Flow Assurance Assignment Design Engineering Essay

Flow Assurance Assignment Design Engineering EssayINTRODUCTIONThis bill describes about the design of subocean melody that transfers condensate from satellite platform to bear on platform. Designing of subsea melody and compiling this report exclusive design programme called Pipesim from Schlumberger is used. This programme used for designing and analyses for oil and gas production. And also analysis flow line and surface facility accomplishment to produce complete production constitution analysis.OBJECTIVESAvoid the formation of hydrateScreen the pipeline for severe riser bullet trainging to avoid its occurrenceSize a slug catcherOptimise the insularity of the pipelinesCarry out an corrosion and erosion analysisProvide engineering dataPIPELINE EXPLANTIONThe pipeline begins from satellite platform. From that platform it goes down to 400 feet into sea bed. Then pipeline laid for 6.8 miles on the sea floor. job is connected to riser and taking upto platform surface.Here that will be connected to water seperator and polyphase pump. The water seperator has to be 90 % efficiency and about polyphase pump there has three choices of 50, 100, and 200 HP with efficiency of 80 %. later multiphase pump comes down with riser about 400 feet and connected to pipeline.This horizontal pipieline laid for 5 miles.End point of this pipeline connected to riser and taken upto platform. From that platfrom, pipeline travels over the sea to touch on platform for 8 miles.Every technical datas atomic number 18 provided in appendix 2. Schematic sketch of pipeline is given below from Pipesimgrape DesignSelection of Internal Diameter of PipelineIn this project, we view as choice of pipeline ID size 8, 10 and 12.Condensate should have to reach in processing platform terminal with token(prenominal) pressure of 1000 psia. By doing analysis with three unlike IDs only a combined pipe size of 10 and 12 wind minimum pressure at processing platform. For 11,000 stb/d and 6000 stb/d, minimum arrival pressure is 1425 psia and 1,109 psia respectively got from graph. For multiphase pump decided to choose 50 HP. After selection of pump and pipeline size, these have to be checked in pressure temperature profile analysis for ensuring arrival pressure at processing platform above 1,000 psia ( Shown in appendix 1).Pipeline InsulationMinimum arrival temperature of condensate is 750F at processing platform. For attaining this comfort, the pipeline has to be insulted due to oestrus transfer loss. For finding out how much detachment have to use in pipeline through with(p) through by using pressure temperature analysis. For this insulation analysis is started with thickness of 0.25 and if its not satisfied, hence we have to increment 0.25 continuously. Thickness selection basis be done through by clicking in pipeline and enter set in heat transfer tab. There we potbelly enter pipe conductivity, ambient temperature and burial depth. After entering all these values we will get an insulation thickness of 6 and minimum arrival temperature as 81.50F. These arrival temperature satisfys both processing platform temperature and formation of hydrate ( Shown in appendix 1, figure 4).Formation of HydrateHydrates are form at high pressure and low temperature with combination of water and gas. Usually hydrates are formed inside subsea pipelines like plug formation. This can create major issues in oil and gas industry and resultant will be damaging of pipelines as well as processing facility. To hinder hydrates, inhibitors are used in pipelines. Widely used inhibitor is methanol. Hydrate formation condition provided in notes as followsTemperature Temperature 1500 psiaAfter taking amount of insulation in account for getting an arrival temperature above 750F is satisfied from above results. And keeping temperature and pressure in limited figures can control formation of hydrates in pipeline. From graph values (Shown in appendix 1, figure 4) above conditions a re satisfiedLiquid flow rate alike(p) pressure and temperature 6,000 stb/d 1425 psia 81.5 0F respectively.Liquid flow rate corresponding pressure and temperature 11,000 stb/d 1109 psia 100 0F respectively.Screening for severe riser sluggingNumber of factors is caused due to slug formation in riser. Some of them are given below.1. When Pipeline elevation is slightly downward before riser connection2. If fluid flow type is segregatedBy using PI-SS number riser slugging can be determined. Riser slugging can be conformed when number is less than 1.Then slug catcher have to be designed by using pipesim. PI-SS number can be calculated through report from pipesim. By using this manikin software can be generate two reports. Out file can be obtained from report file and flow map. Then re-run model and from that out file obtained. beginning PI-SS numbers are highlighted in out file. Riser slugging happens in flow line 1. This shows that slug catcher have to be design.Design of Slug cat cherThe slug catcher size is determined based on following three criteria. They areThe essential to hold the major slug in emergingNecessity for handling liquid comes out from pigRequired for store the slug where production rate is increased to 6000 to 11000 stb/dFollowing values are calculated from design. The output file is shown in Appendix and biggest one in one thousand slug size is originated. In this report it is calculated to 2211.168 feet. From the value we have got slug volume 2892.93 ft3.For second value taken from the liquid cleaned in front of a pig can be checked. It is clear that the minimum flow gives larger volume about 1801.512 bbl or 10114.73 ft3. Now calculated is liquid delayed when flow is increased 6000 to 11000 stb/d. This is dissimilarity in totality delay between the two flow rates. That means 3201.99 bbl 2459 bbl = 742.25 bbl = 4164.0225 ft3.Therefore the pigging volume is 10114.73 ft3 (Appendix 1, figure of speech 6,7,8). eating away and erosion analy siserosion and erosion are main concern in pipelines and this have to be kept very low. When erosion occurs, it reduces pipeline diameter. This has to be replaced before when it reaches to minimum value. Corrosion is occurred due to many reasons. This is major problem in oil and gas industry. The erosion analysis is done through following steps. Software analysis is done and the plot is got from erosion velocity ratio in Y axis and total distance from X axis. From graph flow is not exceeding value one which shows that there will be no erosion occurring in pipeline. ( Appendix 1, type 2)Engineering DataFlowline 1Flowline 2Flowline3Size of Pipeline ( Inches)101010Insulation Thickness666Riser size 10 inchesMultiphase pump 50 HPSlugging YesSize of Slug Catcher 10114.73 ft3Erosion or Corrosion NoConclusionPipesim is tool used for designing pipeline and for getting exact performance in system. In this project, for flowline 1 and flowline 2 are used 10 inch pipeline size. For flowline 3, pipeline size is 12 inch. After considering flowlines sizes we will achieve minimum arrival pressure and temperature at processing platform. Formation of hydrate was eliminated by proper insulation and multiphase pump power. Slugging is found in simulation for that reason we have provided slug catcher. Analyzing erosion and corrosion proved that there will be no erosion in pipeline. Generally project is successfully designed according to requirement.REFERENCEPipesim HelpClass notes from Dr Shuisheng. Hehttp//www.easycalculation.com/unit-conversion/volume-unit-converter.phphttp//www.slb.com/services/software/production_software/prod_analysis_diagnostics/pipesim.aspxE.D.Sloan, Clathrate Hydrates of Natural Gashttp//en.wikipedia.org/wiki/HydrateAPPENDIX 1 encrypt 1 Pressure TemperatureFigure 2 Erosional velocity ratio- Total distanceFigure3 Pressure Vs Total distanceFigure 4 Temperature Vs Total distanceFigure 5 Pressure Vs Total distance ( without flow rate)Figure 6 PI-SS Numbe rFigure 7 Largest 1/1000 slug lengthFigure 8 Liquid by sphere number