# Horizontal Well Performance Optimization Analysis

26 May 2016
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### Horizontal Well Performance Optimization Analysis

• 2. • Aim • What is Optimization? • What is Production Optimization? • Production Optimization Using Nodal Analysis • Improved Nodal Analysis for Horizontal Well • Factors Affects Pressure Losses in Horizontal Section • Factors Affects Pressure Losses in Inclination Section • What is PROSPER? • Applications of PROSPER • Results • Unimaginable Point! • Conclusion • References 2
• 3. The aim of this project is to optimize the production in horizontal wells, there are several methods to optimize production in horizontal wells. One of the most effective way to achieve the gaol is increasing horizontal well section. 3
• 4. Optimization is an act, process, or methodology of making as fully perfect, functional, or effective as possible, specifically the mathematical procedures involved in this. 4
• 5. • The term ‘‘production optimization’’ has been used to describe different processes in the oil and gas industry. • Production Optimization means Balance between Production rate / Deliverability and demand. • Production Optimization includes a good understanding about Production Systems and Reservoir Fluid. 5
• 6. • Well deliverability is determined by the combination of well inflow performance and wellbore flow performance. • This work focuses on prediction of achievable fluid production rates from reservoirs with specified production string characteristics. • The technique of analysis is called “Nodal Analysis” 6 Gilbert (1956) (10)
• 7. 7production optimization using Nodal Analysis (2)
• 8. After improve nodal analysis for horizontal well, two important section will be increased that are following: • Horizontal Section • Inclination Section 8
• 9. 1. The characteristics and physical properties of the fluid. 2. Friction in pipes. 3. Energy losses in fitting. 4. Pressure drop through equipment. 5. The distance or length the fluid must travel. 6. Diameter change of the pipe. 9
• 10. Factors affects pressure losses in horizontal section same as bent section, only one factor will be added which is Pressure Losses whenever the flow direction changes. The pressure loss in a bend can thus be calculated as: 10
• 11. • PROSPER is a well performance, design and optimization program. • PROSPER is designed to allow the building of reliable and consistent well models, with the ability to address each aspect of well bore modelling PVT, VLP correlations and IPR. • PROSPER enables detailed surface pipeline performance and design: Flow Regimes, pipeline stability, Slug Size and Frequency. 11
• 12. • Design and optimize well completions including multi-lateral, multilayer and horizontal wells. • Design and optimize tubing and pipeline sizes. • Design, diagnose and optimize Gas lifted, Hydraulic pumps and ESP wells. • Calculate pressure losses in wells, flow lines and across chokes. • Predict flowing temperatures in wells and pipelines. • Calculate total skin and determine breakdown. • Allocate production between wells. 12
• 13. D:Koya UniProd Eng II - 2015-2016projec tH.W OptPROSPE R ModelT 04_HORIZONT ALOILWE LL.Out 0 21000 42000 63000 84000 0 1000 2000 3000 4000 IPR plot Horizontal Well - No Flow Boundaries (HW 05/14/2016 - 11:58:15) Rate (S T B/day) Pressure(psig) Inflow T ype Single Branch Completion Cased Hole Sand Control None Gas Coning No Reservoir Model Horizontal Well - No Flow Boundaries M& G Skin Model Enter Skin B y Hand Compaction Permeability Reduction Model No Relative P ermeability No Formation PI 41.07 (ST B /day/ps i) Absolute Open Flow (AOF)82543.8 (ST B /day) Reservoir Pres sure4000.00 (ps ig) Reservoir T emperature200.00 (deg F) Water Cut 0 (perc ent) T otal GOR400.00 (sc f/S T B) Reservoir Permeability150.00 (md) Reservoir T hic knes s 100.0 (feet) Wellbore Radius 0.354 (feet) Reservoir Porosity (fraction) Horizontal Anis otropy 1 (fraction) Vertic al A nisotropy 0.1 (fraction) Length Of Well2000.0 (feet) Reservoir Length5000.0 (feet) Reservoir Width5000.0 (feet) Dis tanc e From Length E dge T o Centre Of Well2500.0 (feet) Dis tanc e From Width Edge T o Centre Of Well2500.0 (feet) Dis tanc e From Bottom T o Centre Of Well 50.0 (feet) Skin 5 AOF : 82543.8 (ST B/day) Formation PI : 41.07 (ST B/day/psi) SK IN : 5 Results: IPR curve 13
• 14. Results: Well Capacity 0 10000 20000 30000 40000 0 1500 3000 4500 6000 Inf low (IPR) v Outf low (VLP) Plot (HW 05/15/2016 - 08:35:04) Liquid Rate (STB/day) Pressure(psig) PVT Method Black Oil Fluid Oil Flow Type Tubing Top Node Pressure250.00 (psig) Water Cut 0 (percent) Bottom Measured Depth8050.0 (feet) Inflow Type Single Branch Completion Cased Hole Sand Control None Solution Point Liquid Rate18453.6 (STB/day) Oil Rate18453.6 (STB/day) Water Rate 0 (STB/day) Gas Rate 7.381 (MMscf/day) Solution Node Pressure3354.18 (psig) dP Friction 823.12 (psi) dP Gravity2237.76 (psi) dP T otal Skin 196.48 (psi) dP Perforation 0 (psi) dP Damage 0 (psi) dP Completion 0 (psi) Completion Skin 5.00 Total Skin 5.00 Wellhead Liquid Density 52.761 (lb/ft3) Wellhead Gas Density0.87847 (lb/ft3) Wellhead Liquid Viscosity 2.3440 (centipoise) Wellhead Gas Viscosity0.012674 (centipoise) Wellhead Superficial Liquid Velocity 14.432 (ft/sec) Wellhead Superficial Gas Velocity 56.913 (ft/sec) Wellhead Z Factor0.96557 Wellhead Interfacial Tension14.9531 (dyne/cm) Wellhead Pressure 250.00 (psig) Wellhead Temperature 172.16 (deg F) First Node Liquid Density 52.761 (lb/ft3) First Node Gas Density0.87847 (lb/ft3) First Node Liquid Viscosity 2.3440 (centipoise) First Node Gas Viscosity0.012674 (centipoise) First Node Superficial Liquid Velocity 14.432 (ft/sec) First Node Superficial Gas Velocity 56.913 (ft/sec) First Node Z Factor0.96557 First Node Interfacial T ension14.9531 (dyne/cm) First Node Pressure 250.00 (psig) First Node Temperature 172.16 (deg F) E E E 14
• 15. Results: Well Length Optimization Reuslts 0 10000 20000 30000 40000 0 1500 3000 4500 6000 Inf low (IPR) v Outf low (VLP) Plot (HW 05/14/2016 - 12:04:10) Liquid Rate (STB/day) Pressure(psig) PVT Method Black Oil Fluid Oil Top Node Pressure250.00 (psig) Water Cut 0 (percent) Inflow Type Single Branch Completion Cased Hole Variables 1:Well Length (feet) 1 2 3 0=500.0 1=1000.0 2=1500.0 3=2000.0 4=2500.0 5=3000.0 0 0 E E E 1 1 E E E 2 2 E E E 3 3 E E E 4 4 E E E 5 5 E E E 15
• 16. Results: Well Length Sensitivity Results 16
• 17. Results: Well Length Sensitivity Results 0 500 1000 1500 2000 2500 3000 3500 4000 0 500 1000 1500 2000 2500 3000 3500 Pwf Well Length 17
• 18. Results: Well Length Sensitivity Data Results Well length in ft Pressure in psi Production rate STB/day 500 2706.98 11689.5 1000 3036.53 15233.2 1500 3226.67 17152.5 2000 3354.18 18453.6 2500 3448.84 19379.3 3000 3522.08 20062.4 18
• 19. • With increasing length, pressure drop must be increased. • Also with increasing length, Pwf & Flowrate will be increased. 19
• 20. 20 well length Pwf dp friction dp gravity 500 2706.98 388.5 2045.59 1000 3036.53 600.26 2153.6 1500 3226.67 728.4 2207.15 2000 3354.18 823.1 2237.77 2500 3448.84 892.15 2259.63 3000 3522.08 944.54 2275.82
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• 22. • Horizontal wells are better than vertical. • To optimize production in horizontal wells, many factors can be considered. • The production can be optimized by increasing of length of horizontal section. • The PROSPER can be helpful to achieve the results, it may be used to choose the best result. 22
• 23. 1. Petroleum Production Engineering, A Computer-Assisted Approach by Boyun Guo, PH.D. , William C. Lyons, PH.D. and Ali Ghalambor, PH.D. 2. Production Optimization Using Nodal Analysis by H. Dale Beggs, 1991 Oklahoma. 3. Development and Applications of Production Optimization Techniques by PENGJU WANG, 2003 Stanford. 4. Pressure drop evaluation along pipelines https://www.scribd.com/doc/284696108/Theory 5. Fluid-Flow Theory, Energy Losses in Flow http://www.nzifst.org.nz/unitoperations/flfltheory5.htm#frictioninpipes 6. Pressure Loss Form Fittings – Expansion and Reduction in Pipe Size https://neutrium.net/fluid_flow/pressure-loss-from-fittings-expansion- and-reduction-in-pipe-size/ 23
• 24. 7. Flow in Pipes http://www.uomisan.edu.iq/eng/ar/admin/pdf/26059867395.pdf 8. Bends, Flow and Pressure Drop in by Jayanti, Sreenivas http://www.thermopedia.com/content/577/ 9. Its application to well producing system was first proposed by Gilbert (1954) 10. PROSPER, Petroleum Experts, User Manual, Version 11.5, January 2010 24
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