Slb Limited · NYSE:SLB
Slb — SIS Global Forum 2019
28 slides from Slb's conference presentation, Sep 18, 2019
Slide 1: Managing Wells with Flow Assurance in the Karachaganak Field using OLGA
SIS GLOBAL FORUM 2019 Managing Wells with Flow Assurance in the Karachaganak Field for Sustainable Production using OLGA Monaco 18 September 2019
Slide 2: Agenda
Agenda § Introduction § Objectives § OLGA results § Conclusion and recommendation SIS Global Forum 2019 18 September 2019 2
Slide 3: Introduction
INTRODUCTION § One of the world’s largest oil & gas RUSSIA Major Pricaspian oil and gas fields condensate fields; Samara Aktobe UKRAINE Orenberg § Discovered in 1979; Uralsk Astana Aksai Karachaganak § Gross reserves – over 2.4 billion barrels of Sea of Azov Novorissiysk PRICASPIAN BASIN Atyrau Zhan
Slide 4: Objectives
OBJECTIVES § The primary objective is to present the application of transient multiphase flow simulator as an aid to predicting production system performance with solids deposition in tubing and flowline in the Karachaganak field § The secondary objective is to able to provide solutions using modell
Slide 5: Wax, Asphaltenes and Hydrates
Wax, Asphaltenes and Hydrates § Wax – mainly consists of heavy high molecular weight normal paraffins, varying amounts of cycloparaffins, isoparaffins § Asphaltenes – are complex heavy hydrocarbon molecules defined to be soluble in benzene and insoluble in low molecular weight n-alkanes § Gas Hydrat
Slide 6: Well model
INPUT DATA Deviation data Vertical wells Well completion Fluid composition Casing, Tubing, (KPO PVT Packer, Perforation database, EoS) data Wax Laboratory Production data Well analysis WAT, WDT, FWHP, Pmanifold, model HTGS, Wax content, SARA Qoil, GOR, analysis e.t.c. Reservoir Flowline profile para
Slide 7: Well D08 - Wax deposition
Well D08 - Wax deposition § Well background § Model setup § Well performance matching § Wax deposition assessment § Conclusion SIS Global Forum 2019 18 September 2019 7
Slide 8: Well D08 - Model setup
Well D08 - Wax deposition Model setup § Input data: § Pres=390 bar § Pslot=73 bar § PI=1 sm3/d/bar § GOR ~ 660 sm3/sm3 § PI and GOR were selected to match Average Oil Rate: 180 sm3/d § Uncertainties: § PVT § Where and when Deposition occurs ? SIS Global Forum 2019 18 September 2019 8
Slide 9: Well D08 - Model setup
Well D08 - Wax deposition Model setup § Fluid model was created and calibrated based with Laboratory data - WAT, WDT, rheology and wax content in Multiflash WAT line 28° C § Blue line shows the wax appearance temperature (WAT) calculated by Wilson model within Multiflash § To the right of the WAT cu
Slide 10: Performance matching - Fluid temperature in flowline
Well D08 - Wax deposition Well performance matching – Fluid temperature in flowline WAT T (fluid) < WAT ºC Ambient temperature SIS Global Forum 2019 18 September 2019 10
Slide 11: Performance matching - Flowline plug
Well D08 - Wax deposition Well performance matching – Flowline plug § Prediction of wax deposition in flowline, requires selecting a period of a plug formation for matching § Matzain, RRR, Heatanalogy models at different diffusion and shear coefficients built § RRR model gave the highest wax deposit
Slide 12: Wax deposition assessment in flowline
Well D08 - Wax deposition Wax deposition assessment in flowline Tam b -25° C Tam b -30° C Tam b -15° C Tam b -15° C Pressure Mass Tam b -25° C Tam b -5° C Tam b -30° C Tam b 0° C Time (d) Time (d) § OLGA predicts plugging of flowline at § Mass of wax deposit at different temperatures different ambie
Slide 13: Wax deposition assessment in flowline
Well D08 - Wax deposition Wax deposition assessment in flowline SIS Global Forum 2019 18 September 2019 13
Slide 14: Wax deposition assessment with heater
Well D08 - Wax deposition Wax deposition assessment with heater § Placing heater (Tout=65ºC) near 55°C 60°C 65°C wellhead has a significant impact on a temperature profile § Heating doesn’t eliminate wax deposition completely § However, reduces the amount of wax deposition in flowline § Eliminates p
Slide 15: Production with Reactive vs. Proactive Intervention Strategy
Well D08 - Wax deposition Well D08 Production with Reactive vs. Proactive Intervention Strategy Proactive Intevention Strategy and Reactive Intervention Strategy Transient Simulation Model Benefits Date Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 Cummulative production fore
Slide 16: Conclusion
Well D08 - Wax deposition Conclusion § Well flowing condition of the model matched to available measured data § Wax deposition in the flow line occurs from -25°C to 0°C § OLGA reproduces flowline plugging behavior § RRR model predicted the highest wax deposit matching plugging behavior of D08 § Heat
Slide 17: D20 - Hydrate
D20 - HYDRATE § Well background § Model setup § Hydrate formation assessment § Hydrate mitigation § Conclusion SIS Global Forum 2019 18 September 2019 17
Slide 18: D20 - Hydrate model setup
D20 - HYDRATE Model setup Input data: § Pres=343 bar § Pslot=100 bar § PI=4.4 sm3/d/bar § GOR ~ 1300 sm3/sm3 SIS Global Forum 2019 18 September 2019 18
Slide 19: D20 - Hydrate formation curve
D20 - HYDRATE Model setup Hydrate formation curve No hydrate zone Hydrate zone SIS Global Forum 2019 18 September 2019 19
Slide 20: D20 - Hydrate DTHYD
D20 - HYDRATE § OLGA provides the DTHYD which is difference between the prevailing temperature at that point and the Hydrate formation temperature at the local operating conditions (DTHYD=Thyd-Tfluid) § If DTHYD is positive then Hydrate Formation is occur ºC Pipeline length SIS Global Forum 2019 18
Slide 21: Hydrate formation assessment
D20 - HYDRATE Hydrate formation assessment Fluid temperature DTHYD ºC ºC dThyd<0 dThyd>0 Tubing length Pipeline length § No hydrate inside tubing § Tfluid <Thyd 400 m away from wellhead § Tambient=0ºC § Tambient=0ºC § dThyd=Thyd-Tfluid SIS Global Forum 2019 18 September 2019 21
Slide 22: Batch pumping of methanol
D20 - HYDRATE Batch pumping of methanol § Batch injection cannot be used as a preventive measurement (MeOH flows out after 1.5-2 hrs) § Calculated optimum continuous MeOH injection rates at different ambient temperature DTHYD Fluid temperature ºC Pipeline Pipeline length SIS Global Forum 2019 18 Sep
Slide 23: Continuous pumping of methanol
D20 - HYDRATE Continuous pumping of methanol Tambient, MeOH 30 kg/hr 40 kg/hr 50 kg/hr ºC injection rate, kg/hr 0 30 0 40 0 50 ºC Pipeline Pipeline length SIS Global Forum 2019 18 September 2019 23
Slide 24: D20 - Hydrate Conclusion
D20 - HYDRATE Conclusion § Trace water in hydrocarbon (presence of gas) at the right dP and low temperature can create hydrates § Batch injection of Methanol (MeOH) is not an effective measure to mitigate hydrates irrespective of volumes pumped § Only continuous injection of methanol enables stable
Slide 25: Conclusion
CONCLUSION § OLGA as a transient multiphase flow simulator has demonstrated the versatility to predict key flow assurance issues, such as hydrate and wax deposition § OLGA enabled a better understanding of flow transients and offered a quantitative management strategy of proactive treatments with ch
Slide 26: Ongoing Work and Future Studies
ONGOING WORK AND FUTURE STUDIES Continuous injection of solvent/inhibitor to remove wax deposition § Laboratory analysis § Compositional analysis, § Determination WAT at different concentration of solvent in crude oil, § Flow loop testing § OLGA model § Lab results to serve as input into further OLG
Slide 27: Q&A
Q&A SIS Global Forum 2019 18 September 2019 27
Slide 28: Thank You
THANK YOU SIS Global Forum 2019 18 September 2019 28