Master Thesis Pure Unileoben Ac At-Books Pdf

Master Thesis pure unileoben ac at
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I declare in lieu of oath that I wrote this thesis and performed the associated research. myself using only literature cited in this volume . , Thomas Posch , Leoben November 2010, Table of Contents. 1 Abstract 1, 2 Introduction 2, 3 Theory 3, 3 1 Parts of an ESP 3. 3 1 1 Motor 4, 3 1 2 Pump 5, 3 1 3 Protector or Seal Section 7. 3 1 4 Pump Intake and Downhole Gas Separator 10, 3 1 5 Switchboard 10. 3 1 6 Power Cable 12, 3 1 7 Pump Housing Limit 12.
3 2 Factors affecting pump design 12, 3 2 1 Influence of speed specific gravity and diameter 13. 3 2 2 Effect of viscosity 14, 3 2 3 Pump Shaft Horsepower Limit 14. 3 2 4 Vibration and wear 14, 3 3 NodalTM Analysis 15. 4 The Ras Fanar Field 17, 4 1 General Characteristics of the Reservoir 17. 4 2 Reservoir Geology 18, 4 3 Production History 19.
4 4 Reservoir Pressure Decline 20, 5 Evaluation of the Current Situation 21. 5 1 Nominal Platform Layout 21, 5 2 Wellhead 22, 5 3 Wellbore Completion 23. 5 4 Wellbore installation 25, 5 5 Well Behaviour 26. 6 Investigations 30, 6 1 Failure Analysis Trip History and Run Life 30. 6 1 1 Electric Failures 32, 6 1 2 Failures due to Old Age 32.
6 2 Well Test Data 33, 6 2 1 Tubing Leak in RF B4 34. 6 3 Optimization of IPR Determination 35, 6 3 1 Setting up an IPR Model Current Procedure 35. 6 3 2 Investigation of Input Data 37, 6 3 3 Allocation Factor 37. 6 3 4 Multiphase Flow Correlation 39, 6 3 5 Setting up an IPR Model Recommended Procedure 44. 6 3 6 IPR Determination 45, 6 3 7 Pressure drop in the choke 52.
6 4 Re calculation of the ESP 53, 6 5 Chemical treatment 63. 7 Recommendations 64, 7 1 Chemical treatment 64, 7 1 1 Downhole injection of Corrosion Inhibitor 64. 7 1 2 Sampling Procedure 64, 7 2 Electricity 66, 7 2 1 Improvement of power quality 66. 7 2 2 Minimum Motor Current 67, 7 2 3 VSD Setting for Gassy Wells 67. 7 3 Data 68, 7 3 1 Static Pressure Surveys 68, 7 3 2 Multisensor 68.
7 3 3 Echometer Survey 68, 7 3 4 Production Data 69. 7 3 5 Availability of Data 69, 7 4 ESP Design 70. 7 4 1 ESP Set Up 70, 7 4 2 Simulation 70, 7 5 Production 71. 7 5 1 High pwh of B9 71, 7 5 2 Work over 71, 7 5 3 Production Increase 72. 7 5 4 Bottlenecks in the Flow Line 73, 8 Economic Assessment 74.
9 Conclusion 77, 10 References 78, Appendix 81, List of Figures. Figure 1 Geological structure1 2, Figure 2 Typical ESP Installation4 3. Figure 3 Design and flow path of a pump stage7 5, Figure 4 One stage pump performance curve8 6. Figure 5 Impeller thrust versus flow rate7 7, Figure 6 Expansion of the heated motor oil9 8. Figure 7 Labyrinth chamber9 8, Figure 8 Thrust bearing9 9.
Figure 9 Shaft seal9 9, Figure 10 Starting Torque versus Frequency and Current11 11. Figure 11 VSD curve also known as tornado chart7 11. Figure 12 Possible pressure losses in a complete production system13 15. Figure 13 Node pressure pwf versus flow rate q16 16. Figure 14 Strartigraphic Column2 18, Figure 15 Cumulative Production of Ras Fanar1 19. Figure 16 Ras Fanar Oil Reserve Distribution June 2008 19. Figure 17 Static Bottom hole Pressure Main Field 20. Figure 18 Static Bottom hole Pressure West Field 20. Figure 19 Platform Layout 21, Figure 20 Wellhead Design17 22. Figure 21 Completion Diagram17 24, Figure 22 Outtake of the irregular Echometer shot trace 34. Figure 23 Location of various nodes 35, Figure 24 IPR of RF B1 with available data and current design procedure 36.
Figure 25 Flow correlation matching B1 pressure versus depth chart 43. Figure 26 IPR of B1 45, Figure 27 IPR of B2 46, Figure 28 IPR of B3 47. Figure 29 IPR of B7 48, Figure 30 IPR of B8 49, Figure 31 IPR of B9 50. Figure 32 IPR of B10 51, Figure 33 Tornado chart for the present IPR 55. Figure 34 Tornado chart for the present IPR actual pump and 30 bar pwh 60. Figure 35 Tornado chart of B10 61, Figure 36 Tornado chart of B11 62. Figure 37 Emulsion viscosity multiplier for medium light crude oil33 64. Figure 38 Pseudo Sine Wave34 66, Figure 39 Effect of changing load on the motor35 67.
List of Tables, Table 1 Average Reservoir Fluid Properties 17. Table 2 Configuration of installed pumps 25, Table 3 Averaged Production Data Measured via Offshore Test Separator at 5 bar and 45 C26. Table 4 Average run life of ESP 30, Table 5 Failure history of Ras Fanar B 31. Table 6 Echometer Level shot results 33, Table 7 Input Data to set up a model of RF B1 36. Table 8 Gas Analysis 37, Table 9 Platform B production with allocation factors 38.
Table 10 Applicable Correlations 39, Table 11 Comparison study16 42. Table 12 Recommended Input Data 44, Table 13 Recommended Input Data B1 45. Table 14 Recommended Input Data B2 46, Table 15 Recommended Input Data B3 47. Table 16 Recommended Input Data B7 48, Table 17 Recommended Input Data B8 49. Table 18 Recommended Input Data B9 50, Table 19 Recommended Input Data B10 51.
Table 20 Critical Flow Correlations and Results 52. Table 21 Comparison of actual and proposed pump type B1 55. Table 22 Comparison of actual and proposed pump type B2 56. Table 23 Proposed designs for B2 56, Table 24 Comparison of actual and proposed pump type B3 57. Table 25 Proposed designs for B3 57, Table 26 Actual design is in operation range B7 58. Table 27 Proposed designs for B7 58, Table 28 Actual design is in operation range B8a 59. Table 29 Proposed designs for B8a 59, Table 30 Actual design is not in operation range B9 60. Table 31 Actual design is in operation range B10 61. Table 32 Proposed design B11 62, Table 33 Production scenarios 72.
Table 34 Budget for several proposals 74, Table 35 Input parameters for economical assessment 75. Table 36 Economic Assessment Factors 76, Acknowledgements. This thesis was composed at the Department of Petroleum Production and Processing at the. Mining University of Leoben for RWE Dea as the contracting company I wish to thank the. following people for their support and assistance to make the thesis possible . First I wish to thank Univ Prof Dr Herbert Hofst tter head of the Department for his. helpful advice and patience , I also owe thanks to Dipl Ing Herbert Scheibenbauer of the SUCO who was the spiritual. father of this thesis and who supported me with all the data I needed and with his advice . Without his help this thesis would not have been completed successfully . Armando Villavona MSc was of great importance for the success of this thesis He was my. advisor at the Suez Oil Company He always had an open ear for problems or with data and. he gave me some good advice and ideas around this thesis which helped me to continue He. was the person who gave me orientation when I needed it . I also wish to thank Dipl Ing Bernd K nig of the SUCO who arranged meetings field trips. and arranged the very important exchange of knowledge with German engineers possible . The work in the field would have been much more difficult without his assistance . I owe great gratitude to my parents Eleonore and Werner Posch Without their moral. support their patience and their generosity this study would not have been finished I want to. say them a big Thank You , ESP Production Optimization. 1 Abstract, The mature field Ras Fanar was equipped with Electrical Submersible Pumps ESP in 1996.
due to the low bottom hole flowing pressure BHFP Since then new wells in the mature Main. Field and in the smaller West Field which is separated by a fault have been drilled and. equipped from the start with ESP and the drilling program proceeds . The thesis shall examine the current ESP operation on the unmanned production platform B in. Ras Fanar producing in the Main Field and the West Field Possible optimization potential and a. sustainable economic shall be derived related to the actual forecast . Since data is not available centrally existing production data like water cut productivity index . BHFP and static bottom hole pressure SBHP are recorded and summarized The. measurements of BHFP by means of an Echometer are started if well conditions are suitable . The platform facilities and the design are evaluated and possible restrictions in the flow line or. equipment are investigated , On this basis new possibilities to increase efficiency are investigated and identified Although. there are no restrictions in regard to platform design the production data do not allow the. modelling of an Inflow Performance Relationship which is fundamental to design an ESP. layout Investigations revealed the production data measured by the offshore test separator. must be allocated and the reported gas oil ratio GOR has to be corrected Furthermore the. measured amount of gas is lower than reported by the company EGPC which processes the. TM, production onshore Using the program Pipesim by Schlumberger for Nodal Analysis an. improved Inflow Performance Relationship IPR based on the corrected data is determined . With this IPR the layout of the ESP can be recalculated well by well and optimization. possibilities are stated , Possible operation alternatives and the required budget are defined Based on the assumption. that the proposals can lead to an increase of pump run life and a production increase due to. improved gas handling the economic calculation showed the proposals will be economically. valuable compared by Net Present Value Pay out Time and a comparison of Cumulative Cost. of the operation modes , Author Thomas Posch Page 1. ESP Production Optimization, 2 Introduction, Ras Fanar is located in the western part of the Gulf of Suez 300 km South East of Cairo The.
field named Main Field was discovered and declared commercial in 1974 by a Shell BP . Deminex co operation It commenced production in 1984 with six wells drilled successfully from. platforms A and B , Figure 1 Geological structure1. Production began in January 1984 on natural flow and a peak production rate of 22 MSTB D . was achieved by October 1993 Production can be divided into four phases . Natural Flow with wells located along the main axis of the reservoir near the crest. except A3 which was located on the NW toe of platform A in a down thrown fault block . This period ended in May 1992 , Infill drilling of A4 and B4 along the main axis at the crest again using natural flow. The other wells were drilled in 1996 Artificial lift method had to be chosen due to the. relatively low pressure of the reservoir ESPs were installed and led to a production. boost as well as a rapid increase in water production afterwards This was attributed to. water coning due to the production increase However an integrated field study in 2002. showed the rising of the water cut as a result of a general increase of. oil water contact OWC due to reservoir properties . Southeast of the fault a new reservoir named West field was explored and production. started in June 2004 produced by six wells drilled from platforms A and B The main. fault completely isolates the West Field from the Main Field which has a separate. 2, aquifer too In 2009 A10 was drilled with deviations to West field PVT properties . Author Thomas Posch Page 2, ESP Production Optimization. 3 Theory, Many high volume wells are equipped with an Electric Submersible Pump ESP to lift the liquid.
and decrease bottom hole well flowing pressure The ESP is a multistage centrifugal pump and. applicable to a wide area of pumping operations The pumping system can be used for very. high liquid rates up to 64000 bbl d and small rates like 250 bbl d hence it is the artificial lift. system with the broadest producing range ESPs can be installed up to 13000 ft in any. deviations although there are special designs for horizontal applications Dogleg is a problem. because of its mobile shaft With the introduction of variable speed drives and newly designed. gas administration devices the ESP was able to broaden its area of application It was thus able. to manage up to 75 of gas volume fraction while furthermore becoming more flexible in its. 3, run life Improved production in deeper wells compared to sucker rod pumps and a small. footprint make it a good and highly efficient decision for offshore operations especially where. lifting gas for gas lift operations is not available although it is possible to combine the ESP with. a common gas lift system to improve reliability of the production . 3 1 Parts of an ESP, Placed on the surface is the Ammeter which records motor consumption electrical equipment. like the transformer and the switchboard The motor is connected with the pump and the. discharge head via the protector which protects the motor from the well fluid The discharge. head is mounted on the tubing at a certain depth in the well and hung on the wellhead . Figure 2 Typical ESP Installation4, Author Thomas Posch Page 3. ESP Production Optimization, The motor receives power through a cable with a three phase power source from the surface It. is operated at 60 Hz AC in the US in the rest of the world the power supply is usually 50 Hz . depending on national power grid standards But together with the later described VSD it is. possible to change the frequency and consequently the production rate As the motor must be. production onshore Using the program Pipesim by Schlumberger for NodalTM Analysis an improved Inflow Performance Relationship IPR based on the corrected data is determined With this IPR the layout of the ESP can berecalculated well by well and optimization possibilities are stated

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