Calculations showed economical efficiency of system implementation on 7451 wells out of over technologies can deliver 11,000 working ESP wells, with possible annual • 4% Production oil production increase of 11 million bbls .” Enhancement ▪ This justified the investment of 6400 US$ per well • 13% Cost Savings in automation hardware i.e. Variable Speed Drive, Gauges and real time data transmission ▪ The first step is identifying the well max. potential ▪ What is the actual IPR curve? Pr and PI? ▪ What could be the PI after possible stimulation? 6

Agenda Commonly Available ESP Generic Concepts: VALUE OBJECTIVES Real Time Data ▪ Gauge metrology 1- Frequency 1. Uptime ▪ Data visualization 2- Current 3- Voltage 2. Run Life ▪ Slow & Fast Loop 4- Tubing Head Pressure ▪ Data to Value 3. Power Consumption Chain 5- Pump Discharge ▪ The importance Pressure 4. Production of high frequency Enhancement flowrate in 6- Pi = Intake Pressure addition to 7- Ti = Intake Temperature pressure data 8 - Tm = Motor Temperature 7

ESP Gauges…mature technology 1. Reliability – MTBF >10 years 2. No need for instrument line ➔ low cost 3. Metrology of ESP gauges ▪ Accuracy +/- 5 psi ▪ Resolution 0.1 psi ▪ Drift 5 psi / year ➔ INFLOW ANALYSIS IS POSSIBLE 8

Data Visualisation ➔ Solution = Multiple Tracks Challenge = Large Production Sets Solution - 6 to 15 analogue signals per well - Separate tracks for signal groups - 1 million points / year /signal - User defined filtering 9

Data to Value Chain Data Information Decisions Execution Value Domain 10

How Real Time Data & Automation Proactive Execution Data Maximized Information Decisions Value Domain Automation 11

The Value of Data … Interpretation Goal & Modeling Evaluate Data Options Acquisition Decision Makers Action takers Execute Shell’s Smart Fields Value Loop 12

Slow & Fast Feedback Loops – Applied to ESPs Design pump system Dedicated Field Stock: ▪ New replacement to well-site with 12 hours Workover Ops ▪ Dynamic to reflect future needs (not present) ▪ Cover the range of expected flows and heads ESP assembly & Commissioning Fast Lo ast Loop op Set Operating Parameters: Minutes & hours Stock is 1. Stop and Start replenished via 2. Choke Slow Slo w Lo Loop op manufacturing 3. Frequency Time is measured in facility 4. Control Mode months and in most cases years Monitor Performance: Rate, pressure, temperature Re-specify Equipment Pull Pump string Carry Out failure analysis Workover Operations (stimulation, fracking, sidetracking, reperforation) 13

VALUE OBJECTIVES 1.Uptime 2. Run Life 3. Power Consumption 4. Production Enhancement

The Main Causes of ESP Downtime The main two causes are: 1. Facility shut-downs e.g. electrical power interruption. 2. ESP stops automatically triggered by the motor controller to protect the ESP from misoperation, which would otherwise lead to failure. The main types are: – Deadheading : Usually caused by inadvertent valve closure – Pump-Off: Loss of submergence caused by pump rate greater than inflow potential – Gas Lock: performance is degraded by large volumes of free gas, which initially leads to low flowrate events. 15

Improving Uptime with FAST LOOP – Gas Lock Uptime All shutdowns eliminated for 300 days Domain & Algorithm Sets (previously 1 shutdown per day) 74% - Target Current - Underload delay Intake Pressure Stabilised - Low Frequency Setting Execution Data Frequency Current Variation Constant Current Achieved Value Frequency Varied Automatically Eliminate All Trips Courtesy of SPE-190940-MS; Tuning VSDs in ESP Wells to Optimize Oil Production — Case Studies 16

Gas Lock Protection 500 Period with no 400 Press.,psia Wellhead flow to wellhead 300 200 2200 Pump Discharge Press.,psia 2000 1800 1600 920 Pump Intake Press.,psia 900 900 860 Current Increasing Current, Amps 30 Gas Lock Current = 20 A 20 10 Underload Trip 60 Frequency, Hz Setting 15 A 40 18 11:4 12:00 12:15 12:30 5

PHI & Real Time Modelling Detecting Gas • Operating point relative to 1.5 BEP has an impact on pump Q/Q_BEP 1.0 gas handling (SPE 163048) 0.5 0 • PCL pump flowrate is higher and the Downhole Pump Rate difference with measured rate provides a measure of gas degradation. • PCL provides confirmation that transient Gas degradation downhole pump rate reaches zero rate when in gas lock mode. impact on rate • When frequency is increased, PIP & Pd, psia 4000 there is a step decrease in discharge pressure, this is due 2000 to gas degradation 2.0 • PHI provides advanced warning of Early identification of gas degradation, which is not gas degradation 1.5 detected by discharge pressure, PHI which also provides an alarm as to 1.0 when flowrate calculation overestimates rate 0 • Frequency can be tuned to eliminate severe 60 gas degradation. Frequency, Hz • Also in constant current mode, when No “flat Toping” = 50 frequency is not “flat toping”, PHI is 1.0, current target reached “flat toping” = current target thereby confirming gas degradation is quasi eliminated. When PHI is ~1.5, there is severe not reached = PHI = 1.5, PD 40 gas degradation low June Nov Dec Jan Feb Mar Apr May

• PCL provides confirmation that transient downhole pump rate reaches zero rate when in gas lock mode. • While this is OK occasionally to avoid a gas lock trip No “flat Toping” = and motor “flat toping” = current target not reached = PHI = overheating, the current target 1.5 frequency of these reached = PHI=1.0 events is high and causing additional stress to the ESP.

Increased Gas Degradation at Operating Point < BEP Multiple Stages – Schlumberger Test Single Stage – Tulsa University Less severe as the GVF is lower closer to discharge Courtesy of Gamboa, J. and Prado, M., 2012, Experimental Study of Two-Phase Performance of an Electric-Submersible- of pump as gas is compressed Pump Stage, SPE-163048-PA.

Improving Uptime with FAST LOOP – Pump Off Challenge: 5 shut-downs 100% Uptime with stable in 5 days production for one year Low PI well with some Liquid Rate, gas tripping on underload Calculated liquid rate B/D causing downtime. press., psia Intake Constant intake pressure Solution Constant intake pressure Temp, oF Motor feedback mode ➔ maintains drawdown and Motor Temperature spikes during restarts Frequency, avoids tripping. Hz Frequency automatically varied 22

Improving Uptime with SLOW Loop Production Increased by 250 sm3/day Wellhead Pressure indicates Severe Slugging Stabilized At Workover Helico-Axial SPE 141668; Helicoaxial Pump Gas Handling Technology: A Pump Installed Case Study of Three ESP Wells in the Congo 23