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HomeMy WebLinkAboutMarch 30 Multimetering · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . - March 30, 2007 Jane Williamson Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Art Copoulos Division of Oil and Gas Department of Natural Resources 550 West ih Avenue, Suite 800 Anchorage, AK 99501 Robynn Wilson Tax Division Department of Revenue 550 West ih Avenue, Suite 500 Anchorage, AK 99501 Re: Application Report for.EMSTM Multiphase Metering System Amendment to CO 547 - Prudhoe Bay Oil Pool Amendment to CO 548 - Endicott Oil Pool Amendment to CO 550 - Milne Point Oil Pool Amendment to CO 551 - Northstar Oil Pool Amendment to CO 559 - Put River Oil Pool Amendment to CO 570 - Raven Oil Pool Amendment to CO 402A - Badami Oil Pool Dear Ms. Williamson, Mr. Copoulos and Ms. Wilson: RECEIVED APR 1 1 tU07 Alaska Oil II Gas Cons. Convnission Anchorage BP Exploration (Alaska) Inc. (BPXA), Operator of the fields shown in Appendix 2 öf the attached Application Report, hereby requests authorization to use a portable multi- phase measurement device, as described in the Application Report, for the purpose of well testing and production allocation within BPXA operations conducted in the Prudhoe Bay Oil Pool, Endicott Oil Pool, Milne Point Oil Pool, Northstar Oil Pool, Put River Oil Pool, Raven Oil Pool, and Badami Oil Pool pursuant to 11 MC 83.371, 20 MC 25.228, and 20 MC 25.230. The report describes the design, the expected performance and the anticipated applications of the Schlumberger PhaseWatcher VX™ Multi-Phase Flow Meter as a self contained unit and in combination with FMC Technologies CDS-Gasunie separator for well testing in these BPXA operations. BPXA also requests an amendment to each of the aforementioned AOGCC Conservation Orders (CO) governing each pool in order to allow for the use of multi- phase meter technology as described in the Attached Report. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . BPXA has conducted extensive study of multi-phase metering technology. In September 2003 BPXA conducted a field trial in Prudhoe Bay of four (4) different kinds of multi-phase meters.· These meters were tested in a series and were statistically evaluated .for accuracy, precision, and repeatability against a known standard two- phase separator. Based on the result of this test and other experience gained throughout the world, BPXA has gained an improved understanding of the applicability and limitations of multi-phase metering to North Slope production wells. BPXAis proposing two configurations of the PhaseWatcher VX™. The first configuration is a stand alone PhaseWatcher VXTM (hereafter referred to as Vx) meter, manufactured by Schlumberger, for testing well streams with gas volume fraction (GVF) of 90% or less. The second configuration is a VX™ in combination with a CDS separator when the GVF in the well streams exceeds 90%. In the later configuration the metering skid is designed to remove gas from the inlet to the multiphase meters by employing a proven cyclonic separator developed by CDS Engineering of The Netherlands. This separator is known as a Gasunie and it is capable of high degree of separation efficiently as compared to conventional separation technology. With a high level of confidence in the removal of the gas from the well streams, a set of multi phase meters, manufactured by Schlumberger, are used to accurately measure oil, water, and gas flow rates. Field testing of these units is not planned given the extensive field testing of the Gasunie separator for the FMC Technologies Enhanced Multiphase System™ (EMSTM) will have already been .completed and given the testing of the Schlumberger PhaseWatcher VX™ during the September 2003 BPXA field trial in Prudhoe Bay. The proposed multi phase metering system is designed as either a mobile unit or stationary unit. The mobile unit will be operated by Schlumberger who has extensive North Slope experience and extensive worldwide experience in mobile well testing. The stationary or permanent unit will be installed at a well pad and will be operated by BPXA personnel similar to current pad test separator facilities. The AOGCC.Application "Report submitted herein compiles the data and literature that were used to qualify the design and establish performance levels for the Schlumberger PhaseWatcher VX™ Multi-Phase Flow Meter as a self contained unit and in combination with FMC Technologies CDS-Gasunie separator. This document was prepared following the "Guidelines for Qualification of Multiphase Metering Systems for Well Testing" issued November 30,2004 by the AOGCC. Approval of this request will advance the use of multi-phase technology for North Slope production measurements. It will allow BPXA to gain operational experience with this meter while demonstrating multi-phase metering technology can provide allocation well tests comparable to a conventional portable separator. It will also free up limited portable separator units, currently used for well production allocation testing, to do flowback jobs on new production wells and after wellwork. Additional benefits from a portable multi-phase meter includes improved testing frequency (faster rig-up, no stabilization period required), production fingerprinting (no vessel dampening), reduced 2 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . HSE risk (smaller footprint, fewer personnel, no vessel), and opportunity for lift optimization. Should you have any questions regarding this request, please don't hesitate to contact Jerry Brady of my staff at 564-5291. We would be pleased to provide additional information on this subject at your convenience. Thank you for your assistance. Sincerely yours, ~c?~ Gordon Pospisil GPB Waterflood Manager Attachment Cc: Frank Paskvan, BPXA Scott Digert, BPXA Diane Richmond, BPXA Mark Weggeland, BPXA John McMullen, BPXA Sherri Gould, BPXA John Cyr, BPXA Jerry Brady, BPXA Alan Mitchell, BPXA Sonny Rix, ExxonMobil Dan Kruse, CPAI G. M. (Gary) Forstoff, Chevron USA Scott Millington, Anadarko Daniel "Toby" Osborn, Doyon Ltd Mathew Fagnani, Nana Glenn Fredrick, Unocal Ignacid Herr~re, Murphy Exploration 3 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . AOGCC "Application Report" for PhaseWatcher VX™ Multiphase Metering System BPX - Alaska March 30, 2007 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . Table of Contents 1. Introduction................................................................................................................... .........2 2. Proposed Applications ............. .................. ........................ ............................ ............ ............. 2 3. System Design and Measurement Strategy............................................................................ 3 4. Accuracy and Measurement Methodology ........... ........................... ....................................... 7 5. Performance of the Phase Watcher Vx Meter in Flow Loops................................................ 7 6. Gas Measurement Accuracy for the HG Multiphase Metering Skids ..................................10 7. CDS Separator Performance... ................................... ................... ....................... ................. 12 8. High GVF Multiphase Metering Skid - System Control......................................................12 9. Factory Acceptance Tests (FAT).......................................................................................... 13 10. Field Maintenance and Periodic Calibration ......................................................................14 11. List of Appendices................................ ........................................... ................................... 14 1 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . AOGCC "Application Report" for PhaseWatcher VX™ Multiphase Measurement System 1. Introduction This document describes the design and anticipated performance of PhaseWatcher VX™ multiphase metering skids designed for well testing of wells in operating areas shown in Appendix 2. The proposed metering skids use the stand alone PhaseWatcher VX™ (hereafter referred to as Vx) meter, manufactured by Schlumberger, for testing well streams with gas volume fraction (GVF) of 90% or less and in combination with a CDS separator when the GVF in the well streams exceeds 90%. In the later case the metering skid is designed to remove gas from the inlet to the multiphase meters by employing a proven cyclonic separator developed by CDS Engineering of The Netherlands. This separator is known as a Gasunie and it is capable of high degree of separation efficiently as compared to conventional separation technology. With a high level of confidence in the removal of the gas from the well streams, a set of multiphase meters, manufactured by Schlumberger, are used to accurately measure oil, water, and gas flow rates. The description of each skid is provided in this report. This report also compiles the data and literature that was used to qualify the design and establish performance levels for the Vx skids. This document is to be submitted to Alaska Oil and Gas Conservation Commission (AOGCC) as an "Application Report" to obtain their approval for using this multiphase metering system as an alternative to conventional gravity based test separators for well testing. The "Guidelines for Qualification of Multiphase Metering Systems for Well Testing" issued by AOGCC (included in Appendix 1), requires operators to submit this "Application Report" before new metering systems are used for production well testing and allocations. Section 3 of the AOGCC document outlines the type of information that the application has to provide. This BPX "Application Report" provides the information that is requested in the Section 3 of the AOGCC document. 2. Proposed Applications The proposed multiphase metering systems are designed to be used either as permanent wellhead installation or mobile systems deployed in a field. Table 2A-I in Appendix 2 shows the wells and production horizons in which BP is the operator or has working interest that may use the proposed multiphase metering unit. This Table also shows the working interest owners. All parties with working interest, royalty ownership, as well as the Alaska Department of Revenue will be notified about the use of the metering system when the application of the metering system affects such interests. The proposed application will use the multiphase metering skids for production allocation. In the event that the proposed multiphase metering scheme does not produce the expected accuracy, we will revert to use the conventional well testing techniques. The allocation methodology currently practiced will continue and would not be affected by the multiphase metering system. 2 - 15 I I · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 3. System Design and Measurement Strategy During the summer of 2003, BPX - North Slope Operations conducted an extensive field test of four multiphase metering systems at their V-Pad. These tests were carried out to evaluate the performance of these systems for testing wells in NS operating areas. The four meters tested in these field trials use a wide range of measurement techniques and strategies, which increased the probability of finding meters that would qualify for measuring the production from various fields. The four meters tested included Agar's MPFM401, FMC's TopFlow, Roxar's 1900 VI and Schlumberger's Phase Watcher (Vx29). North Slope well testing provides numerous obstacles to the successful application of multiphase measurement techniques. These obstacles include varying crude quality from three different horizons, high gas-volume fractions (85%-99% GVF), and a wide range of water cuts (0-100% We). Monitoring is further complicated by the fact that a high percentage of the wells are on artificial lift with either gas-lift or jet pumps powered by water. In either case artificial lift greatly increases the GVF or WC of the fluid stream measured at the surface. The results of the tests showed that all four metering systems qualified in specific or limited operating areas. In general, the high GVF applications were much more problematic for the meters and resulted in a significantly higher measurement error. Wells with high gas lift rates, or in the Gravity Drainage (GD) portion of the field, fall into this high GVF flow regime. Four applications for these meters were identified. They included individual well deployment (usually for new developments), supplementation of current well test separators; a mobile test unit; and replacement of existing test separators. This report deals with the application of multiphase metering for mobile tester and as replacement for existing test separators. Based on the experience gained from the above mentioned field tests, BPX has developed two configurations of a metering system that is compact, can be installed in well housing, and can also handle high GVF measurements. This approach to multiphase metering incorporates the multiphase metering techniques, as well as, a unique but tested separation technology to achieve measurement capabilities that are specifically suited for high gas fraction production streams as well as production streams with lower gas fractions. The configuration for high GVF (HG) and low GVF (LG) skids are shown schematically in Figures 1 and 2. For the HG configuration, as shown in Figure 1, flow stream from the well is directed into a cyclonic gas liquid separator made by CDS-Gasunie that would convert the initial high GVF stream into liquid rich and gas rich streams. The system is designed so that the liquid rich leg will have a GVF of less than 90%. Parallel liquid measurement lines with 29 mm and 52 mm Vx multiphase meters manufactured by Schlumberger will provide multiphase measurements. This HG configuration can also handle well head streams with GVF:::;90% through bypassing the CDS separator as shown in Figure I.Alternatively, as shown in Figure 2, a skid made up of the Vx meters only is proposed to test production streams with GVF:::;90% without the need for CDS separator. The HG configuration skid is also designed to produce a low liquid content gas stream. Gas rates are measured by a Vortex type gas meter. Figure 3 shows the layout of the HG skid. Table 1 describes the measurement ranges for each of the proposed HG and LG configurations. The flow rates of individual components of each system as well as the total liquid and gas flow rate capacities for each configuration are listed in Table 1. The specific 3 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · combination of liquid and gas flow rate available for an application is determined by the operating envelopes for the 29 mm and 52 mm Vx meters shown in Figures 4 and 5. These flow rates may also be constrained by the flow velocity in the associated piping and flow lines connected to the meter. Both configurations are to provide water cut measurements in the range of 0-100%. The accuracy performance of the skids for measuring oil, water and gas flow rates are detailed and discussed in the following sections of this report. Figure 1 - Block diagram of the High GVF multiphase metering skid Figure 2- Block diagram of the Low GVF multiphase metering skid 4 - 15 · · · '. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Table I - Flow Rate Performance Range for the Proposed Meter Configurations Configuration Liquid flow Operating Gas Flow Ran e Envelo Rates STD BPD MMSCFD VX 29 400 13,000 Fig. 4 0,025 0.23 0.5 4.6 Vx 52 ],200 40,000 Fig. 5 0.065 0.685 1.3 13.7 Tota] Fluids in Liquid Leg 400 53,000 0.5 18.3 Additiona] Gas Rate of 0.010 0.75 0.19 15.1 Vortex Meter- 3" Total High GVF Ranges 400 0.2 33.4 Low GVF - Fig. 2 Vx29 400 13,000 Fig. 4 0.025 0.23 0.5 4.6 Vx 52 1,200 40,000 Fig. 5 0.065 0.685 1.3 ]3.7 Total Low GVF Ranges 400 53,000 0.5 18.3 29 mm 3nd 52 rrm Vx Multi-Phue Mehrs Figure 3 - This Drawing depicts the HG metering system layout. 5 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 0pêralngEnveIGp. PhaSêW.ech.r Vx 21 mm 20000 2000 0.1 0.2 0.3 0.4 0.5 0.6 0.7 08 1??oo '1??oo I 114000 )12000 II 10000 15 ¡ )??oo joooo ' I! 4000 ! lie.. _ A8te: IllllMeuft "'" _ (line __I Figure 4 - Operating envelope for the PhaseWatcher Vx 29 mm at 300 psi. The orange rectangle corresponds to the additional gas capacity with the Vortex meter and CDS separator. Op.ratmg œnv.IGpe Pf'aaseWatcher Vx 52 mm 60000 '50000 I 14??oo I 130000 1\1 ) ~ 20000 j 110000 .... 0.1 0.2 03 OA 05 O. a_plew A8te:lllllMeuft "'" ell. (line __I 0.7 0.8 Figure 5 - Operating envelope for the PhaseWatcher Vx 52 mm at 300 psi. The orange rectangle corresponds to the additional gas capacity with the Vortex meter and CDS separator. 6 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 4. Accuracy and Measurement Methodology The specified accuracy for each metering configuration to measure liquid, gas and water cut is shown in Table 2. These accuracy levels are applicable to the range of flow rates shown in Figures 4 & 5. Table 2 - Fluid Measurements and Water Cut Accuracy Item Accurac Li uid Flow Rates Gas Flow Rates-Hi h GVF Confi uration shown in Fi .1 Gas Flow Rates- Low GVF Confi ration shown in Fi .2 Water Cut To obtain these accuracy levels the components of the metering system must perform the following major tasks: 1. The CDS separator must deliver liquid with GVF:::; 90% to the Vx multiphase meters in the liquid leg. 2. The Vx meters should deliver the ± 2.5% liquid rate, ±1O% gas rate, and ± 2.5% water cut accuracy when operating at a GVF :::; 90%. 3. The CDS separator must also deliver Type 1 gas with low liquid content (Lockhart Martenilli Number:::; 0.03) to the gas rich leg. The combined gas measurement rate from the Vortex meter used in the gas rich leg and the Vx meters in the liquid rich leg should provide ±6% to ±8% gas measurement accuracy. 4. The control system and control philosophy operating the separator must contend with slug flow conditions expected in well tests and sustain the GVF levels, described in items 1 and 3 above, in the liquid and gas legs. Data to support that the above requirements can be met are presented in the following sections. 5. Performance of the Phase Watcher Vx Meter in Flow Loops Appendix 3 contains literature describing the principle of operations of the PhaseWatcher VX™ meter. This section provides flow loop performance and field verification data for PhaseWatcher VX™ multiphase flow meters. The manufacturer's specified uncertainties for the PhaseWatcher VX™ when operated in liquid measurement mode at 0-98% GVF is shown in Table 3. The 0-90% GVF accuracy levels are used for the proposed applications. Table 3 - Phase Watcher Vx Accuracy Specifications Accuracy Liquid Rate - Volume WLR(%WC) Gas Rate @ >300 psi Gas Rate @, <300 psi 0-90% GVF 2.5% - Relative 2.5% Absolute 5%- Relative 10%- Relative 90-96% GVF 5% - Relative 2.5% - 5% Absolute 5%- Relative 15%- Relative 96-98% GVF 10% - RelatÎve 5% - 8% Absolute 5%- Relative 15%- Relative 7 - 15 i ~ · · · · · · · · · · · · · · · · · · · .' · · · · · · · · · · · · · · · · · · · · · · · . . Data to validate the accuracy performance of the Vx meter was collected from three sources as shown in Table 4. The sources include SINTEF flow loop in Trondheim, Norway, Frank Mohn flow loop in Flatøy, Norway and the BPX field tests at GPB in Alaska. Table 4 also summarizes the fluid properties and flow rates as well as the reference meters used for each evaluation program. BPX - GPB Deadhorse (August, 2003) Table 4 - Summary of Flow Loop and Field Test Conditions Exxsol (SG. = 0.8; viscosity 1-2 cP) Fresh water Nitrogen Pressure Reference Meters bara Oil & Water: 7-9 V-Cone meters, 4 sizes Coriolis (mass, density) Gas: V-Cone meters ( 4 sizes) Venturi meter Flow Rates Liquid: 2.5- 70 1113/h (380-10570 bpd) Gas: 6-280 m3/h (5-237 Mcfd) Liquid: up to 450 m3/h (68,000 BPD) Gas: up to 1600 Am3/h (1,354 Mcfd) Liquid: 500-3300 BPD Gas: 0.3-7.8 MMSCFD WC: 10-92% Figures 6-8 show the 2-phase plots of the test loop data for we, liquid and gas flow rates. The solid green and pink lines on each of these plots represent the manufacturer's specified uncertainties for we, liquid and gas rates with 90% confidence level. These accuracy levels are based on the meter performance over the range of 0-90% gas volumetric fraction (GVF). The data shown in Figures 6-8 indicate that vendor specification for accuracy shown in Table 3 can be supported by test loop results. Location - Fluids Date Frank Mohn Flow Loop, Flatøy, Norway April, 2003 - June, 2004 Sintef, Trondheim, Norway April, 2004 Naphta SG 0.716, Viscosity 0.3 cP Liquid: 1-104 Fisher Turbine meter Nitrogen Density = kg/m3 due Naphta vapor Gas: FlowSic 600 Ultrasonic meter (50-1600 m3/hr) Rosemount Vortex meter (5- 245 m3/hr) 1.58 to WH Fluids Crude Viscosity: 16-56 cp Produced Water: SG=1.0123 -1.0178 Gas: SG= 0.654-0.754 Portable Test Separator 20- 50 Liquid: MicroMotion Coriolis meter Gas: Halliburton Turbine meters Water cut: Phase Dynamics water cut meter 8 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · PhaseWatcher Vx 52mm Flow Loop Data Water Liquid Ratio, absolute error, 0 - 90% GVF 10.0% 7.5% --------- 5.0% 2.5% 0:: 0.0% ...J š: o Yo -2.5% -5.0% -7.5% -10.0% ----,------ ì------ I I ------- - --------- GVF Figure 6 - Water-Liquid Ratio (WLR) absolute error as a function of GYF, flow loop tests. There are a total of 96 data points. 10.0% 7.5% 5.0% g 2.5% <I> .$ ~ :;:: 0.0% ,g "0 'S cr -2.5% ::¡ -5.0% -7.5% -10.0% PhaseWatcher Vx 52mm Flow Loop Data Liquid volumentric flow relative error, 0 - 90% GVF - -- - ,- - - - - -- - - - - - - - - - --1------ I ,- ---- " " GVF Figure 7 - Liquid volumetric flow rate relative elTor as a function of GYF, How loop tests. There are a total of94 data points. 9 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 15% PhaseWatcher Vx 52mm Flow Loop Data Gas volumetric flow relative error, P'::' 15 bara, 0 - 90% GVF Sinter, 26 bar Sinter, 40 bar Sintef, 85 bar .. Sintef. 15 bar .. 10% .. 5% g .. " .. .. $ ~ 0% ;t 00 2Q% 40% 60% 80% 0 ¡¡:: 1/1 .. C) -5% .. -10% -15% GVF Figure 8 - Gas volumetric flow rate relative error at pressures> 15 bara as a function of GVF, flow loop tests. There are a total of 37 data points. Table 5 shows the results from field tests conducted by BPX at the GPB V -pad. In these field tests the performance of the PhaseWatcher VX™ meter was indexed against the ASRC portable well test separator. For the 13 field tests with GVF in the range of 50-90% and WC in the range of 10- 75% in the well head stream, the accuracy level for the pay fluids - i.e. oil and gas flow rates - are shown in Table 5. On the average the Vx meter produced liquid flow rates within ± 4% of the test separator. The data presented in this section indicate that the Vx meter can meet the performance capabilities listed in Table 2 and when its performance is indexed against an acceptable "well attended" test separator, the Vx is expected to produce on average oil flow rate accuracy levels within ± 5% of a test separator. The gas flow rate accuracy levels that are expected to be within ±5 to ± 1 0 % of the test separator. 6. the HG Skids The gas rates the gas rich leg of the HG metering configuration shown in Figure 1 will be measured by a 3" Vortex meter. Figure 9 shows the uncertainty as a function gas velocity and liquid loading for a vortex meter similar to the one to be used in the HG multiphase metering skid. For liquid content of less than 1.0%, expected in the gas rich leg of the CDS separator, the relative uncertainty is better than ± 8% of the reading. This accuracy can be attained over a wide range gas velocity (gas flow rates) 10 15 · · · · · · · · · · · '. · · · · · · .' · · · · · · · · · · · · · · · · · · · · · · · · · . . Table 5 - Results from the BPX- GPB Field Tests for GVF Range of 0-90% Liquid Reference Oil flowrate flowrate Gas flowrate Water cut W/C GVF value error value error value error value error abs % % stb/d rei % stb/d rei % MMscf/d rei % % % 13 91 1735 -4 1778 -8 3.4 5 2 -4 33 90 1663 -7 2490 -5 2.7 9 33 1 69 89 1025 -10 2664 -10 6.6 5 62 0 73 89 803 14 2578 3 2.9 -1 69 -3 70 89 747 -15 2485 -9 6.0 11 70 2 29 88 1882 -6 2116 -5 2.7 11 11 0 30 88 1485 -4 2121 -4 2.8 9 30 0 14 88 1351 -11 1934 -10 3.2 8 30 1 14 88 1755 -11 2019 -10 3.1 10 13 0 16 87 1868 -5 2172 -4 2.6 10 14 1 42 76 2126 9 3256 1 1.3 7 35 -4 47 59 1138 24 1977 19 0.3 11 42 -2 42 54 865 -4 1386 -3 0.2 16 38 1 Average-all tests -2 -4 8 -1 -21 ?f, ...... ... g 15 W j 10 LL :; C) 5 30 25 -e- Dry -G-0.OO5 0.10% -tr0.012 0.25% -*- 0.024 0.60% -è- 0.047 1.00% ..... 0.12 2.50% -+- 0.24 5.0% o ~" ;., ~)/ "'~"lI / ''t ( . ~~----o ~------~..,_~ x ¿ . " .- = ____ 19 _____ -- ~ . ,.. X -----7< ·5 1 5 10 15 21 25 30 35 Superficial Gas Velocity (mla) Figure 9- Vortex meter error as a function of gas velocity and liquid volume fraction at 450 psig (data from National Engineering Lab. UK, joint industry project). The amount ofliquid in gas varied from 0.1 % to 5% in these tests. The data for 0.5% to I % liquid content was used to calculate the gas rate uncertainty for the HG skid configuration. 11-15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . The overall gas measurement accuracy in the HG configuration skid (see Fig.!) is a combination of measurement accuracy in the gas rich leg (Vortex meter) and the gas accuracy from Vx meters in the liquid rich leg. The procedure used to obtain the overall gas accuracy for the system is described in Appendix 4. The gas rate measurement accuracy for the HG metering skid is dominated by the accuracy measurement in the Vortex meter as most of the gas is diverted and measured in the gas rich leg. Assuming a diversion rate of 95% or higher (see Table 6), well within the capability of system as described in the next section, the overall accuracy for the gas is calculated (Appendix 4) to be about 5-8 %. 7. CDS Separator Performance Appendix 5 provides literature describing the principle of operation and prior field applications of the CDS-Gasunie. The special configuration employed in design of the separator, described in Appendix 5, enables this device to achieve greater than 98% rate of gas removal. Data in support of this claim is presented in Table 6. The data shown in Table 6 was obtained by CDS Separation Technologies in their flow loop in Anthem, The Netherlands. The test arrangement used was similar to the schematic shown in Figure 1. However a TopF10w multiphase meter made by F10wSys was used in these tests instead of the Vx meter. The measurements for liquid rates were made by liquid ultrasonic meters. The gas rates were measured with a Vortex meter. The mixed fluids were allowed to travel down 25 feet of flexible 4" hoses to allow the flow regime to develop. The water cut in the flow stream ranged from 0 to 68%.The inlet stream with a GVF level of 99% was diverted to a liquid rich stream with a GVF:::; 36% at the TopF10w meter. In configuring the HG skid with Vx meters, we have assumed a GFV:::; 90% for the liquid rich stream entering the Vx meter. The CDS tests have shown that the Gasunie separator is capable of delivering GVF as low as 36% to the Vx meter. At this level of gas volume fractions, the Vx meter should be able to deliver liquid rate and water cut accuracy as shown in Table 2. Table 6 - liquid removal efficiency of the CDS separator Oil Flow Water Liquid Gas Gas Gas wc Gas Rate Flow Flow Flow Fraction Fraction Removal Rate Rate Rate at at Efficiency Separator TopFlow Inlet BPD BPD BPD MSCFD GVF GVF % 227 151 378 191 99% 12% 40.0 98.73% 151 227 378 191 99% 36% 60.0 98.40% 272 106 378 191 99% 19% 28.0 98.63% 151 302 453 170 99% 23% 66.7 98.63% 302 151 453 170 99% 23% 33.3 98.07% 453 0 453 170 99% 32% 0.0 98.09% 8. High GVF Multiphase Metering Skid - System Control The control philosophy used in the system is described in Appendix 6. A typical P&ID diagram for the HG mu1tiphase metering skid in Appendix 7 shows details of the control devices. 12 - 15 · · · · · · · · · .. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . Due to the large variations in gas and liquid flow rates, separate control valves have been placed in the gas and the liquid lines. The function of these valves is to regulate the pressure balance over the Gasunie cyclone separator so that dry gas enters the vortex meter in the gas- rich line of the vessel and that sufficiently degassed liquid enters the multiphase meters in the liquid leg over the complete operating envelope of the unit. The benefit of degassing the liquids as much as possible is that the liquid measurement accuracy of the Vx meter improves with reduction in GVF. The intention is to regulate these valves by use of the guided wave radar transmitter located on the top of the cyclone separator in the following methodology. A. At start up - The gas valve opening will be 0% and the liquid valve opening 100%. In all scenarios the liquid control will be the source of primary control. The reason for this is to minimize the total pressure drop over the skid. B. High Liquid / Low Gas regime - The system will then try to regulate a liquid level at a 25% set point by closing the liquid control valve. If the liquid valve is more than 70% open then the gas valve will start to close until the liquid valve opening reduces below the 70% threshold. The reason for applying a 70% opening maximum is that if a liquid surge enters the vessel there is valve capacity left to help in the disposal of this liquid. Otherwise the cyclone separator would soon fill with liquid and the liquid is carried over to the gas leg, thus affecting the accuracy of the gas measurement. C. Liquid / High Gas regime - The system will try to regulate a liquid level at a 25% set point by regulating the liquid control valve with the gas valve fully open. Should the dP over the Venturi in the Vx meter become less than the minimum value then the 25% set point of the level transmitter shall be ignored. In this scenario, the dP over the Venturi will become the controlling parameter. The reason for this is to increase the Reynolds number in the Venturi to ensure that no loss of liquid measurement accuracy occurs. D. To achieve the minimum pressure drop over the Venturi of the Vx at the lower liquid flows, some gas needs to pass through the meter. During this condition, depending upon the particular fluids being processed the level in the cyclone separator may fall below the 25% set point. E. In above control mode it is likely that the liquid control valve will be nearly closed due to the higher dP over the gas leg. If a liquid slug arrives then there is a risk that the separator will rapidly fill up and therefore the gas vortex meter may become flooded with liquid. To overcome this scenario should the liquid level rise above 50% in the separator the liquid valve will be signalled to open. At the same time the gas control valve will start to close. Once the rise in liquid level is arrested then normal control will be re-established, initially by opening the gas control valve followed by the liquid control valve. 9. Factory Acceptance Tests (FAT) Factory acceptance tests will be conducted per the guidelines listed in Appendix 8. The FAT will include the following functional component tests: 13 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . · Pressure test of all the piping and the separator. · The functionality of the control valves will be checked · The functionality of the level indicator will be checked · The flow meters (Vortex and Vx) will be checked. · PhaseWatcher Vx flow meter FAT is performed at the 3-Phase Measurements flow loop in Norway. · Functionality of all the manual valves will be checked · Functionality of the "check valve" will be checked · Functionality of the SDV will be checked · Functionality of the choke will be checked · Complete assembled skid testing (including Vx and all other components and piping) can be accomplished on a flow loop to be designated. In addition liquid and gas flow rate tests will be conducted to check the performance of the skids. The test conditions will be guided by both the operating constraints of the test meter and of the flow facility. In general, however, the overall range of test conditions will cover a wide range of GVF from 80% up to approximately 97%, and water cuts across the range 10% to 80%. The total liquid flow rate will be varied across a range suitable for the meter sizes selected. The rates used in the FAT evaluations will be such that the over-all expected velocities and GVF values will simulate the values of these parameters in the field. For Vx, this requirement will be included in the FAT at the factory. 10. Field Maintenance and Periodic Calibration Periodic maintenance of the skids is required. These items are identified by Schlumberger Report and are listed in Appendix 9. Periodic calibration of the Vx systems will be required when fluid properties - i.e. oil gravity or composition and produced water salinity changes. These calibrations will follow the procedures also described in Appendix 9 as a guide. 11. List of Appendices Appendix 1 - AOGCC REPORT REQUIREMENTS Appendix 2- FIELDS. POOLS. AND WELLS Appendix 3 - PHASEWA TCHER VX PRINCIPLE OF OPERA TION Appendix 4 -OVERALL GAS ACCURACY Appendix 5 - CDS SEPARA TOR Appendix 6 - HG SKID CONTROL SYSTEM ApIJendix 7 - HG SKID P&ID AIJIJendix 8 - FACTORY ACCEPTANCE TEST AIJIJendix 9 - PERIODIC CALlBRA TlON 14 - 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . GUIDELINES For QUALIFICATION OF MUL TIPHASE METERING SYSTEMS FOR WELL TESTING November 30, 2004 Alaska Oil & Gas Conservation Commission www.aoacc.alaska.aov Prepared by: Parviz Mehdizadeh, Ph.D. Production Technology Inc. Jane Williamson, P.E. Alaska Oil and Gas Conservation Commission · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . Guidelines for Qualification of Multiphase Metering Systems for Well Testing Table of Contents 1.0 Purpose........ ................................. ........................... ................ 3 1.1 Organization of the AOGCC Guidelines........................... 4 1.2 "Principles of Multiphase Measurements" ........................ 4 2.0 AOGCC Administrative Process ............................................5 2.1 Application Contents-General.......................................... 5 2.2 Review Process............................... ................................ 5 2.3 AOGCC Decision ............................................................. 6 3.0 Qualifying Multiphase Metering Systems for Well Testing. 6 3.1 Application Contents........................................................ 6 3.2 Accuracy Expectations..................................................... 8 4.0 Validation of Meter Performance in Field............................ 10 4.1 Field Verification ............................................................ 10 4.2 Field Test Plan............................................................... 11 4.3 Reporting the Field Results............................................ 13 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 1.0 . . Guidelines for Qualification of Multiphase Metering Systems for Well Testing Purpose 1.0.1 The use of multiphase meters for well testing is gaining increased support within petroleum production operations. It is anticipated that Alaskan operators will be pursuing their use in well testing and field production allocation. 1.0.2 Multiphase meters are devices that measure oil, gas, and water flow rates of a well stream with or without partial separation of these components into individual phases. Multiphase metering techniques were developed as an alternative to measurement methods using two and three phase gravity based test separators. 1.0.3 The Alaska Oil and Gas Conservation Commission (AOGCC) is authorized to evaluate and approve methodology and equipment utilized for well testing and allocation of production in Alaska per regulation (20 MC 25.230) and Alaska Statute (Sec 31.05.030(d)(6». 1.0.4 Industry standards and recommended practices are in place for test separator based single-phase gas or liquid metering. However, there are no standards and few guidelines available for multiphase meters. 1.0.5 Considering that the multi phase metering technology is relatively new and that accurate well test metering has both financial and reservoir management importance, the AOGCC will require approval prior to use of mutiphase meters to satisfy requirements of 20 AAC 25.230. These guidelines are provided to train and direct the operator and AOGCC on how to qualify these new measurement techniques. 1.0.6 These guidelines address both wet gas and multiphase metering systems for use in well testing. Custody transfer applications are regulated under 20 MC 25.228 and are outside the scope of these guidelines. 1.0.7 The materials described in the "Guidelines for Qualification of Multiphase Metering Systems for Well Testing" were developed to serve the following objectives: · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 1.0.7.1 As a guide for the operator in submitting a request to apply new multiphase metering techniques for well testing and allocation of production, 1.0.7.2 As a guide and process tool for reviewing operators' requests for qualifying a multiphase metering system for well testing, and 1.0.7.3 As a training tool for AOGCC personnel who will be involved in the assessment of the multiphase technology for well testing. 1.1 Oraanization of the AOGCC Guidelines The remaining sections of this document are organized as follows: Section 2 AOGCC Administrative Process: This section outlines the overall administrative process that will be followed for certification of a multiphase metering system. Section 3 Qualifvinq Multiphase Meterinq Systems for Well Testinq: AOGCC expectations of documentation to accompany the application for pre-certification or certification of the proposed multi phase metering system are described. Section 4 Validation of Meter Performance in Field: In some instances, the AOGCC may require field verification of meter performance prior to approving use. This section provides recommendations and requirements for conducting these field tests to gather information required by the AOGCC for qualification of the multiphase metering systems and outlines requirements for documentation of the field test results. 1.2 "Princioles of Multiohase Measurements" A separate document, "Principles of Multiphase Measurements", is concurrently issued with these guidelines. This document provides basic information on multiphase meters, a list of references for further education on multiphase meters, a list of terms and definitions, and installation suggestions for multi phase meters. It is recommended that the novice review the "Principles of Multiphase Measurements" document in conjunction with these guidelines. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 2.0 2.1 2.2 AOGCC Administrative Process 2.0.1 This section describes the AOGCC review and decision process that will be used in processing requests and summarizes required application contents. Section 3 provides further detail on required application content. 2.0.2 AOGCC approval will be required prior to use of multiphase meters in well rate determination to satisfy requirements of 20 MC 25.230. 2.0.3 AOGCC approval will not be required for minor changes (such as meter size or minor technical upgrades that will not deteriorate performance) of previously approved meter systems. However, if production characteristics change significantly (such as large changes in GVF and water cut) from the initial approved application, a new application must be submitted. Approval will not be required for use of multiphase meters if the well test results are not used to satisfy monthly production reporting and well test allocation requirements of 20 MC 25.230. 2.0.4 The AOGCC will only approve use of a multiphase meter system by Commission order adopting or amending pool rules under 20 MC 25.520 or, in the Commission's discretion, by administrative approval where provided under an existing order. However, in the case of a pool for which pool rules have not been adopted and for which the applicant demonstrates that pool rules are not yet needed, the Commission will consider an ad hoc application for an order under 20 MC 25.540 approving use of a multiphase meter system. Aoolication Contents-General The application must include a cover-letter request with a summary description of the proposed meter system, discussion of how the proposed meter will be used for the determination of well production within the allocation system, reference to the conservation orders which prescribe the rules for development and operation of the pool, requested changes to the conservation order, and other documentation described in Section 3. Review Process 2.2.1 It is recommended that the applicant contact the AOGCC early in the evaluation process to decrease the ultimate time to process applications and to reduce the risk of later costly revisions to plans. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 2.3 3.0 3.1 2.2.2 If the application is deemed complete, AOGCC will notice the application for public comment and potential hearing, unless handled by administrative approval. By regulation, a minimum of 30 days is required for public comment from the date notice is issued. In some cases an oral hearing may also be held. Applicants should expect the full approval process, from submittal of a complete application to AOGCC decision, to take 30 to 60 days. AOGCC Decision 2.3.1 If sufficient information is provided, the AOGCC may approve the system either unconditionally, or conditionally upon field testing and subsequent reporting of meter performance. Any approval is conditioned upon maintenance of the multiphase meter to provide accurate and reliable measurement, and will require periodic calibration of the multiphase meter and records to be kept to verify the calibration of the meter. 2.3.2 An applicant that is dissatisfied with the AOGCC's decision has the option to request reconsideration ("rehearing"). Qualitvina Multiphase Meterina Systems for Well Testina The operator shall submit a proposal to the AOGCC for deploying the multiphase meter or meters in a designated application as a well testing system. ADDlication Contents A complete application must address the following: 3.1.1 Discuss the intended application, proposed location and projected timing of installation of the meter. 3.1.2 List fields, pools, and wells affected by the proposal. Are multiple pools commingled? If so, provide details. 3.1.3 Outline any differences in working interest, royalty interest, and tax treatment for leases or for commingled pools. 3.1.4 Ensure that all working interest owners, royalty owners (e.g. Alaska Department of Natural Resources), and state revenue department (Alaska Department of Revenue) are notified. 3.1.5 Describe the meter make, model, type and measurement ~ ~ · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . methodology for the intended applications. 3.1.6 Describe plans for field-testing the meter (see Section 4). If no field-testing is planned, provide justification. 3.1.7 Provide data on the performance of metering systems obtained from laboratory or field tests. Discuss the expected effect of the proposed meter system upon the quality of the well test data measurement accuracy and overall production allocation in the planned application. 3.1.8 Provide information on expected precision, repeatability, and bias over the range of conditions for which the meter is planned for use. Accuracy must be evaluated across the full range of expected production flow rates, water cut (WC), gas volume fraction (GVF) and process conditions for which the system will be used (see also Section 4.3). 3.1.B.1 Review accuracy for each phase. 3.1.B.2 The method of accuracy description must be clearly defined. It is preferred that the accuracy be expressed as the percentage (+/-) uncertainty in the flow rates for each phase - i.e. oil, water, and gas flow rates. Other methods may be accepted by the AOGCC on a case-by-case basis if sufficient justification is provided. 3.1.8.3 A numerical degree of confidence in the accuracy estimate must be provided and method of determining the confidence level must be discussed. In general, accuracy must be evaluated at a 90% or higher level of confidence. Other confidence levels or statistical analysis of confidence may be accepted by the AOGCC on a case- by-case basis if the methodology for determining confidence level is explained and sufficient justification is provided. 3.1.9 Summarize the production allocation methodology currently being used and explain how the meter will be incorporated into the existing methods of well production allocation. 3.1.10 Describe the contingency plan in the event the meter system does not meet the expected performance. Can the meter be changed out if the system does not meet expected performance, or if the well conditions change such that the production is outside the ~ ~ · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . original designed operating envelope of the meter system? How will this be accomplished? 3.1.11 Submit plans for quality assurance of long-term accuracy. 3.1.12 Describe the proposed systematic maintenance of the measurement system, including methods and frequency of periodic calibration. Describe the proposed record keeping and reporting format. 3.2 Accuracv Expectations 3.2.1 Generally, the AOGCC will expect accuracy for the pay fluid (oil or gas) from the multiphase meter to be within ± 5% over the full range of rates, GVF and we that the meter will measure when in service. It should be noted that this 5% is relative to the reference equipment. 3.2.2 When a multiphase meter is tested against a reference test separator in the field, the accuracy of fluid measurement by both the test separator and multiphase meter will affect the accuracy of the data obtained by the process. Using a root mean square (RMS) approach, the total probable error (accuracy) of the process is determined by: TPE = (E2TS + E2MP) % Where: TPE = total probable error in the measurement E TS = error due to the Test Separator measurement E MP = error due to the Multiphase Meter measurements As an example, if the test separator accuracy is 5% and the multiphase meter accuracy is 5%, the total probable error will be 7%. To obtain a meaningful multiphase meter accuracy, it is critical that the error of the reference equipment be less than 5%. (See also 4.2.2) 3.2.3 Some circumstances may warrant the use of multiphase metering for production allocation even if the meter accuracy is outside the ranges noted above. The AOGCC will consider applications on a case-by-case basis if thorough justification is provided with the application to the AOGCC. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 3.2.4 The applicant shall provide justification for use of a meter system that will operate outside the above stated accuracy criteria. The following are examples where the AOGCC may determine it to be appropriate to relax these criteria. 3.2.4.1 If the meter is used solely for reservoir management and there are no significant financial impacts resulting from well test allocation with multiphase meter systems, less accuracy may be acceptable. 3.2.4.2 Relaxation of accuracy criteria may be appropriate if agreed to by all parties that are financially impacted by inaccuracies of the meter system. 3.2.4.3 It may be very difficult to obtain valid, accurate well tests with conventional separator based systems. As an example, some produced fluids may be extremely difficult to separate and lack of adequate separation will cause large errors in readings. In such instances, use of multiphase meters operating outside of the stated accuracy targets may provide better accuracy and may be preferable to use of separator based systems. 3.2.4.4 Multiphase meters often reduce the measurement system footprint and visits by on-site personnel compared to gravity based separation systems. Multiphase meters may therefore provide an environmental advantage in new, remote drillsite developments and may improve chances of development approval from other regulatory agencies with authority over land use and environmental conservation. 3.2.4.5 Multiphase meter systems may facilitate more frequent well tests as compared to a gravity separator based system. The stability of production during the non-test times will greatly affect the overall allocation accuracy. With more frequent testing and the resulting greater certainty in well test production, overall production allocation may be improved even if the absolute accuracy of the multiphase meter is less than that of the gravity based test separator. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 4.0 4.1 Validation of Meter Performance in Field 4.0.1 The AOGCC will generally require field validation of meter performance prior to final approval. This section provides a guide to the operator in planning a field test to verify the performance of the measurement system and required documentation of these tests. It is strongly encouraged that the field test plan be reviewed with the AOGCC prior to actual field-testing to ensure required data is obtained and to help speed the approval process. 4.0.2 In determining whether to waive the requirement of field testing in a particular situation, the AOGCC will consider such factors as other performance validation options, including prior successful field tests for similar types of fluids and flow conditions, the purpose to which the multiphase metering system will be put, and the practicability of field testing. 4.0.3 Situations where the AOGCC may choose to waive requirements of a field test include but are not limited to the following. 4.0.3.1 Field validation may be unnecessary if the meter system has been successfully tested in a field with similar fluids, flow regimes, operating conditions, rates, GVF and WC. Results of the prior testing must be provided. 4.0.3.2 If the meter is used solely for reservoir management purposes and other lab or field tests are available at similar conditions, a field test may be unnecessary. 4.0.3.3 Field validation of multiphase meters may be difficult, logistically impossible or highly impractical in some instances, particularly for new, remote drill sites. In lieu of a field test, the AOGCC may accept other lab or field tests conducted at similar operating conditions 4.0.4 If the AOGCC determines that a field verification of the proposed multiphase metering system is required, the processes described in the remainder of this section must be followed. Field Verification 4.1.1 The field tests must be conducted under normal field operating conditions. 4.1.2 Field tests require comparison to reference field measurements. Options used to determine the reference flow are: · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 4.1.2.1 Capturing fluids that flow through the system during the test and measuring them with secondary equipment. This option requires extra equipment that must be calibrated per appropriate standards. 4.1.2.2 Indexing the performance of the new system against an established well test measurement system such as a conventional gravity based test separator. 4.1.2.3 A combination of the above. 4.1.3 There may be a large uncertainty in the reference measurements. Pre-calibration and maintenance of the reference measurement system must be performed prior to conducting the field trial. 4.2 Field Test Plan The following is a guide for planning of field tests and may be revised to suit specific conditions. 4.2.1 Establish performance expectations that are within the design and tested constraints of the system. 4.2.1.1 Multiphase metering accuracy degradation typically occurs for wells that have operating liquid rates, gas rates, water cut, or gas volume fractions outside the system's designed accuracy range. 4.2.1.2 The multiphase metering system must be sized and designed to handle the flow range, pressure, and temperature (ambient and production) conditions existing in the field. 4.2.1.3 Multiphase meter performance is also related to the fluid composition such as salt content of the liquids, impurities in the gases etc, which can change over the field life. 4.2.2 In a majority of qualification tests, 2-phase or 3-phase gravity based test separators are used to verify the performance of other multiphase measurement systems. Since these systems are used as the reference, the test plan must document the procedures used to calibrate and establish the accuracy of the liquid and gas measurement devices, the water cut analysis and monitoring, and the data acquisition and recording. 4.2.3 Full separation is rarely achieved and the procedures must make · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 4.2.4 4.2.5 4.2.6 4.2.7 4.2.8 4.2.9 an allowance for reduced instrumentation accuracy of the reference under field conditions. Multiphase meters must be calibrated initially to accommodate the properties of the field fluids. The calibration procedures to be used prior to the field tests must be described. The calibration procedures must cover both the multiphase metering system as well as the reference systems. Quite often the multiphase meter, the reference test separator, and the tanks used for fluid measurements are operating at different pressures and temperatures. Measurements made by these systems must be converted to rates at standard conditions (14.65 psia and 60 OF). Actual test measurements, prior to conversion to standard conditions, must be retained. Procedures used to determine shrinkage and conversion of volumes to standard conditions must be addressed. Once the initial calibration is done, the field test results must be obtained without further intervention in the settings of the multiphase meter. If repair, resetting, or recalibration is required during the field tests, the nature and frequency of these interventions must be recorded and reported. One of the major objectives of the field test is to evaluate the performance of the multi phase metering system over the full range of gas volume fraction and water cut since these are the two principal factors in determining the accuracy of the multiphase metering systems. To accomplish this, an outline of the test matrix to be used in the field tests is needed, noting the range of flow rates, GVF, and WC to be covered in the field tests. It is recognized that this matrix may be limited by the flow rates of the wells available, however the test matrix must cover a wide enough range to allow for practical evaluation of the performance. The testing program must cover enough data points to allow a statistical evaluation of the accuracy performance such as the number of points in the tests that can meet the acceptance criteria of Section 3.2. The proposed method for reporting the field test results must be described (see Section 4.3). · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · .! · · · · · · 4.3 . . Reoortina the Field Results 4.3.1 Thorough documentation will be required if field verification is required by the AOGCC prior to final approval of the multi-phase meter system. A report must be submitted to the AOGCC describing the results of such field trials, including accuracy results. The guidelines described in this section are recommended for formatting the report of the field test results. Alternate formats may be used. Regardless, it is required that evaluation of performance be provided as a function of factors (rates, fluid properties, operating conditions, GVF, WC, etc.) found to significantly affect accuracy. 4.3.2 All flow performance data for the metering system must be described in conventional oilfield units at standard conditions. 4.3.3 Individual well test results as measured by the multiphase meter and the reference measurement system must be provided and include the following: 4.3.3.1 Flowing pressure - measured at the meter in pounds per square inch absolute (psia). 4.3.3.2 Flowing temperature - measured at the meter in degrees Fahrenheit (OF) 4.3.3.3 Oil rate - Stock Tank Barrels of Oil per Day (STBD) corrected to standard conditions, at 14.65 psia and 60°F. 4.3.3.4 Water rate - barrel per day (BPD). 4.3.3.5 Gas rate - thousand standard cubic feet per day (MSCFD), at 14.65 psia and 60°F. 4.3.3.6 Gas-ail-ratio (GaR) - (SCF/STB) the gas volume flow rate, relative to the oil volume flow rate, both converted to volumes at standard pressure and temperature. 4.3.3.7 Gas Volume Factor (GVF) - gas volume flow rate, relative to the multi phase volume flow rate (oil, gas, water), at the pressure and temperature prevailing at the meter. The GVF is normally expressed as a percentage 4.3.3.8 Water cut (WC) - the water volume flow rate, relative to the total liquid volume flow rate (oil and water), both converted to volumes at standard pressure and temperature. The WC is normally expressed as a percentage. · .' · · · · · · · · · · · · · · · · e; .\ .ì · · · · · · · · · · · · · · · · · · ~ · · · · . 4.3.4 4.3.5 . 4.3.3.9 Water-in-liquid ratio (WLR) (optional) - the water volume flow rate, relative to the total liquid volume flow rate (oil and water) at the pressure and temperature prevailing at the meter. The WLR is normally expressed as a percentage. 4.3.3.10 Fluid properties including: · Oil volume factor (Barrels at meter conditions/STB) · Gas volume factor (Cubic feet at meter conditions/SCF) · Water salinity · Oil gravity (0 API) · Gas specific gravity Figure 1 shows an illustrative graphical method that may be used to display accuracy results as a function of oil, water, and gas flow rates, WC, GVF or other important factors. In this figure the y coordinate represents flow rate error relative to the reference measurements. Repeatability of the measured data and confidence level (see 3.1. 8.3) must be stated. The repeatability is expressed by the following relationship: . . (max error)-(min error) repeatabzlIty = ~ number of tests · · · · · · · · · · · · · · · · · .' .1 · '. · · · · · · · · · · · · · · · · · · · · · · · Fig. 1 - An illustrative graphical method of reporting the accuracy performance of multiphase metering systems. These plots should be provided for each phase compared to GVF, water cut, and other important parameters. Liquid Flowrate Error VS. GVF 50 .... 40 0......... t: ~ 30 W ~ 20 Q) Q) ...... '$ 10 ~O::: ~ .8 0 o Q) -10 > IJ.. ~ -20 "C & -30 __ :;j 0 C" ~ -40 ..J -50 20 Test Data I - - Blue Lines, Range of relative flow rate error 30 40 50 60 70 80 90 100 Reference GVF (CÞfo) · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e . . . Appendix 2 Table 1 - List fields, pools and wells affected by this proposal Working interest, royality interest, and tax treatment for leases Alaska Property Ownerships AOGCC BP Processing Facility Participating Area Pool Code AOGCC Pool Description Royalty Rate % ELF Exploration Chevron Conoco Phillips Exxon Mobil Doyon Ltd Nana Unocal Anadarko Murphy Total Badami Badami 060100 Badami 12.5% to 16.67% Separate 100 100 Endicott Eider 220165 Ivishak Undefined (Eider) 12.50% Separate 100 100 Endicott Endicott 220100 Endicott 12.5% to 20% Separate 67.9221 0.0234 21.0206 0.1291 0.3874 10.5174 100 Endicott Sag Delta North 220150 Sag Delta North 12.5% to 20% Separate 98.1327 0.4668 1 .4005 100 LPC Niakuk 640148 Niakuk 12.5% Consolidated Niakuk 26.360567 1.16 36.076746 36.402687 100 LPC Tract Operations 640147 GPMA Ivishak-Sag River 12.5% Consolidated Niakuk 0 LPC West Niakuk 640149 Niakuk, Undefined 12.5% Consolidated Niakuk 26.360567 1.16 36.076746 36.402687 100 LPC North Prudhoe Bay State 640152 North Prudhoe Bay State 12.5% Separate 26.360567 1.16 36.076746 36.402687 100 LPC West Beach 640186 West Beach 12.5% Separate 26.360567 1.16 36.076746 36.402687 100 LPC & Prudhoe GC-1 Lisburne 640144 Lisburne 12.5% Separate 26.360567 1.16 36.076746 36.402687 100 Milne Point MPU Kuparuk 525100 Milne Point Kuparuk 12.5% to 20% Separate 99.425769 0.574231 100 Milne Point MPU Sag River 525150 Milne Point Sag River 12.5% to 20% Separate 98.741072 1.258928 100 Milne Point MPU Schrader Bluff 525140 Milne Point Schrader Bluff 12.5% to 20% Separate 99.269596 0.730404 100 Milne Point Tract Operations 525160 Milne Point Ugnu, undefined 12.5% Separate 100 100 Northstar Northstar 590100 Northstar 20% plus supplemental Separate 98.5772 1 .4228 100 LPC & Prudhoe GC-1 Point Mcintyre 640180 Point Mcintyre 12.5% to 16.67% Consolidated Prudhoe 26.360567 1.16 36.076746 36.402687 100 Prudhoe All GC & FS Prudhoe IPAs (ORlGC) 640150 Sadlerochit 12.5% Consolidated Prudhoe 26.360567 1.16 36.076746 36.402687 100 Prudhoe GC-1 Midnight Sun 640158 Midnight Sun, undefined 12.5% Consolidated Prudhoe 26.360567 1.16 36.076746 36.402687 100 Prudhoe GC-2 Aurora 640120 PBU Aurora, Undefined 12.5% Consolidated Prudhoe 26.360567 1.16 36.076746 36.402687 100 Prudhoe GC-2 Borealis 640130 PBU Borealis, Undefined 12.5% Consolidated Prudhoe 26.360567 1.16 36.076746 36.402687 100 Prudhoe GC-2 Orion 640135 PBU Orion, Undefined 12.5% Consolidated Prudhoe 26.360567 1.16 36.076746 36.402687 100 Prudhoe GC-2 Polaris 640160 Schrader Bluff (Satellite), undefined 12.5% Consolidated Prudhoe 26.360567 1.16 36.076746 36.402687 100 G. Benson · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · NORTH SLOPE OR OilFIELD AND POOL OWNERSHIP March 2007 Map LocatjOn~ ,-," j \.".~ $ ........ PRUDHOE BAY UNIT' All PAs including OIL RIM and GAS CA ExxonMobll 36.402687% CPAI 36.076746% BP Exploration 26.360567% Chevron 1.160000% , ¡:: ¡§ <: I Island UTM6/NAD27 COLVILLE RIVER UNIT ALPINE, FIORD-NECHElIK, FIORD-KUPARUK. NANUO-NANUO, AND NANUQ-KUPARUK PAs Approx. 10 Miles West CPAI 71:1.00% Anadarko 22.00% CroS$ !s 1;1I1d DUCK ISLAND UNIT ENDICOTT PA BP Exploration 67.9221 % ExxonMobll 21.0206% Unocal 10.5174% Nana 0.3874"/0 Doyon ltd. 0.1291% CPAI 0.0234% KUPARUK RIVER UNIT'" All PAs CPAI BP Explo ration Unocal ExxonMobll PT. THOMSON UNIT Approx. 25 Mlle. East ExxonMobll 48.0% BP Exploration 31.0% Chevron 15.00,4 Others 6.0% BADAMI UNIT BADAMI SANDS PA Approx. 7 Miles East BP Exploration 100.0% TAPS BP Pipelines Inc. CPAI ExxonMobll Williams Unocal 46.8765% 28.2323% 20.4325% 3.0845% 1.3742% BPXA Cartography/lm15098 2007.dgn · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · BPXA OPERATING UNITS - NORTH SLOPE, ALASKA Leavitt ........~_..~.. "" Pad Or Drill Site 1. Topographic and hydrographic features are from U.S. Geological Survey 1 :63360 Quadrangles. Pipeline -- Access Roads BPXA Operating Unit I£r,; Cross Island <r.. Reindeer Island Argo Island ii No Name Island o 2 F==~ o 2 DS3C NarwhallsJand Jeanette fsfa¡1d D$1L .. \ /' 2. Man made features are from Unit Operator 1 :6,000 Mapping ( based on 1973 aerial photography with periodic updates) 3. Unit boundaries shown effective April 2006 4 6 Kilometers .~ 4 Miles 4. BPXA Cartography does not warrant that the data is accurate or fit for any particular use. User hereby indemnifies and holds harmles BPXA Cartography for any claims and/or liabilities which may arise from users use of this data. UTM6/NAD27 ~'" ~" 4" """".. Karluk Island Stockton !slands Polals · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · hase atche Vx* multiphase measurement technology combines an instrumented venturi with a dual-energy fraction meter. This combination measures the total mass flow rate and the fractions of gas, oil, and water, which in turn detennine the oil, water, and gas flow rates. Vx technology functions without the need for separation or an upstream mixing device, which minimizes the size and weight of the equipment. The technology has no moving parts and is essentially maintenance-free. The Phase Watcher* permanent multiphase flowmeter uses Vx technology to continu- ously measure flow rates in wells exhibiting one-, two-, or three-phase flow for produc- tion monitoring on land, platfornl, and subsea wells. The Phase Watcher Vx meter operates equally well in both oil and gas wells, making it possible to test dry gas, condensate, and oil wells with a single meter. Because there is no need for separators, this significantly reduces space, load, and mainte- nance requirements in offshore applications and decreases the footprint in land-based applications. The Phase Watcher Vx meter enables safer, more efficient installations while reducing field development costs. A superior dynamic response enables the Phase Watcher Vx meter to take accurate and repeatable measurements in less time than required for flow stabilization. These meas- urements enable continuous diagnosis of x production anomalies for fme-tuning of artificial lift systems and well performance. Additionally, the Phase Watcher Vx meter is not affected by complex flow regimes such as slug flow, so a higher frequency of well testing is both feasible and cost-effective. The Phase Watcher Vx meter can interface securely with the Internet to allow monitor- ing of and remote decision making for well and field operations anywhere in the world. Because minimal operational input is needed after the initial setup, data quality is assured online in real time. Phase Watcher Vx ser- vices are ideal for satellite, unmarmed, and subsea locations. Regulatory bodies such as the US Minerals Management Service, the UK Department of Trade and Industry, and the Norwegian Petroleum Directorate have recognized Vx technology by approving applications of Phase Watcher meters for fiscal allocation of production. The Phase Watcher Vx system is the only multiphase meter that is approved by all three regulatory bodies for fiscal allocation. This recognition has prompted industry organizations such as the American Petroleum Institute, the International Organization for Standardization, and the Norwegian Society for Oil and Gas Measurement to rewrite production well testing and allocation standards. lu b Applications III Production well testing III Production and fiscal allocation on land, platform and subsea wells III Production trending III Artificial lift system optimization III Oil, water, and gas measure- ments for any given gas volume fraction Benefits .. Quicker, more efficient well testing, saving response time and costs .. Lower field development costs .. Safer installation and operation III Better flow rate accuracy enabled by fluid characterization services Features .. Small, lightweight, and simple to operate and maintain II Remote real-time operation and data acquisition III Repeatable, highly accurate measurements III Exceptional dynamic response III No separation and no flowing calibration required III Optional sampling capabilities III Flow measurements in slug,gfoam, and emulsion environments .. Common high-pressure-rating hardware device for both oil and gas wells . . Specifications Well applications Operating modes Mechanical specifications Service Max. working pressure, kPa [psi] Temperature rating, degC [degF] Ambient working temperature, degC [degF] Ambient storage temperature, degC [degF] Dimensions (W x D x HI, mm [ft] Vx 29 mm Oil. condensate, and gas wells Oil mode and gas mode Vx 88 mm Oil. condensate, and gas wells Oil mode and gas mode Vx 52 mm Oil. condensate, and gas wells Oil mode and gas mode HzS (wetted parts) 34.474 [5,000] (optionally, 103.421 [15,000]1 -20 to 150 [-4 to 302] (optionally, 200 [392] -20 to 85 [-4 to 185] -40 to 85 [-40 to 185] 663 x 686 x 633 [2.18 x 2.25 x 2.08] 270 [595] 127.0 [5.00W 25 W continuous CENELEC EEx" d liB T5 and North American Flame Proof Class 1, Division 1, Groups C and D T5 IP 66 RS422 MODBUS RTU, RS 485 MODBUS RTU, and TCP/IP over Ethernet or MODBUS 684 x 479 x 467 [2.24 x 1.57 x 1.53] 210 [463J 76.2 [3.00W 742 x 766 x 930 [2,43 x 2.51 x 3.05] 398 [877] 203.2 [8.00W Weight, kg [Ibm] Connections, mm [in] Power consumption Certification for explosion-proof equipment Ingress protection (IPI Communication protocols Common Metrological Specifications Liquid viscosity range, Pa.s [cP] Repeatability Resolution Oil Mode Specifications 0.0001 to 2 [0.1 to 2,000] at line conditions Better than 1 % (total mass rate at line conditionsl Better than 0.1 % (total mass rate at line conditions) Water/liquid ratio Gas volume fraction Max. liquid flow capacity at low gas flow and line conditions, m3/d [bbljd] Gas Mode Specifications Water/liquid ratio Liquid volume fraction Maximum gas flow capacity at zero liquid flow ratett t GRAYLOC® hub 'European-approved explosion-proof equipment § Maximum liquid capacity at gas/liquid ratio = O. liquid density = 850 kg/m3 [53 Ibm/f!'). pressure = 2.068 kPa [300 psi). water/liquid ratio = O. venturi differential pressure = 500 kPa 172.5 pSi). and maximum total fluid velocity of 0.3 Mach It Maximum gas capacity at zero liquid flow rate. gas density = 1.121 kg/m3 [70 Ibm/ft3). pressure = 34.474 kPa [5.000 psi). venturi differential pressure of 500 kPa [72.5 psi). and maximum total fluid velocity of 0.3 Mach. o to 100% o to 98% 2,051 [12,900jl o to 100% o to 98% 6.280 [39,500] o to 100% o to 98% 17,807 [112,000] o to 100% o to 10% 1.0 x 106 m3/d [36.3 MMcf/d] o to 100% o to 10% 3.2 x 106 m3/d [116 MMcf/d] o to 100% o to 10% 9.1 x 106 m3/d [323 MMcf/d] www.slb.com/weJltesti ng OS-WT-062 July 2006 *Markof Schlumberger Other company, product, and service names are the properties of their respective owners. Copyright © 2006 Schlumberger. All rights reserved Produced by Schlumberger Marketing Communications Schlumberger · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . Distribution : 3PM File Clients Document tiUe: PhaseWatcher Vx Design Basis Comments: - ~ JL.....2 c:;: C 1 O-OCT -2001 Production JR aJI'.fIa ~ B 06-JUL-2oo1 Production BLa BVH BP A 15-JUN-2001 Production DM BP 00 29-NOV-2000 Production BLalAFo BVH 01 23-NOV-2000 IDC BLalAFo Rev.: Date: Issued for: Made by: Checked: Approved: Project number. Project name. PhaseWatcher Vx Customer document number. NIA 3-Phase Measurements document number. No. of pages. ~3-PHASE 6009-1329-D 16 Measurements AS . ~ 3-PHASE ~easurements AS No: Rev.: Date: Page' 6009-1329-D C 10/10101 2 of 16 PhaseWatcher Vx Design Basis TABLE OF CONTENT 1. INTRODUCTION ................................................................................................................................................................4 1 .1 PURPOSE.. ........ ..................... ............. ....... ........... ........... ................... ........ ........................ ......... ................ ................. 4 1 .2 REFERENCES .... ........ .... ........ ........ .... ........... ......... ... .... ...... ........... ......... ....... ............... ......... ....... ............ .... ............ ..... 4 1.3 ST ANDAROS ...... ........ .... ... ..... ........ .... ........... ......... ....... ...... ............. ........ ...... ............. .......... ........ ............ .... ......... ........ 4 1.4 RADIOACTIVITY .. ... ..... ....... ........ ..... ........ ....... ..... ... ... ..... ........ ............... .... ...... ........... .... .... .... ........ ............ .... .... ............. 4 1.5 QuAlITY AssURANCE I QUAliTY CONTROl....................................................................................................................... 4 1.6 OPERATION AND MAINTENANCE REQUIREMENT ................................................................................................................. 4 2. EQUIPMENT DESIGN REQUIREMENTS .......................................................................................................................... 5 2.1 METERING UNIT SITE INTEGRATION.................................................................................................................................. 5 2.2 DESIGN LIFE...... ............ ........ .............. ....... .......... ........ ... ....... ...... ...................... ...... ..... ....... .... ............ .... ........ ............. 5 2.3 PRESSURE AND TEMPERATURE DESIGN CRITERIA ............................................................................................................. 5 2.4 MATERIALS OF CONSTRUCTION .......................................................................................................................................5 3. PHASEWATCHER VX METERING INSTRUMENTATION ................................................................................................ 6 3.1 DATA AcaUISITION FLOW COMPUTER AND JUNCTION Box ................................................................................................. 7 3.1.1 Junction Box (JB)................................................................................................................................................ 7 3.1.2 Data Acquisition Flow Computer (DAFC)............................................................................................................ 7 3.2 METERING SECTION ..... ...... ........ ............ ........ ......... ............. ............... ........ ........ .......... .............. ...................... ............. 8 3.2.1 Gamma Fraction Meter.......................................................................................................................................8 3.2.2 Transmitters ................ ........ .... ..... ....... ........... ........ ........ ........ .......... ......... ......... ........ ... ................... ...... ....... ...... 9 4. ACCURACY ..................................................................................................................................................................... 10 5. INSTALLATION ACCESSORIES..................................................................................................................................... 12 5. 1 Cables......................................... .... ........ .... ....... .... .... ........ ........ ........ ...... ...... ... ..... ........ .............................. ......... 12 5.2 Glands .................................................................................................................................................................. 12 5.3 Tag labels ...... ........ ..................... .... ..... ... ...... ............. ............. ... .... ........ ........ ............ ............................ ..... .......... 12 6. MECHANICAL DESCRIPTION ........................................................................................................................................ 12 6.1 INTERFACES ...... ......... .... ...... ................. ................ ........... ........................ ............ .......... ................. ..................... ....... 12 6.2 OvERALL DIMENSIONS. .... .......... ............. ............ ...... ........... ....... ....... ..... .... ... ..... ... ........ ............. .... ............... ............... 13 6.3 DETAILED DESCRIPTION .. .......... ............... .......... .......... ............. .................................... .............................. .......... ....... 14 6.3.1 Blind T88........................................................................................................................................................... 14 6.3.2 Detector body.... ... ........ .... ........... ............ ................... ..... .............. ...... ....... ........ ........... ..... ....... ......... ........ ....... 14 6.3.3 Source body...................................................................................................................................................... 14 7. PHASEWATCHER SUPERVISORY SYSTEM INTERFACE ........................................................................................... 15 8. SERVICE COMPUTER..................................................... ................................................................................................ 15 8.1 SERVICE COMPUTER REQUIREMENTS ............................................................................................................................ 15 8.2 SERVICE COMPUTER APPLICATION SoFTWARE ............................................................................................................... 15 9. SYSTEM TESTING........................................................... ................................................................................................ 15 10. AVAILABLE OPTIONS ................................................................................................................................................ 16 10.1 VFD DISPLAY MoDULE ................................................................................................................................................ 16 10.2 GAlVANIC ISOlATORS ................................................................................................... ............................................... 16 10.3 SERVICE COMPUTER .................................................................................................................................................... 16 10.4 FLOWLOOP TEST .......................................................................................................................................................... 16 10.5 DATAlOGGER ................. ..................... ...... ... ..... ...... ................. .... .......... .............. ......... ........ ... ..... ............ ........... ....... 16 10.6 OTHER OPTIONAl ITEMS.. . ........ .......... ......... ........... ......... ......... ...... .......... ................ ............... ........ .............................. 16 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . No: 600t-1~ PhaseWatcher Vx Rev.: C ~3-PHASE Design Basis Date: 10110101 Measurements AS Page: 3 of 16 List of FIGures : Figure 1 : PhaseWatcher Vx instrumentation block diagram ...................................................................................................... 6 Figure 2 : Gas accuracy............................................................................................................................................................ 10 Figure 3 : WLR accuracy .......................................................................................................................................................... 11 Figure 4 : Uquid accuracy......................................................................................................................................................... 11 . . No: 6009-1329-D PhaseWatcher Vx Rev.: C ~3-PHASE Design Basis Date: 10/10/01 Measurements AS Page: 4 of 16 1. INTRODUCTION 1.1 Purpose The purpose of this document is to provide a well defined functional design basis for the 3PM PhaseWatcher Vx, designed to provide individual Well Test and Reservoir Management data for Production Wells, by routing the Well stream through the Flow Metering System. 1.2 References · Pressure Vessel and Boiler Code ASME VIII, div.2, rev.1998 · API 6A Specification for Wellhead and Christmas Tree Equipment. Edition 17, 1996 PSL 3 · ASME IX (Welding) · NACE MR-0175, rev.2000 · NS 3472 (lifting arrangement) · NORSOK R-001, Mechanical Equipment, Rev. 3, Nov. 1997 1.3 Standards · The pressure retaining parts to be calculated according to ASME VIII, div.2 · API6A Specification for Wellhead and Christmas Tree Equipment. Edition 17, 1996 PSL 3 · EC Electromagnetic Compatibility Directive 89/336IEEC as amended · Harmonised EMC standards: · EN 50081-1 (1992) Emission · EN 61000-6-2 (1999) Immunity · Ex standards: · EN 50014 General requirements · EN 50018 Flameproof enclosures "cI" · EN 50020 Intrinsic safety Wi" · EN 60079-14 Electrical installations in hazardous areas · EN 60079-17 Inspection and maintenance of electrical installations in hazardous areas · CE mark compliant · EC Directive 96/29/Euratom 1.4 Radioactivity It is our customer's responsibility so seek approval for import and installation of a device containing a Radioactive Source at his premises, and for the disposal of the source after end use. 3PM personnel is certified according to Norwegian Regulations for handling (removal and re-installation) of the Radioactive Source utilised in the PhaseWatcher. 1.5 Quality Assurance I Quality Control A dedicated Quality Control Plan (QC) has been established by 3PM in order to define tests and inspections relevant to the design, manufacture and testing of the PhaseWatcher. The QC plan also define inspection hold and/or witness points. 1.6 Operation and Maintenance Requirement PhaseWatchers are built of highly reliable components and are based on Offshore and Onshore experience. We expect limited Service and Maintenance requirements. Please refer to the document O&M manual, for more details on Maintenance. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ 3-PHASE "'Measurements AS PhaseWatcher Vx Design Basis No: Rev.: Date: Page: 6009-1329-0 C 10110101 5 of 16 2. EQUIPMENT DESIGN REQUIREMENTS 2.1 Metering Unit Site Integration The Metering Unit complete with instrumentation and Data Acquisition Flow Computer is designed for outdoor Hazardous Area operation: · Ex certification: Zone 1, Gas group liB, Temperature classification T4 and higher. Certification is to CENELEC flameproof EEx d standard (CSA in option). · Inaress Protection liP} : IP 66 minimum · Power reauirement : Single 24VDC power input from customer provided power supply - Operating voltage: 20 to 35 VDC - Steady state operating power consumption: 35 W maximum (24 Waverage) · Communication: - RS-422 Modbus serial link for processed data to the Supervisory System ( Modbus Master) and the PhaseWatcher Service Computer. 2.2 Design Life The design life of the PhaseWatcher is 20 years. The Flow Meter contains a Sa -133 isotope with a half-life of 10.66 years. The nuclear decay is automatically accounted for in the flow calculations. It is recommended to change the Ba-133 source every 5 - 10 years depending on the GVF in the application. 2.3 Pressure and Temperature Design Criteria · Design pressure: · Test pressure: · Process temperature, mechanical: · Ambient (enclosure internal) temperature, electrical: · Storage temperature : 345 barg (5000 psig) 690 barg (10,000 psig) -40 °C to +150 °C -20°C to +85 °C -40 °C to +85 °C NOTE: The listed design pressures and temperature ranges are valid for the standard design only. Other ranges may apply, depending on customer's requirements or implementation of options. 2.4 Materials of Construction All Materials are selected according to NACE MR-0175. · Bobs: · Nuts: · Pressure housings : · Non-pressurised parts: · 3/8" piping : · DAFC enclosure (JB) : · Glands: · Transmitter housings: · Transmitter brackets: · Transmitter wetted parts: Hot dip galvanised and made according to ASTM A320 L7 Hot dip galvanised and made according to ASTM A 194 GR.4-S4 UNS S31803 (Duplex stainless steel) AISI 316L AISI316UUNS S31803 AISI316L For transmitters: AISI 316, all other glands: Brass Aluminium (epoxy coated). AISI 316 AISI 316 (not a process wetted part when using remote seals) . . No: 6009-1329-D PhaseWatcher Vx Rev.: C ~~ Design Basis Date: 10110101 Measurements AS Page: 6 of 16 . Transmitter remote seals: . Thermowell: Hastelloy C-276 (wetted parts) / AISI 316 (capillaries) / AISI 304 (armour) AISI316L NOTE: Other materials may apply. depending on customer's requirements. 3. PHASEWATCHER VX METERING INSTRUMENTATION The PhaseWatcher Instrumentation Block Diagram below provides an overview of the PhaseWatcher instrumentation. JIJIIICTION BOX I1AlAROQUS AIlEA SAFE AA£A ADDITIONAL !tART TRAHSUITTERS ICLIENT INSTALLED OPTION) ~ call1ll(e) .......22 Nødbue eom- _UVOC_) TO ClIfHT'S CONTAOL I ~:: ~, POWER 8UPPL , AS-232 í-~- I I AS-4Z2 i!IEIMCI! ADAPnR CCIIØ'UT1!JI (OP11OH) (Of'TIOH) Figure 1 : PhaseWatcher Vx Instrumentation block diagram Standard Trensmltt8ra : PDT01: Differential Pressure gauge transmitter Fuji FCX-A PT01: Pressure gauge transmitter Fuji FCX-A TT01: Blind-Tee Fluid Temperature transmitter Rosemount 644 The PhaseWatcher instrumentation consists of a Multi Energy Fraction Meter, a Differential Pressure transmitter and 2 Smart transmitters. The Data Acquisition Flow Computer (DAFC) receives all measurement signals from the transmitters and Gamma Detector. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · No: 6009-1329-D PhaseWatcher Vx Rev.: C ~~ Design Basis Date: 10/10/01 Measurements AS Page: 7 of 16 . . 3.1 Data Acquisition Flow Computer and Junction Box All instruments at the PhaseWatcher are wired to the Data Acquisition Flow Computer located in a dedicated EEx d certified enclosure (Junction Box) fixed to the Venturi Section structure. 3.1.1 Junction Box (JB) The standard Junction Box is a single compartment EEx d enclosure. It houses the DAFC, terminals and customer selected options. Reference documentation: · 6009-1526-3 · 6009-1527-4 · 6009-1528-3 · 6009-1529-4 · 6009-1356-D Junction Box Assembly StahVStd Junction Box Assembly StahVStd L.O.M Junction Box Assembly StahVDisplay Junction Box Assembly StahVDisplay L.O.M Junction Box Checkout Procedure PhaseWatcher Vx 3.1.2 Data Acquisition Flow Computer (DAFC) The DAFC is an embedded Computer System tailor made for its use in 3PM Flow Meters. The design is qualified for use over a wide temperature range and for withstanding severe shock and vibration levels. The following primary measurements are acquired by the Data Acquisition Flow Computer: · Gamma ray attenuation at the Venturi throat · Differential pressure across the Venturi · Line pressure · Line temperature · Ambient temperature The Data Acquisition Flow Computer comprises the following main elements : · Single board computer · Flash disk · HART and Analog Modem (HAM) VO board · Power supply board · Termination board · DAFC rack The Data Acquisition Flow Computer will during power up automatically load the Application program and start metering. After power-up a period of time is needed for heating the Gamma Detector to its stabilisation temperature in order to reach final required accuracy. However, presentation of flow data will start approximately 3 minutes after power-up. DAFC Overall Specifications: · Processor: · Data Storage: · Serial Interface: · Parallel Interface: · CAN Interface: Various connections: · General Input Channels: · Digital Output: AMD 5x86, 133 MHz 8 Mbytes onboard DRAM, 32 Mbytes Enhanced IDE flash disk 2 RS-232 ports. and 2 RS-422 ports opto isolated Bi-directionallEEE 1284 enhanced parallel port Supports CAN specification 2.0 Floppy disk, mouse, and keyboard. reset button, etc. 12 current loop channels (0-21 mA), Hereof 8 channels with HART modems (Up to 4 transmitters per HART channel), 4 voltage channels (0- 5 VDC) 4 potential free change over relays (NC\NO) 3..PHASE Measurements AS PhaseWatcher Vx Design Basis 6009-1329-D C 10/10/01 8 of 16 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 3.2 Metering Section A Venturi Momentum Meter arrangement is used in combination with the Gamma Fraction Meter to obtain the flow rates of Oil, Water and Gas. The Venturi Section, defined according to ISO 5167, is located immediately downstream the Blind Tee. Here the multiphase mixture can be treated in a generic way whatever the flow conditions upstream of the Blind Tea. A unique flow model, based on measurements taken at the throat of the Venturi, is used for the interpretation and for providing the basic answer product. A high precision Differential Pressure Transmitter measures the Venturi differential pressure. This Transmitter is equipped with remote seal sensors of pancake type, bolted to the sides of the Venturi section. If the pressure ports for any reasons become clogged, the process pressure will no longer be transmitted to the remote seals, and the recorded values will maintain on the last values prior to clogging. An indication of such a situation occur if the Gamma Fraction Meter indicates changes in flow composition and flow rates without any changes in the recorded Venturi Differential Pressure. 3.2.1 Gamma Fraction Meter The Multi Energy Gamma Fraction Meter provides the fractions of Oil, Water and Gas in the flow. The calculation is based on the attenuation of two different Gamma energy levels of a 133-Ba isotope. The Gamma Detector System is enclosed in a NEMKO/CENELEC certified EEx d housing located at the Venturi throat, it comprises the following main elements: . A Nal(TI) scintillation Detector of rugged design complete with Photo Multiplier Tube, high voltage supply and electronics which detects the Gamma energy pulses emitted by the Barium-133 isotope and transmits the information to the DAFC on an RS-232 link. . Integrated and potted cable Penetrator assembly. The Radioactive Source is encapsulated in a separate housing diametrically opposite the Detector housing at the Venturi throat. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . ~ 3-PHASE ~easurementsAS 3.2.2 Transmitters PhaseWatcher Vx Design Basis No: Rev.: Date: Page: 6009-1329-D C 10/10/01 9 of 16 General transmitter sD8Clfic8t1ons : · Operating pressure 5,000 PSI. . test pressure 10,000 PSI. · EEx d (flameproof) certified (SCA option) · Smart 2-wire transmitters with superimposed HART communication protocol. · Analog (4-20 mA) output range set to calibrated range. HART output range is 150% of analog range (provided transmitter's Upper Range Limit (URL) not exceeded). Differential P.....ure Tran.mltter : A Differential Pressure transmitter is used to measure the differential pressure across the Venturi Section. The selected Transmitter must be able to withstand high Well Shut-in pressure, and must be able to measure a differential pressures down to 50 mbar with high line static pressure applied. NQæ The transmitter type and listed parameters may change, depending on customer's requirements Reference documentation: · 6009-1230-0 Differential pressure transmitter/remote sealsldatalPW Pressure Transmitter: A gauge Pressure Transmitter is applied to measure the line pressure at the Venturi throat. NOTE: The transmitter type and listed parameters may change, depending on customer's requirements. Reference documentation: · 6009-1231-0 Pressure transmitter/remote sealsldatalPW 3-PHASE AS PhaseWatcher Vx Design Basis No: Rev.: Date: Page: 6009-1329-D C 10/10/01 10 of 16 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Temøerature Transmitter : A Temperature Transmitter monitors the average temperature of the multiphase flow. T em; Drift Signal Hazardous Area Certification NOTE: The transmitter type and listed parameters may change, depending on customer's requirements Reference doçumentatlon : .. 6009-1541-0 Temperature transmitter /1500 Lbs flanged Thermowel! Data sheets PW .. 6009-1232-0 Temperature transmitter/Thermowellsldata/PW 4. ACCURACY The PhaseWatcher Multiphase Flowmeter accuracy is given at line conditions, the information given here-below are just Indicative, and they are based on our past experience about what we could achieve in a reasonable working environment. They are not contractual and they will be updated independently of this document. The main measurements from the meter are: .. the WLR (Water Liquid Ratio). .. the GVF (Gas Volumetric Flow rate). .. Liquid Volumetric Flow Rate. Here below are the error represented by a graph versus the GVF for these parameters uncertainties: I c:J ! I GVF Figure :2 : Gas Volumetric Flow Rate accuracy · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 3-PHASE Measurements AS PhaseWatcher Vx Design Basis No: Rev.: Date: Page: 6009-1329-D C 10/10/01 11 of 16 ,. ·2 II: 2 i I · w .. .. .. .,. GVF Figure 3 : Water liquid Ratio accuracy 11 j ... , I J .j GVF Figure 4 : liquid Volumetric Flow Rate accuracy Remarks: .. The optimal working envelope of the standard meter on the full range of temperature is defined with a DP measurement between 200 and 4500 mbar and an absolute line pressure higher than 120 psia. .. The accuracy is given assuming enough contrast between the oil and water density of 200 kglm3. . . No: 6009-1329-D PhaseWatcher Vx Rev.: C ~3-PHASE Design Basis Date: 10/10/01 Measurements AS Page: 12 of 16 5. INSTAllATION ACCESSORIES 5.1 Cables The following field cables are supplied and installed at the PhaseWatcher by 3PM : · 1-pair cable between differential pressure transmitter and the Data Acquisition Flow Computer: BFOU(i) 1 pair x 0.75 mm2. Colour: Grey (standard) · 1-pair cable between line pressure transmitter and the Data Acquisition Flow Computer: BFOU(i) 1 pair x 0.75 mm2. Colour: Grey (standard) · 1-pair cable between line temperature transmitter and the Data Acquisition Flow Computer: BFOU(i) 1 pair x 0.75 mm2. Colour: Grey (standard). Supplied cable length 5 m. · 4-pair cable between gamma detector and the Data Acquisition Flow Computer: BFOU(c) 4 pair x 0.75 mm2. Colour: Grey 5.2 Glands All supplied glands are Raufoss D-705 series and Hawke ICG 6531UNIV series, EEx d certified. 5.3 Tag labels Stainless steel tag labels are fitted to all instrumentation and adjacent to the corresponding mounting positions. Tag labels are also fitted to supply cables and the Junction Box. Reference documentation: for standard tag names (Customer specified names are available on request) : · PhaseWatcher Interconnection Diagram. 6. MECHANICAL DESCRIPTION The PhaseWatcher Vx comprises the following main elements: (J Venturi Momentum Meter (J Blind Tee Three standardised Venturi diameters are offered: 29.25, 52 and 87.5 mm. The Venturi beta ratio is 0.5. 6.1 Interfaces PhaseWatcher model PhaseWatcher Vx 29 PhaseWatcher Vx 29-lV PhaseWatcher Vx 52 PhaseWatcher Vx 66 3GR23 5GR40 SGR40 e 8GR67 Outlet 3" hub 5" hub 5"hub 6"hub Inlet 3" hub 5"hub S"hub 8" hub 3GR23 SGR40 SGR40 e BGR67 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . ~3-PHASE ~easurements AS PhaseWatcher Vx Design Basis No: Rev.: Date: Page: 6009-1329-0 C 10110101 13 of 16 OuIIet Junction Box DAFC Differential Pressure Transmitter Temperatura Transmitter 6.2 Overall Dimensions Pha..Watcher model C lmate dimenslon8 PhaseWalcher Vx 29 PhaseWatcher Vx 29lV' PhaseWatcher Vx 52 PhaseWatcher Vx 88 NIA 930 722 764 * Vx 29 ·LV is the long Venturi version which is full compatible with 1I1e Vx 52 .. Junction Box fixed on Venturi Weight k 116 116 + 59·' 21'0 398 A'tçfJ~t..t.· /1'11.;~lIffI .He!.' hr, ..t.. qf .aeNfl' - , \, . . No: 800&-1329-D PhsseWatcher Vx Rev.: C ~3-PHASE Design Basis Date: 10110101 Measurements AS Page: 14 of 16 RUiOll'flltftded II'Iltlllhll" O{UU for JIIII(tIU bOa 6.3 Detailed Description The main operating feature of the PhaseWatcher Vx design is the capability to operate and to provide consistent measurements in any kind of multiphase flow regime. 6.3.1 Blind Tee The Blind Tee is located immediately upstream the Venturi throat. The Blind Tee is required in order to be independent of the effects of variable and unpredictable flow regimes which are encountered in multiphase well streams and also of any interaction from upstream devices set on the line (i.e. choke, valves, etc.). The Temperature Transmitter is mounted on the Blind Tee for commodity. The Blind Tee is customer supply (or may be supplied by 3PM as an option). 6.3.2 Detector body The Gamma Detector Housing is made of AIS1316L. Top cover of detector housing is made of AIS 31Sl. Total assembly of the Detector housing, Detector & Cable Penetrator assembly is certified explosion proof for use in zone 1 by NEMKO in Norway. 6.3.3 Source body The source is mounted in a stainless steel body UNS S-31803 filled with lead to protect the users from the extemal radiation. The source is mounted in Source housing by means of a threaded connection. An identification plate is riveted on the Source body to indicate the source serial number, fabrication date and initial activity. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · No: 6009-1329-D PhaseWatcher Yx Rev.: C ~3-PHASE Design Basis Date: 10/10101 Measurements AS Page: 15 of 16 . . 7. PHASEWATCHER SUPERVISORY SYSTEM INTERFACE Data available at the Processed Data Modbus serial communication port include Volumetric flow rates and Phase fractions at standard conditions and at line conditions, Total Mass flow rate, Water Liquid Ratio (WLR), Gas Volume Fraction (GVF), Gas Oil Ratio (GOR), Basic Sediment and Water (BSW) and cumulative values for Oil, Water and Gas. Please refer to the following reference document for a full description of the Serial link interface: · PhaseWatcher Client Serial Link Interface, Modbus RTU. 8. SERVICE COMPUTER 8.1 Service Computer Requirements The Service Computer must operate under Windows NT 4.0, Service Pack 6.0 or higher. Screen resolution must be 1024 x 768 or higher and the computer must have a dedicated communication port, which communicates on RS-422 (directly or via an RS-422 adapter). 8.2 Service Computer Application Software The Service Computer Application Software is supplied on a Compact Disc (CD). The Software features the following main functionality : · Provides user interface for the PhaseWatcher during set-up, reference measurements and service. · HART communication with transmitters is possible through the Service Computer User Interface permitting reading of transmitter measurements and set-up data as well as sending "zero trim" and other commands. · Retrieve and display measured values and calculated data from the DAFC. · Performs storage of configuration and reference parameters, locally or to office network. · Performs storage of data, locally or to office network. · Permits flow monitoring and trending to be displayed. 9. SYSTEM TESTING Every PhaseWatcher Vx will be thoroughly tested in various stages to ensure satisfactory system performance. The following main test and inspection activities are identified: · Hydrostatic pressure test The purpose of this test is to verify the Multiphase Flow Meter Assembly's structural integrity. Reference documentation: PhaseWatcher Vx Hydrostatic Pressure Test procedure. · Junction Box check-out Reference documentation: Junction Box Check-out Procedure PhaseWatcher Vx. · Instrumentation set-up and Inspection · Function test I FAT The purpose of this test is to ensure that the system performs all specified functions satisfactorily and the test will be performed with the complete system installed. There will be no process flow during the FAT. ~ 3-PHA5E ~easurements AS PhaseWatcher Vx Design Basis No: Rev.: Date : Page: 6009-1329-D C 10/10101 16 of 16 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . Reference documentation: PhaseWatcher Vx Function Test / FAT Procedure. . Final Inspection The following main activities will be included in the Final Inspection / Mechanical Completion of the PhaseWatcher : o Review of PhaseWatcher test and inspection reports. o Review of Quality Control Plan and certification documentations. Reference documentation: Final Inspection Procedure for PhaseWatcher Vx - FE report. The hand-over of the PhaseWatcher Vx to the Customer shall be upon the successful completion of these tests and inspections. 10. AVAILABLE OPTIONS 10.1 VFD Display Module A local VFD display at the front of the Data Acquisition Flow Computer is offered as an option. A 100 mm diameter window section will be fitted in the Junction Box lid if this option is selected. The display will start presenting data a few minutes after power-up of the PhaseWatcher. The display automatically toggles between pre-defined screens presenting updated key data (flow rates, fractions, transmitter readings and density data). 10.2 Galvanic Isolators Galvanic Isolators type MTL5042 will be installed in the Junction Box if Intrinsically Safe Transmitter options are selected. The installation of such galvanic isolators will limit the upper operating ambient temperature (Le. Junction Box intemal temperature) to 60°C. 10.3 Service Computer 3PM offers a standard laptop PC intended for indoor Safe Area use only as a Service Computer. 10.4 Flowloop test The optional Flowloop Test Procedure and Test Matrix shall be agreed with Client prior to commencing any testing. 10.5 Datalogger An optional Datalogger Unit may be installed inside the Junction Box. The Datalogger will run the Service Computer Application Software, offering storage of measured and calculated data. Stored data may be uploaded from the Datalogger using pcANYWHERE Software. 10.6 Other optional Items o Blind Tee. o Double block & bleed valves for pressure and differential pressure transmitter. o Stainless steel housings for transmitters. o RS-485 communication adapter. o Thermowell with ANSI flange. o CSA option. MULTI PHASE FLOW METER DESIGN PRESSURE DESIGN TEMPERATURE SERVICE H S 2 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · e) · · · · · · 8· II$TI.lIAIIOIIOTATlOI LlG£. .s, Pl(SSII[ WE n 'A!.IE TCI IE". COITIOUED 'A!.IE '$1 IIPT. DISa LCI LUlL COITIOLLlD 'ALII: III FLOI WETT 'ALIE PI Pl(S$IIE IECOIIIEI ør SlUTIOII 'ALIE PAIl PlES$IIE ALAIII IIGI! 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FLOI COITIOL 'ALIE i[}OIIFI(E .IEI Sa PlESSUIE IELUf 'ALII: -([} IOTAIT DISP. .TEI ....,U. AllESTOI ""G- '''110 I[YlCE Vx . NOTES : 2 . F E D NOTE I: PI VI 29 3GR23 PI VI 52 SGR40 PI VI 88 8GR67 NOTE 2: Blind lee ond clomp hos 10 be ordered uperolely. C 00 22opr2005 ISSUED FOR INFORMATION 01 21apr2005 IDC C) C) C) '" Rn Dote Description Chk Appr en < 3-PHASE nil 4...iIL i, n. ,..,erl, .,.,- .1 3·P.... .$0'_1" AS. II h 1.1 ,. ~. 1..ce4. c: ctpid .. p." ;,.14 .i n..1 u Measurements AS .1' ..; II.. ctl,nl. I.' I. e ~. .inld il .1, ..,. U ... Tit Ie PhaseWotcher Vx Weight "" ... 0 u Process Dia :::IE ram u Dwg number Scale ... 6009-2419-3 0 .t:: c.. . ...... Replaces Replaced by (9 · · · · · · · · · · · · · · · · · · · · .1 · · · · · · · · · · · · · · · · · · · · · · · e . 00 23-APR-2003 INFORMATION BAE DRD BLa 01 22-APR-2003 IDC BAE Bla Rev.: Date: Issued for: Made by: Checked: Approved: Title. Data Sheet for PhaseWatcher Vx US Version Project number Document number. 6010-0137-D Customer I Supplier document number. No. of pages. 3-PHASE Measurements AS 3 Doc. No. . 6010-0137-D ISh!. 213 3-PHASE Measurements AS P.ONo. Project Platform Data Sheet for PhaseWatcher Vx US Area Tag No. Version Manufacturer 3-Phase Measurements AS Model No. VXPS-A (29 mm Venturi Diameter) VXPM-A (52 mm Venturi Diameter) VXPL-A (88 mm Venturi Diameter) ENVIRONMENTAL DATA Item DESCRIPTION VENDOR DATA REMARKS 1 Ambient Temperature (Enclosure Internal) -20 to + 85°C 2 Ambient Temperature Storage -40 to + 85 'C 3 Humidity 0- 100 % RH. 4 Environment Exposed, Saliferous 5 Area Classification Zone 1, Div. 1, Gas Groups C&D, T4 EQUIPMENT SPECIFIC DATA 6 SERVICE 7 Type Vx Meter 8 9 DESIGN 10 Fluid Oil, Water and Gas 11 Pressure 345 barg (5000 psig) 12 Hydrostatic Test Pressure 690 barg (10,000 psig) 13 Temperature -40 to +150 'C 14 Venturi Throat Diameter (VXPS-ANXPM-ANXPL-A) 29.25 mm /52 mm /87.5mm 15 Pressure Design Code ASME VIII, div.2; API 6A 16 17 MATERIAL 18 Venturi Body UNS S-31803 (Duplex) 19 Bolts (Pressure Retaining) ASTM A320 GRL.7, HDG 20 Nuts (Pressure Retaining) ASTM A194 GR4.-S3, HOG 21 Transmitter Housing Epoxy Coated Low-Copper Aluminium 22 (Optional: AISI 316) 23 Transmitter Wetted Parts Hastelloy C-276 24 Impulse Tubing AISI 316L 25 Thermowell AISI 316L 26 Conduit Nipple Copper Free Aluminium 27 Blanking Plug Copper Free Aluminium 28 Sealing Fittings Copper Free Aluminium 29 Support Frame N/A 30 Enclosure (Junction Box) Copper Free Aluminium 31 Sour Service (NACE MR-01-75) (yes/no) Yes 32 Surface Protection None 33 34 PROTECTION 35 Equipment Ingress Protection NEMA 4X 36 Hazardous Area (Electrical) Flameproof 37 Zone 1, Div. 1, Gas Groups C&D, T4 38 INTERFACES 39 Electrical. Power 24 VDC (Ref. Interconnection Diagram) 40 Electrical, Signal RS-422 MODBUS RTU 41 VXPS·A VXPM·A VXPL·A 42 Process Connection (Inlet & Outlet Hub) 5GR40 5GR40 8GR67 43 Vertical Distance Between Flanges 553 mm 553 mm 930 mm 44 Estimated Weight 250 kg 240 kg 400 kg 3-Phase on Zeus\Document File\6010\doc6010-0137-D_Rev 00 PW Vx Data Sheet US.xls · · · · · · · · · · · · · · · · · · · · ie · · · · · · · · · · · e · · · · · · · e · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · PhaseWatcher Vx D-&eet o. 6010-0137-D ISheet 3/3 Tag No.1 DESCRIPTION VENDOR DATA REMARKS Item INSTRUMENTATION 1 Differential Pressure Transmitter Fuji FCX-AII 2 Process connections Via Remote Seal System wI Capillary Tubes 3 Differential Pressure Range Ot05bar 4 Static pressure limit 860 barg 5 Signal HART 6 Local Display (Option) (Yes/No) No 7 Double Block & Bleed Valve (Y es/No) No 8 9 Gauge Pressure Transmitter Fuji FCX-AII 10 Process connections 3/8" Impulse Tube, 11 Autoclave 9/16"-18 UNF Fittings 12 Pressure Range o to 500 barg 13 Signal HART 14 Local Display (Option) (Yes/No) No 15 Double Block & Bleed Valve (Yes/No) No 16 17 Temperature Transmitter Rosemount 3144 18 Process Connections Thermowell 19 Temperature Range -20°C to 150°C 20 Temperature Element Pt-100,4-wire 21 Signal HART 22 Local Display (Option) (Yes/No) No 23 24 Thermowell 1/2" -14 NPT Connection 25 (Optional Flanged Type) 26 27 Gamma Detection System 28 Gamma Detector 3-PM Scintillation Detector 29 Radioactive Source Ba-133 (10 mCi) 30 31 DATA ACQUISITION FLOW COMPUTER 32 Data Acquisition Flow Computer 3PM DAFC 33 Enciosure EXB-12188 N34 34 Local Display (Option) (Yes/No) No 35 36 CERTIFICATION 37 Pressure Retaining Parts EN-10204-3.1B 38 NACE MR0175 39 Electrical Flameproof 40 EMC According to 89/336/EC 41 Total Supply Statement of Compliance 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 - 3-Phase on Zeus\Document File\6010\doc6010-0137-D_Rev 00 PW Vx Data Sheet US.xls · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . Schlumberger Oilfield Services 2525 GarnbeH Schlumberger Alaska 99503 BP Exploration (Alaska) Inc. AOGCC August28,2006 Subject: References for PhaseWatcher Vx multiphase meter technology SPE 71475 Multiphase Flowmeters in Well Testing Applications B.C. Theuveny, SPE; G. Ségéral, SPE and B. Pinguet, SPE; Schlumberger Oilfield Services S P E 63118 Qualification of a Nonintrusive Multiphase Flow Meter in Viscous Flows 0.1. Atkinson, Schlumberger Cambridge Research, UK, M. Bérard, Schlumberger Riboud Product Centre, France, G. Ségéral, SPE, Schlumberger Riboud Product Centre, France. North Sea Flow Measurement Workshop 22nd - 25th October 2002 Kerr-McGee North Sea (UK) Limited - Gryphon Alpha FPSO Monetary Application for Multiphase Meters Jonathan Way, Kerr-McGee North Sea (UK) Limited Ian Wood, Shell U.K. Exploration & Production Bob Staats Testing Field service Manager SCHLUMBERGER OILFIELD SERVICES ............................................ ET + QT= Total volumetric rate QV = volumetric rate the Vortex meter rate the accuracy of Vortex meter ETF accuracy of for gas Note: The above formula calculates mixed stream that of the total gas flow rate CDS tested the Gasunie cyclone in the lab with very little liquid. At a GVF of 90% and higher (up to 99.99% at actual conditions), the cyclone separated at least 98% of all liquid droplets of 10 microns and bigger (at the CDS conditions). The total carry over depends on the incoming droplet size distribution. So at these high GVF's the Gasunie cyclone should stay below the 0.5%v liquid in gas carry over. At lower GVFs we do not have quantitative test data. However the cyclone was tested in a skid similar to EMS ( with Shell and Daniel MPFM) about 5 years ago at NEL. At that time an ultrasonic meter was used to measure the gas rich leg. This meter stopped working if the liquid in gas exceeded 1 % by volume. The UT meter never reached that point during the one day testing. It is therefore reasonable to assume the liquid loading of the gas measured by the Vortex meter is less than 1 %. Assume gas diversion for all flow rates (see Table 6) Assume liquid volume fraction of 0.5% to 1 % in the gas rich leg of HG Skid Vortex Meter Accuracy @ 0.5% 5% Vortex Meter Accurac 1% 10% see Fig. 9 see Fig. 9 Diversion Rate 99% 98% 97% 96% 94% 93% 92% 91% 90% 89% 88% 87% 86% 85% 84% 83% 82% see Fig. 9 HG Accuracy % HG Accuracy % Ave Vortex Accuracy 5% Vortex Accuracy 7.5% 7.6% 7.6% 7.6% 5.1% 5.1% 5.2% 5.3% 5.4% 5.4% 5.5% 5.6% 5.6% 5.7% 5.8% 5.8% 5.9% 6.0% 6.0% 6.1% 6.1% 6.2% 7.7% 7.7% 7.7% 7.8% 7.8% 7.8% 7.8% 7.9% 7.9% 7.9% 8.0% 8.0% 8.0% · · · · · · · · · · · · · · · · · · · '. · · · · · · · · · · · · · · · · · · · · · · · · sepa An Technologies Subsidiary The Gasunie has made this graph long time ago. In the testing they used natural gas and glycol with a liquid percentage ofmax 2 %v. Operating pressure was 40 barg (580 psig) and operating temperature was 25°C (77 OF). , ð Gas Load Factor = * Pgas Pliquid - P gas pgas gas density [kg/m3] Pliquid Jiquid density [kg/m3] vgas superficial gas velocity [m/s] Catch efficiency is defined as the percentage of liquid that is separated by the separator. The liquid was injected into the gas and thus the inlet Jiquid flow was known. The separated liquid is collected in the bottom of the separator and measured as well. In order to get a complete mass balance a filter had been placed in the gas outlet to measure liquid carryover. A catch efficiency of 80 % means that 80 %v of the injected liquid has been separated and 20 %v was carried over with the gas CDS Engineering BV, Delta 101, 6825 MN Arnhem, The Netherlands. Tel: +31267999100 Fax: +31267999119 H.R. Arnhem 090.90.976 Certificate No: 652134 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · cðs~~. separation technology , An oFMC Technologies Subsidiary . CDS-Gasunie cyclone scrubber The GU scrubber was originally developed by Gasunie Netherlands. Gasunie being faced with undesired condensate formation in its gas transmission system in the Netherlands, has tested various types and makes of different gas-liquid separators. On several occasions it was shown that a separator that failed to meet the given specifications of the manufacturer caused the problems due to unremoved liquids. With the experience from testing and theory Gasunie developed its own separation device and tested it in its own high-pressure research facility. Full-scale tests carried out under high pressure showed that even at very high gas flow rates the catch efficiency was close to 100%. Gasunie separators are already more than 15 years in operation and have performed very well. In the Dutch gas transmission system 1000 to 2000 separators are in use. In 1999 the Gasunie cyclone was improved together with CDS Engineering in a j oint improvement project. The result of this project was that the pressure drop over the original Gasunie cyclone was reduced by a factor two while maintaining the same separation performance. The improved separator is called CDS - Gasunie separator and is exclusively marketed by CDS Engineering. The advantages of a CDS-GU cyclone compared to a conventional scrubber are: · Small size and weight as a result of high allowable gas load up to K = 0.9 mls. . High liquid / gas ratio's can be handled . Maintenance friendly, no moving parts or small channels -low fouling tendency. While the initial Gasunie separator has been tested extensively up to K values of 0.9 mis, there are not many references that work at this K value. The most important reference of Gasunie separators at high K value are NAM locations Tjuchem and Bierum that operate at K values of up to 0.9 mls. CDS Engineering BV, Delta 101, 6825 MN Arnhem, The Netherlands. Tel: +31 267999100 Fax: +31 267999119 H.R. Arnhem 090.90.976 Certificate No: 652134 The CDS-Gasunie™ Cyclone Scrubber can be used for separation of liquids (water, hydrocarbon, glycol, etc.) from gases (natural gas and other), for the protection of downstream equipment (compressors, gas turbines, flow meters, etc.). Solid particles (dust, sand, etc.) will also be removed, making the scrubber suitable for use as a gas wellhead separator. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · separation tech An Technologies Subsidiary Principal of CDS-gasunie design Operating Principle The optimised blade geometry brings the combined phase into rotation. The resulting centrifugal force moves the liquid and solid particles towards the vessel wall, where they form a liquid film flowing downwards to the bottom of the vessel. The gas exits the vessel through the central pipe connected to the gas outlet nozzle. The baffles in the bottom of the vessel stop the rotation of the liquid, and the blocking plate prevents liquids from being entrained with the gas. In this way it is ensured, that no gas carry under or liquid carry over can occur. The optimised vane geometry is shown in the picture below. CDS Engineering BV, Delta 101, 6825 MN Arnhem, The Netherlands. Tel: +31 267999100 Fax: +31 267999119 H.R. Arnhem 090.90.976 Certificate No: 652134 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . EMS Control Philosophy CLIENT: ASRC PROJECT: BP Alaska Rev No. Details of Revision Pre pared Checked By Date By Date 5 4 3 2 2nd Issue for Review DS 14-09-05 1 1 SI Issue for Review DS 10-09-05 Business Park IJsseloord 2 CDSt~. Delta 101 6825 MN Arnhem The Netherlands separation technology , Tel. (31) 26 7999100 An -FMC TEchnologiEs Subsidiary Fax. (31) 267999119 Client Order No. Field/Platform BP Alaska End User ASRC Client Document No. CDS Project No. I CDS Document No. 1 Rev No. I No. Pages P04-11006 P04-11006-CPH 2 16 Rev. Date 250603 CWF-2.11 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · CP>St~. separation technology , An <f'MC TEchnologiEs Subsidiary . CDS Project No.: P04-11006 CDS Doc. No.: P04-11006-CPH Revision: 2 Date: 14.09.05 Table of Contents 1 . I ntrod uction ..... .. . . . . . ....... . . . . ........... . . .. . . . . . . . . . . . . ... ......... ... . . ...... .. . . . . . . ...... . . ....... 3 2. Control Philosophy..... ........................................... .............. ......................3 2.1 High Liquid / Low Gas ...........................................................................................3 2.2 Low Liquid / High Gas ...........................................................................................4 3. Configuration of Control Electronics.......................................................... 5 20f6 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · CP>St~. separation technology , An of'MC TEchnologiEs Subsidiary . CDS Project No.: P04-11006 CDS Doc. No.: P04-11006-CPH Revision: 2 Date: 14.09.05 1. Introduction This document is meant to outline the control philosophy for the EMS (Enhanced Multiphase System) skid that is to be supplied to and operated by ASRC. 2. Control Philosophy A particular design consideration for this system is the high design line viscosity of 1000 cP and hence the very low Reynolds numbers that could be present in the venturi of the Topflow multiphase meters. The problem with Reynolds numbers below 5 x 10^4 is that there is no published data as to the performance of converging nozzles and therefore there will be a large uncertainty in to the measurements from the meter. To overcome this issue a different control philosophy is recommended as compared to other EMS installations whereby a minimum, and yet to be determined, pressure drop is to be maintained over the Topflow venturi. Due to the large variations in gas and liquid flow rates separate control valves have been placed in the gas and the liquid lines. The intention of these valves is to regulate the pressure balance over the cyclone separator so that dry gas enters the vortex meter in the gas line of the vessel and that sufficiently degassed liquid enters the multiphase meters in the liquid leg over the complete operating envelope of the unit. The benefit of degassing the liquids as much as possible is that the measurement accuracy of the Topflow meter improves. The intention is to regulate these valves by use of the guided wave radar transmitter located on the cyclone separator in the following methodology. Some control scenarios are explained in some detail below. · At start up the gas valve opening will be 0% and the liquid valve opening 100%. In all scenarios the liquid control will be the source of primary control. The reason for this is to minimise the total pressure drop over the skid. 2.1 High Liquid I Low Gas · The system will then try to regulate a liquid level at a 25% set point by closing the liquid control valve. · If the liquid valve is more than 70% open then the gas valve will start to close until the liquid valve opening reduces below the 70% threshold. The reason for applying a 70% opening maximum is that should a liquid surge enter the vessel there is valve capacity left to help in the disposal of this liquid. Otherwise the cyclone separator would soon fill with liquid and carryover this liquid to the gas leg, thus affecting the accuracy of the gas measurement. 30f6 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · CP>St~. separation technology , An'" TEchnologiEs Subsidiary I Project No.: CDS Doc. No.: Revision: Date: P04-11006 P04-11006-CPH 2 14.09.05 2.2 Low Liquid I High Gas · The system will try to regulate a liquid level at a 25% set point by closing the liquid control valve with the gas valve fully open · Should the dP over the venturi in the Topflow meter be less than the minimum value then the 25% set point of the level transmitter shall be ignored. In this scenario the dP over the venturi will become the controlling parameter. The reason for this is to increase the Reynolds number in the venturi to ensure that no loss of accuracy is seen. · To achieve the minimum pressure drop over the venturi of the Topflow at the lower liquid flows then gas needs to pass through the meter. As a result then depending upon the particular fluids being processed the level in the cyclone separator may fall below the 25% set point. · In this control mode it is likely that the liquid control valve will be nearly closed due to the higher dP over the gas leg. If a liquid slug arrives then there is a risk that the separator will rapidly fill up and therefore the gas vortex meter may become flooded with liquid. To overcome this scenario then should the liquid level rise above 50% in the separator the liquid valve will be forced to open. At the same time the gas control valve will start to close. Once the rise in liquid level is arrested then normal control will be re-established, initially by opening the gas control valve followed by the liquid control valve. 40f6 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · c1!>St~. separation technology , An oftMe Technologies Subsidiary I Project No.: CDS Doc. No.: Revision: P04-11 006 P04-11006-CPH 2 14.09.05 Date: 3. Configuration of Control Electronics The basis for the Topflow electronics is that there will be two computers, one connected to each of the Topflow meters. However there will only be one monitor, keyboard and mouse with a switch box to cross over between the computers. Each Topflow computer will log the usual inputs from the Topflow meters as well as the additional input from the gas vortex meter and the level transmitter. Due to the complexity of the control system in terms of the control valve arrangement an additional third party P&ID controller will be used. Although it has not been finalised we are hoping that this third party P&ID controller can be configured from the Topflow computers to provide only a single interface for the user. A schematic for this proposed control configuration is shown in Figure 1. 50f6 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · CP>St~. separation technology , An of'MC Technologies Subsidiary Outputs Meter 1 ,.. Control Level Set Point to 3'd Party P&ID High Level Set Point to 3'd Party P&ID \...................................................................... ...... Gas Control Valve (Analogue) Liquid Control Valve (Analogue) Outputs Control Level Set Point to 3'd Party P&ID Meter 2 High Level Set Point to 3'd Party P&ID Figure 1: Control Schematic Standard inputs I r....·····...·......·~~~·::~~~...··......·..........] (Analogue) Temperature (Analogue) Pressure drop (Analogue) Conductance (Digital) Capacitance (Digital) . . ..................................................................: Standard inputs I ':.................................................................. Pressure (Analogue) Temperature (Analogue) Pressure drop (Analogue) Conductance (Digital) Capacitance (Digital) ................................................................ t Project No.: CDS Doc. No.: Revision: Date: P04-11 006 P04-11006-CPH 2 14.09.05 Additional inputs :............................................................... Gas Flow Gas Valve Positioner Liquid Valve Positioner Level Transmitter ................................................................... 60f6 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · --' w :z: « CL u :::; => « 0::: o >- :c ::::;¡ a 0::: '-'- V-100 I.D. T/T DESIGN PRESSURE DESIGN TEMP. 364 mm 2860 mm 1335 psig -50/+250' F [I] 600# RF --- NOTE 3 ----- --- --- L "x3" IK~~ I 2" ------------------ m 600# RF l1!U ---- 4" NOTE 6 ~z - - LCV 002 NOTE 6 a '-'- SAFE AREA MULTIPHASE METER CONTROL COMPUTER -- ----------------------- FB C()] 2" <D W I- a :z: I <D W I- ~ FB 1 4" I IC()] -5xD~ 4" 4" NOTE 6 VORTEX NOTE 6 I TURBINE METER (FUTURE) <D I ~IÖ 2" æÇd NOTE 6 I FB IC()] <D I w ~ 1 FB FB 3" C()]~C()] I NOTE 6 600#12500# -I I I I 1 1 1 I I I [I] 1 OUTLET 5K I" 1 1 ~ 'II SCOPE CDS II I 1 I I I 1 1 I [IJI INLET 5K I "IH 1 3" FC SDV 3" 2500# NOTE 1 NOTE 6 ~PSV 4" I 3" H2 CHOKE FB 1 NOTE 6 IQ;J 7fJTC01 I 2500# 1600# <D 6"x3" w I- a æ Çd æ ÇdNOTE 2 :z: V-100 NOTE 6 ~ NOTE 5 IK~~ I 1 [I] 2" <D W I- a :z: NOTE 6 0::: i=! w :::0; w en «: = CL 1= -' ::::> :::0; æÇd 2" NOTE 6 2" <D W I- 3"x4" ~ FB r~C()] 3" I -------- 4"x3" 4"x6" NOTE 1: NOTE 2: NOTE 3: SKID BYPASS LINE. BYPASS LINE AROUND CHOKE. DESIGN PRESSURE STATED IS EQUIVALENT TO A FULL ANSI 600# RATING AT 250·F. DESIGN OF THE SKID IS TO BE SUCH THAT THE FULL ANSI 600# RATING, APPLIES AT ALL TEMPERATURES IN THE DESIGN TEMP. RANGE. DELETED GUIDED WAVE RADAR 1YPE INSTRUMENT WITH INTERNAL MAGNETIC LEVEL GAUGE. )Ç THREADOLET WITH THREADED PLUG 0::: i=! w :::0; w en «: = CL I":; ::::> :::0; 3" NOTE 6 NOTE 4: NOTE 5: NOTE 6: 9 OMMENTS INCORPORATEO 80905 MG DS B DMMENTS INCORPORATED 1608D5 MG DS 7 OMMENTS INCORPORATED 1 D0805 MG DS 6 COMMENTS INCORPORATED 508D5 MG DS 5 OMMENTS INCORPORATED 408D5 MG DS Date Drown Checked Description of Revision Dro:r 1~~:~5 NM~me rnc: ~ Checked - separation t~~~~^. Process 190405 DS An"Technolo lea Subaldlor V Project BP WEll TESTING A 1 Cnent FMC Scale Title P&ID MULTI PHASE METERING SKID Rev. -- ------------------~ This drowí1g. of which COS Engineering BY' ill owner, may neither be multiplied nor given to third parties, in particular competitonl. Improper use ill prohibited by Law and causes nabillty for damages. 9 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · , . DIstribution: 3PM file Document title: PhaseWatcher Vx Function Test/FAT Procedure Comments: ....... ~ (" rJ7 ~ E 15-JUL-2002 PRODUCTION BAE \..f5RD /€.gÁ D 23-JAN-2002 PRODUCTION BAE DRD BLa C 06-NOV-2001 PRODUCTION BAE DRD BP B 1 O-OCT -2001 PRODUCTION JR BP/Bla BP A 17 -SEP-2001 PRODUCTION DRD BAE EgA 00 22-JAN-2001 FOR PRODUCTION RELEASE JTv BLa EgA 01 17-JAN-2001 IDC JTv BLa Rev.: Date: Issued for: Made by: Checked: Approved: Project number. Project name. PhaseWatcher Vx Customer document number. NJA 3-Phase Measurements document number. No. of pages. ~3-PHASE 6009-133O-D 20 Measurements AS . , No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~ 3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 20f20 INDEX 1 INTR 0 D U CTI ON ..........................................................................................................................................3 2 REFEREN CES .................................................................................................................................................3 3 D ESCRIPTI ON ................................................................................................................................................4 4 TEST SE TUP .....................................................................................................................................................4 5 SAFETY I SPECIAL REQUIREMENTS .....................................................................................5 6 PREP ARA TORY CHECKS ...................................................................................................................5 7 EQUIPMENT VISUAL INSPECTI ON ..........................................................................................6 8 POWER-UP TEST FOR TIlE PHASEW A TCIlER VX SYSTEM ...........................7 9 PHASEW A TCHER VX CONFIGURA TION ...........................................................................8 1 0 SOFTWARE VERSI ON ..........................................................................................................................18 11 EXIT .......................................................................................................................................................................18 12 PUN CD LIS T ...................................................................................................................................................19 13 TEST RESULTS ...........................................................................................................................................20 H:\Engineering\6009\6009-1330-D_rev e.doc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 30f20 , . 1 INTRODUCTION 1.1 Purpose Prior to shipping the PhaseWatcher Vx Multiphase Flow Meter to site, a complete system test will be performed at 3-Phase Measurements AS premises. The purpose of this test is to ensure that the system performs all specified functions satisfactorily. The test will be performed with the complete system installed. There will be no process flow during the FAT. 1.2 Applicable Standards and Specifications PhaseWatcher Vx Design Basis 1.3 Abbreviations PW DAFC FAT PhaseWatcher Vx Multiphase Flow Meter Data Acquisition Flow Computer Factory Acceptance Test 2 REFERENCES Latest revision of the following drawings and documents shall be made available during the FAT. Title PhaseWatcher Vx Main Spec. General Arrangement PhaseWatcher Vx Interface Drawing PhaseWatcher Vx General Arrangement PhaseWatcher Vx General Arrangement - List of materials PhaseWatcher Vx Interconnection Diagram PhaseWatcher Vx Junction Box Wiring PhaseWatcher Vx Logs And Parameters PhaseWatcher Vx Junction Box Assembly PhaseWatcher Vx Junction Box Assembly L.O.M. Service Computer User Manual PhaseWatcher Vx Client Serial Link Interface, Modbus RTU PhaseWatcher Vx Instrumentation Setup and Inspection Report PhaseWatcher Vx Final Inspection Procedure Schedule of Equipment in Hazardous Area PhaseWatcher Vx Name Plate H:\Engineering\6009\6009-1330·D _rev e.doc . , No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~1-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 40f20 3 DESCRIPTION The PhaseWatcher Vx Multiphase Flow Meter comprises the following components: Venturi Section. Gamma measurement system compromising Detector and Source assembly. Instrumentation. Data Acquisition Flow Computer located in a flameproof enclosure. The FAT includes full functionality of testing all the instrumentation, the PhaseWatcher Vx Data Acquisition Flow Computer (DAFC), and an optional Service Computer. including Software and the communication link from the DAFC to the Service Computer. The FAT includes the following main activities: Equipment Visual Inspection Power-Up Test for PhaseWatcher Vx System Instrumentation Tests User Interface / Parameter Download Final Results / Result Files Alarms Prior to the FAT, the PhaseWatcher Vx will go through a test and inspection program, where all initial tests will be performed. These tests and results are reported in the · PhaseWatcher Vx Instrumentation Setup and Inspection Report" 4 TEST SETUP The FAT will be performed with the complete PhaseWatcher Vx unit and the Service Computer installed. Communication link between PhaseWatcher Vx unit and Service Computer will be via RS-422 serial link/adapter. All instrumentation will be hooked up. H:\Engineering\6009\6009-1330-D_rava.doc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 50f20 , . 4.1 Test Equipment The following test equipment is available and checked prior to start of the FAT: DESCRIPTION SIZElRANGE REMARKS Digital Multìmeter, With true RMS capability and averaging function PC with Service Computer application software installed RS-422 / RS-232 adapter 24 VDC Power Supply 5 SAFETY I SPECIAL REQUIREMENTS The PhaseWatcher Vx Multiphase Flow Meter uses a Ba-133 isotope as its Gamma Source for the fraction meter. The source is contained within the Flow Meter in a way that extemal radiation is kept below the requirements set forward in EC Directive 96/29Æuratom (S 1 µSv/h at 0.1 m distance from accessible surfaces). The FAT procedure does not Involve any handling of the 8a-133 source. 6 PREPARATORY CHECKS The following test activities shall be successfully completed and documented prior to commencement of the FAT. ITEM Inspection Description Check 6.1 PhaseWatcher Vx Instrumentation Setup and Inspection Report H:\Englneering\6009\6009-1330-D_rev e.doc . , No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 60f20 7 EQUIPMENT VISUAL INSPECTION The purpose of this part of the FAT is to inspect all instrumentation components of the PhaseWatcher Vx- hardware for faults or damages and to ensure that the equipment is properly mounted and in accordance with the design drawings. Item Inspection Description Design Accepted Requirement (YesINo) 7.1 Check all electrical installations on the No visible damage. PhaseWatcher Vx unit for mechanical damage. 7.2 Check that all instrument items and junction PhaseWatcher Vx GA drawing. boxes on the PhaseWatcher Vx unit are mounted properly and in accordance with the GA drawina. 7.3 Check that correct tag numbers are fitted on all Clients documents I PhaseWatcher instrumentation, cables and junction boxes Vx Interconnection Diagram installed on the PhaseWatcher Vx unit. 7.4 Check that all cables are properly mounted on Junction Box I Instrumentation the PhaseWatcher Vx unit. PhaseWatcher Vx 7.5 Check that all cable glands installed on the PhaseWatcher Vx Interconnection PhaseWatcher Vx unit are of correct type, and Diagram are fully tiahtened. 7.6 Check the labelling on all instruments and Schedule of Equipment in Hazardous junction boxes installed on the PhaseWatcher Vx Area unit, for correct EX-certification. 7.7 Check that the gamma detector housing is fitted "DO NOT REMOVE HOUSING BEFORE THE BARIUM SOURCE with a red warning sign for radioactive radiation. HAS BEEN REMOVED" 7.8 Check that the metal cover on the gamma Date of manufacture: source is fitted with a Radioactive Material identification sign. Record values. Serial number: Check that the cover is sealed with two off seal Isotope: 133 Ba strings. Activity: 370 MBq 7.9 Check that the PhaseWatcher Vx Nameplate PhaseWatcher Vx GA drawing. with CE Label is fitted. Nameplate drawina 7.10 Check that the "face to face" dimension PhaseWatcher Vx Interface drawing. lGravloc hubs) of the venturi is correct. 7.11 Check that the Alignment pin is correct in position H:\Engineeñng\6009\6009-1330-D_reve.doc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · '. · · · · · · · · · · · · · · · · · · · · e; · · · · · · , . No.: 6009-1330 . D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test! FAT Procedure Date: 15.07.02 Measurements AS Page: 70f20 8 POWER-UP TEST FOR THE PHASEWATCHER VX SYSTEM The purpose of this test is to verify that the PhaseWatcher Vx Service Computer automatically starts all necessary software, without any error message, when the system is powered up. The following test activities shall be successfully completed and documented. Item Inspection Description Check 8.1 Using the digital multimeter in Volt DC mode, check that the output voltage of the 24 VDC power supply is 24 VDC +/- 2 VDC. Record the value, U = VDC (average value measured at PhaseWatcher Vx entry terminals) 8.2 Connect the 24 VDC to the PhaseWatcher Vx with the digital multimeter in Ampere DC mode in series with one of the power wires. 8.3 Power up the PhaseWatcher Vx system. After 2 minutes, record the current consumption, I = ADC (average value measured). Power down the PhaseWatcher Vx and remove the multimeter. 8.4 PhaseWatcher Vx power consumption is calculated as U * 1= W 8.5 Connect the PhaseWatcher Vx Service Computer to the Flow Meter via the RS422 to RS232 adapter. Power up the Service Computer. 8.6 Power up the PhaseWatcher Vx system. After 3 minutes, start the PhaseWatcher Vx Service Computer proaram on the PhaseWatcher Vx Service Computer. 8.7 Push the "Modbus -> Configuration" button and check the following: COM port: COM1 Baudrate: 38400 Databits: 8 Parity: Odd Stopbits: 1 Slave address: 12 Modbus timeout: 1200 Max retransmissions: 3 Max data bytes: 256 No handshake signals shall be activated. 8.8 Push the "Mdbus -> Connect" button 8.9 Check on the Service Computer that the start-up routine is performed without any error- messages. 8.10 Let the system run for two minutes, and check that time/date data transmitted by the DAFC corresponds to the time/date setting on the Service Computer. 8.11 If a display unit is installed on the PhaseWatcher Vx, check that time/date data displayed locally on the PhaseWatcher Vx unit corresponds to the time/date setting on the Service Computer. Check that production data, count rates, pressure and temperature data are being updated at regular intervals at the display. H:\Engineering\6009\6009-1330-D_rev a.doc . , No.: 6009-1330· D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 80f20 9 PHASEWATCHER VX CONFIGURATION 9.1 Introduction The purpose of this test is to verify and download correct parameter setting to the PhaseWatcher Vx unit. In addition, result windows will be monitored and functions in these windows will be tested. The purpose of section 9.8 and 9.9, is to verify that the Phasewatcher is configured with all well dependent parameters existing in the document ·Phasewatcher Vx Logs&Parameters". If specific well information does not exist from the client, the Phasewatcher will be set up with "default" values for these parameters, and these values are not written in the ·Phasewatcher Vx Logs&Parameters". The transmitter alarm limits have to be set to values that will not trig alarms based on testing conditions. Alarm limits may later have to be changed to fit operating conditions for the actual field. The PhaseWatcher Vx Service Computer Program must be running. 9.2 Flowmeter Parameters The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.2.1 Check that the venturi dimentions are set according to section 2.1 if 29mm venturi, 2.2 if 52mm or 2.3 if 88mm, of Phasewatcher Vx Logs & Parameters 9.2.2 Check that the interpretation model parameters are set according to section 2.4 of PhaseWatcher Vx Logs & Parameters 9.2.3 Check that the Gamma detector parameters are set according to section 2.5 of Phasewatcher Vx Logs & Parameters 9.2.4 Check the system alarm limits are set according to section 2.6 of PhaseWatcher Vx Logs And Parameters. 9.2.5 Check the transmitter alarm limits are set according to section 2.7 of PhaseWatcher Vx Logs And Parameters. 9.2.6 Check that Gamma detector alarm limits are set according to section 2.8 of PhaseWatcher Vx Logs And Parameters. H:\Engineering\6009\6009-1330-D_rav a.doc · · · · · · · · · · · · · · · · .' · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · .' · · · · · · · · · · · · · · · · · , . No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~~ Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 9 of 20 9.3 Transmit Command (Flowmeter Parameters) The values in the list shown in the report window are now the actual values for the configuration data which is ready for transmission to the PhaseWatcher Vx DAFC. The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.3.1 Press the "Update DAFC" push-button and confirm "Update" when prompted. Check that no error message occurs. 9.3.2 The new configuration file will now be updated to the PhaseWatcher Vx DAFC. 9.4 Nuclear stabilisatlon temperature The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.4.1 Press the "Nuclear" flip folder. 9.4.2 Check that 'Stabilisation temperature" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 3. Record Value: 9.4.3 Temporarily set gamma detector stabilisation temperature to 40°C for testing. Press "Set Stabilisation Temperature', and observe that the detector temperature readings decrease. Return to 60 °C, and press ·Set Stabilisation Temperature" again, to return to original conditions.. 9.5 Zero Trim procedure The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.5.1 Check the zero trim of the DP transmitter (acceptance criteria: 0 ± 1 mbar). If necessary, perform a zero trim according to "Instrumentation Setup and Inspection Procedure". 9.5.2 Go to section 9.6 if venturi section is liquid filled. Check the zero trim of the PT transmitter (acceptance criteria: 0.0 ± 0.1 bar). If necessary, perform a zero trim according to "Instrumentation Setup and Inspection Procedure". H:\Engineering\6009\6009-1330-D 3av a.doc . , No.: 6009-1330 . D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 10 of 20 9.6 DPV Offset In order to do a Zero-trim off the DP sensor with the pipe filled with liquid is it possible to set the DPV Offset by calculating the static pressure between the pressure ports : DPV Offset =. [ROIIqUId(kg/m~x 9.81 (mIs2) x Distance DP ports(m)] NB : The DPV Offset should always be 0 mbar with the pipe gas filled (and at no-flow conditions). The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.6.1 Press the "Reference" flip folder. 9.6.2 Insert the value off DPV Offset as calculated above. 9.6.3 Refer to the Zero Trim Procedure in chapter 9.5 in order to do the Zero Trim. 9.7 Empty pipe reference The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.7.1 Press the "Reference" flip folder. 9.7.2 Verify that the gamma detector has reached the set temperature (± 0.5 °C) as stated in paragraph 9.4.2 9.7.3 Tick the "Empty pipe, Air" box 9.7.4 Press "Make reference" button in order to activate the Empty pipe reference. 9.7.5 When the highest value of the standard deviations for "LE", "HE" and "356" is less than 0.02 %, the accuracy of the reference is sufficient. 9.7.6 Press the "Update DAFC" button in order to activate the Empty pipe reference. 9.7.7 Record the following values in the "Empty pipe reference window". Linearised count rates: LE: ............................... cps st dev:.............................. 0/0 HE: ............................... cps st dev:.............................. 0/0 356: ........ ........... ............ cps st dev:.............................. % Total: .................... ........... CDS H:\Engineering\6OO9\6009-1330-D_r9v 9.doc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · i. · · · · · · · · .' · · · · · · · · · · · I) .' · · · · · · · · · · · · · · · · · · · · · · No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~ 3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 11 of 20 , . 9.8 Mass Attenuation Well Dependent Parameters The items under 9.8.1 to 9.8.3 are only applicable if well dependent parameters exists. (Ref. 9.1). Items 9.8.1 to 9.8.3 applicable (YesINo): 9.8.1 011 mass attenuation The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.8.1.1 Press the "Reference" flip folder. 9.8.1.2 Tick the ·Oil - Operator input" button. 9.8.1.3 Press the "PVT" flip folder. 9.8.1.4 Press the "Mass attenuations" button in the "Oil box". 9.8. 1.5 Check that "S" (Sulphur) is set to the value in PhaseWatcher Vx Logs And Parameters 9.8.1.6 Check that "C6H12" is set to the value in PhaseWatcher Vx Logs And Parameters 9.8.1.7 Record oil mass attenuation values: LE: ............................... m2/kg HE: ............................... m2/kg 356: ............................... m2/kg H:\Englneering\6009\6009-1330-D_rev e.doc . , No.: 6009-1330 - D PhaseWatcher Vx Rev.: E #f." 3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 12 of 20 9.8.2 Water mass attenuation The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.8.2.1 Press the "Reference" flip folder. 9.8.2.2 Tick the "Water - Operator input" button. 9.8.2.3 Check that "Mass attenuation - LE" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 6.2 9.8.2.4 Check that "Mass attenuation - HE" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 6.2 9.8.2.5 Check that "Mass attenuation - 356" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 6.2 9.8.2.6 Press the ·PVT" flip folder. 9.8.2.7 Press the "Mass attenuations" button in the 'Water box". 9.8.2.8 Record water mass attenuation values: LE: ............................... m2/kg HE: ............................... m2/kg 356: ............................... m2/kg H:\Engineering\6009\6009-1330-D_rev e.doc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ \........",/ No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 13 of 20 9.8.3 Gas mass attenuation The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.8.3.1 Press the "Reference" flip folder. 9.8.3.2 Tick the "Gas - Operator input" button. - 9.9 PVT Well dependent parameters The items under 9.9.1 to 9.9.4 are only applicable if well dependent parameters exists. (Ref. 9.1). Items 9.9.1 to 9.9.4 applicable (VesINo): 9.9.1 011 PVT parameters The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.9.1.1 Press the "PVT" flip folder. 9.9.1.2 Check that the "PVT model type" is set to "Black Oil". 9.9.1.3 Select "Dead oil". 9.9.1.4 Press the Oil density "CalculateH button 9.9.1.5 Check that oil"Sample density" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.2 9.9.1.6 Check that oil "Sample temperature" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.2 9.9.1.7 Press the "Ok" button in order to calculate the oil PVT values used in the model. H:\Englneering\6009\600g..1330-D_rav a.doc No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3.pHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 14 of 20 9.9.2 Viscosity 011 The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.9.2.1 Press the "PVT" flip folder. 9.9.2.2 Press the calculate button on Viscosity at SC in the "OIL box· 9.9.2.3 Check that oil HSample viscosity" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.3 9.9.2.4 Check that oil "Sample temperature" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.3 9.9.2.5 Press the tlOKII button in order to calculate the oil PVT values used in the model. 9.9.3 Water PVT parameters The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.9.3.1 Press the "PVT" flip folder. 9.9.3.2 Select "Dead water". 9.9.3.3 Press the water density "Calculate" button 9.9.3.4 Check that water "Sample densityH is set to the value in Phase Watcher Vx Logs And Parameters, Chapter 7.4 9.9.3.5 Check that water "Sample temperature" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.4 9.9.3.6 Check that water ·Viscosity at SCII is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.4 9.9.3.7 Press the "Ok" button in order to calculate the water PVT values used in the model H:\Engineering\6009\6009-1330-D _rev e.doc - ~ ~ No.: &009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 15 of 20 9.9.4 Gas PVT parameters The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.9.4.1 Press the IIpVT" flip folder. 9.9.4.2 Select IIN2". 9.9.5 Viscosity liquid The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.9.5.1 Press the "PVT" flip folder. 9.9.5.2 Check that "Inversion point" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.6 9.9.5.3 Check that ''Transition band" is set to the value in PhaseWatcher Vx Logs And Parameters, Chapter 7.6 "',¡<',:¡~./ H:\Engineering\6009\6009-1330-D_rev a.doc No.: 6O()9..1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 16 of 20 9.10 Transmit Command (Well dependent parameters) The values in the list shown in the report window are now the actual values for the configuration data witch is ready for transmission to the PhaseWatcher Vx DAFC. The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.10.1 Press the "PVT" flip folder. 9.1 0.2 Press the "Update DAFC" push-button and confirm "Update" when prompted. Check that no error message occurs. Perform a temporary change for any of the PVT parameters, to check the updating of the DAFC, if no parameters in the PVT flip folder has changed at this point 9.1 0.3 The new configuration file will now be updated to the PhaseWatcher Vx DAFC. 9.11 Save file The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.11 .1 Enter "Configuration Name" (e.g. "FAT setup") on the file pull down menu. 9.11.2 Press the "File -> Save as..." button in the upper left corner. All the updated values used in the PhaseWatcher will now be saved in this file. 9.12 Metering Menu This is the main window in the PhaseWatcher Vx Service Computer Program. The "Flow Results", "Status" and "'nput I measured values" column are displayed in this window. The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.12.1 Select the "Metering" window by clicking the "Metering" flip folder. 9.12.2 Check that the displayed values have correct readings based on operating conditions. H:\Engineering\6009\6009-1330-D _rev e.doc ~ ~/ No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test J FAT Procedure Date: 15.07.02 Measurements AS Page: 17 of 20 9.13 Diagnostics menu This is a utility window where all version numbers of software/models and serial numbers off hardware is listed. Also all the necessary control voltages are displayed in this window. The following test activities shall be successfully completed and documented. Item 9.13.1 Inspection Description Click the "Diagnostics" flip folder. Check 9.13.2 Record the following software Version numbers and hardware Serial numbers: DAFC application software, Version number: ...................................... Nuclear linearisation model, Version number: ..................................... Interpretation model. Version number: ................................................ Gamma detector. Serial number: ........................................................ HART and analog modem card, Hardware version: ........................... Firmware version: ........................... Serial number: ................................ 9.13.3 Record the following DAFC diagnostic parameters: Input voltage: .................................. Volt ISO supply: ..................................... Volt +5. ±12 internal: .............................. DAFC temperature: ......................... °C 9.13.4 Activate the push button "Update Status· and verify that all transmitters are communicating and report without any alarms. Wait 30sec before activating the "Stop Update· button. '- H:\Engineerlng\6009\6009-1330-D _rev e.doc No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 18 of 20 9.14 Alarm I Status menu This is an alarm listing in the PhaseWatcher Vx Service Computer Program. The "Date", "Time", "Description", "State" columns are displayed in this window. All alarms since program start-up are listed in chronological order. The following test activities shall be successfully completed and documented. Item Inspection Description Check 9.14.1 Click the "Alarm I Status" flip folder. 9.14.2 Check that there are not any active alarms. ("Nuclear Linarisation Model Error" alarm will be active if not full calibration is performed, and "Dynamic DP -low" alarm will be active because of no-flow conditions) 10 SOFTWARE VERSION The following test activities shall be successfully completed and documented. Item Inspection Description Check 10.1 Record the software revision on the running PhaseWatcher Vx. Press "Help -> About" to veiw Service Computer Version ........................................ 11 EXIT The following test activities shall be successfully completed and documented. Item Inspection Description Check 11.1 Select the button "File -> Exit". 11.2 The Service Computer PhaseWatcher Program terminates and command is returned to Windows NT. H:\Engineering\6OO9\6009-1330-D _rev e.doc ~~ """'" No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 19 of 20 '-" ~ 12 PUNCH LIST -- Category A:. To be completed within shipment Planned Entered Complete Category B: To be completed at later stage by by Punch CAT. DESCRIPTION Date (Sign) 3PM. CLIENT. DATE item (Ref. to drawing or document) '- COMMENTS VERIFIED 3PM CLIENT Name Sign. Date H:\Engineering\6009\6009-1330-D _rev e.doc No.: 6009-1330 - D PhaseWatcher Vx Rev.: E ~3-PHASE Function Test I FAT Procedure Date: 15.07.02 Measurements AS Page: 20 of 20 13 TEST RESULTS The following shall be attached to the FAT report upon presentation to the parties for final acceptance and signature: Above Results Sheets completed and signed as applicable. Date: Date: 3-PM Name: Client Name: (PRINT NAME) (PRINT NAME) 3-PM Signature: Client Signature: H:\Englneering\6009\6009-1330-D _rev e.doc ~ .~ Distribution: 3PM file Document title: PhaseWatcher Vx FINAL INSPECTION PROCEDURE Comments: ~ -- - ~< - ~ .-~ Uo'SP A 1 O-OCT -2001 JR ~ - \I . 00 07 -SEP-2001 PRODUCTION DRD BLa EgA 02 14-DEC-2000 CONSTRUCTION AFolBlalBP JTv JTv 01 04-DEC-2000 IDC AFOIBLa JTv JTv Rev.: Date: Issued for: Made by: Checked: Approved: Project number. Project name. PhaseWatcher Vx Customer document number. NIA 3-Phase Measurements document number. No. of pages. ~3-PHASE 6009-1365-D 13 Measurements AS ~ 3-PHASE ~easurements AS PhaseWatcher Vx Final Inspection Procedure No.: Rev: Date: Page: 6009-1365-D A 10/10/01 2 of 13 TABLE OF CONTENTS 1.0 INT R OD U CTI ON .......... ............... .... ....... .... ..... .... ....... .... ............... .... ........ ........... ....... ....... .... .... .... ..................... 3 1.1 PURroSE.............................................................................................................................................................. 3 1.2 ABBREVIATIONS. ........ ......... ..... ... .... .... ........ ............... .... ........ .... .... ...... .......... .... ....... ... ....... ........... ..... ....... .........3 2.0 REFERENCES....... .... ........ .... ....... .... ....... .... ......... ........... ........ ....... .... .... .... ......... ......... ...... .................. ....... ......... 3 3.0 D ESCRI P1'I 0 N .. .... ........ .... .... ....... ........... .... ..... .... ............... ............... ............ ............. ..... .... ............ ....... ....... ...... 3 3.1 MECHANICAL DESCRIPTION ......... ........ ........................................... .... .................. ...... ................ ..... .............. ...... 3 4.0 SAFETY I SPECIAL REQUIREMENTS ........................................................................................................... 4 5.0 PREP A RA TORY CHECKS ........ ........... ......... ........... ..... ............ .......... ................. .... .... ......... .... ....... .... ............. 4 5.1 PRECEDING CONTROL AcnVITIES ... ........ ................... ....... ................. ............ ...... ...... .... ........ .... ............ ....... ...... 4 6.0 INSPECTION......... ...... ...... .... ........... ........... ..... ....... .... .... ....... .... .... .... ........ .... ............. ................. .............. .......... 5 6.1 FLow METER MECHANICAL COMPLETION ...................... ............ ...... .............. ..... ............... ................ ................. 5 6.2 MPFM CABUNG AND JUNcnON Box INSTALLATION........................................................................................10 6.3 LABELS AND WARNING SIGNS ............. ........ ....... ........... ..... ........ ......... ................... ............. .............. ................ 11 7.0 PUN CH LIST ..... .... ............... .... .... ....... ......... ....... .... ........... ...... ..... ...... .... ........... .... ......... .... ................ ....... ........ 12 8.0 RFSUL T SHEE TS ............. ........ .... ....... .... ......... .................. ........ ............. ........... ...... ........... .................... ....... ........ 13 ~ ~ PhaseWatcher Vx No.: 6009-1365-D ~3-PHASE Rev: A Final Inspection Procedure Date: 10/10/01 Measurements AS Page: 3 of 13 1.0 INTRODUCTION Purpose The purpose of this test procedure is to perform final completion inspection prior to packing and shipment of the PhaseWatcher Vx Abbreviations 3PM 3-Phase Measurements AS FMFL Frank Mohn Flatøy AS GDH Gamma Detector Housing JB Junction Box PL Punch List SIN Serial Number 2.0 REFERENCES Latest revision of the following drawings and documents are referred to in this procedure and shall be made available prior to commencing final inspection : Documentation Name Ref PWYx88 PWYx52 PWVx29 Standard Block&bløed Standard LV 60()9..()14&4 6009-1551-4 6009-15464 6009-1589-4 6009-16034 6009-0734-3 6009--1549--3 6Q09..1544-3 6009-158&3 6Q09..1602-3 ~~,,~.=-=-~~~ 6OQ9.1129--D 2 PWVx GENERAL ARRANGEMENT LOM PWVxGENERALARRANGEMENT PW Vx HYDROSTATIC PRESSURE TEST PROCUD!!RE ___<_ NAME PLATE DETECTOR HOUSING ASSEMBLY· LO.M DETECTOR HOUSING ASSEMBLY BARIUM SOURCE ASSEMBLY BARIUM SOURCE ASSEMBLY LOM WARNING LABel FOR RADIOACTIVE SOURCE 6 WARNING LABel FOR RADIOACTIVE SOURCE 7 Ex LABEL FOR 3PM GAMMA DETECTION SYSTEM 8 Vx 29 mm-L V Is the long Venturi version which is full compatible with the Vx 52 mm (Same outside dimensions). . FUNCTION TEST 1 FAT REPORT . FLOWLOOP TEST REPORT (If any) 3 4 ~_~~ ··."__,,,~__..~~"rð'~~~"~___"· 5 6009-1339-4 6009-1338-3 6009-1109-3 6009-1110-4 3.0 DESCRIPTION 3.1 Mechanical Description Each PhaseWatcher Vx assembly comprises the following components: Vx-section Instrumentation mounted on Vx-section. Junction Box (delivered as loose item) Double block & bleed valves for DP & P PhaseWatcher Vx No.: 6009-1385-D Rev: A ~3-PHASE Final Inspection Procedure Date: 10/10/01 Measurements AS Page: 4 of 13 4.0 SAFETY I SPECIAL REQUIREMENTS The PW Vx uses a Ba 133-source as its gamma-source for the fraction meter. The source is contained within the PhaseWatcher in such a way that external radiation is below the requirements set forward in Council Directive 96/29Æuratom (1 µSvlh at 0.1 m distance from accesible parts). CAUTION: CAUTION: Any work at the Barium 133 isotope J housing or Gamma Detector shall be performed by authorized personnel only. The Barium133 isotope activity is 10 mCi ( millicuries). All safety regulations applicable at the test site shall be adhered to by all personnel attending 5.0 PREPARATORY CHECKS Equipment Serial No : 5.1 Preceding Control Activities The following activities for the test object shall be successfully completed and documented prior to commencement of test (with no outstanding items): ACTIVITY 3PM Report doc. No. Checked Function Test / FAT report Multiphase Flow Loop Test report(if any) Punch List cleared (if any) PL NOTE: Documentation of above activities may be presented according to manufacturers internal system for the purpose of this test. Date: Comments : 3PM Signature : CLIENT Signature: - '~ ~ PhaseWatcher Vx No.: 6009-1385-D Rev: A ~3-PHASE Final Inspection Procedure Date: 10/10/01 Measurements AS Page: 5 of 13 6.0 INSPECTION 6.1 Flow Meter Mechanical Completion Check the føllowlna on the Pha_Watcher Vx Detector houslna : DETECTOR HOUSING \~~ Step Inspection Description ItemlRef Nb Check Reap. Sign 6.1.1 Check that the M6 bolts are mounted 4/4 FMFL 6.1.2 Check that collimator Is mounted 5/4 FMFL 6.1.3 Check that o-ring is mounted 614 FMFL 6.1.4 Check that o-ring Is mounted 9/4 FMFL 6.1.5 Check that blank plug Is Installed 10/4 FMFL 6.1.6 Gamma Detection System Check that the GDH and Detector are clean and that all a-rings are in place /4 (on top of the detector, bottom of detector and 2 off around the body of the detector). Check that the Lema connector Is locked 214 6.1.7 in the Detector 3PM 6.1.8 Place a new Silica Gel bag type DRY-PAX 3 grms (Davison Chemical), 214 or similar in the GDH. Fit it to the Detector handle with a plastic tie 6.1.9 Immediately perlorm nitrogen purging and close the GDH making sure that the wires are not pinched. 6.1.10 Check that the shielding plate is installed 7/4 FMFL 6.1.11 Check that all M 16 bolts (4 off) are 4/4 mounted with correct torque FMFL · Bolts I Nuts: Apply torque as per 6009-1129-0 (197 Nm) Date: Comments: I 3PM Signature : CLIENT Signature : PhaseWatcher Vx No.: 6009-1365-D Rev: A ~3-PHASE Flnallnsp8Ctlon Procedure Date: 10/10/01 Measurements AS Page: 6 of 13 A ...-, I i , i ~. A SECT ION A-A Figure 1 : Source Housing Assembly (Reference drawing 6009-1109-3, LOM 6009-1110-4) "- ~ ~ Ph8seWatcher Vx No.: 6009-1365-0 ~3-PHASE Rev: A Final Inspection Procedure Date: 10/10/01 Measurements AS Page: 7 of 13 Check the followlna on the PW Vx Source Houslna : SOURCE HOUSING Step Inspection Description Item NblRef Nb Check Resp. Sign 6.1.12 Check that o-ring is mounted 10/5 FMFL 6.1.13 Check that source envelope plug is mounted 2/5 FMFL 6.1.14 Check that bolt M5 is mounted 5/5 FMFL 6.1.15 Check that o-ring is mounted 415 FMFL 6.1.16 Check that o-ring is mounted 10/5 FMFL 6.1.17 Check that pop rivets is mounted 6/5 FMFL 6.1.18 Check that warning label is mounted 7/5 FMFL 6.1.19 Check that warning label is mounted 8/5 FMFL 6.1.20 Check that seal is mounted. Only mounted 11/5 when source is installed FMFL 6.1.21 Check that all M 16 bolts (4 off) are 9/5 mounted with correct torque · FMFL · Bolts I Nuts: Apply torque as per 6009-1129-D (197 Nm) Date: 3PM Signature : CLIENT Signature : PhaseWatcher Vx No.: 6009-1365-0 Rev: A ~3-PHA5E Final Inspection Procedure Date: 10/10/01 Measurements AS Page: 8 of 13 PT -transmitter DPV-transmitter TT -transmitter Figure 2 : Transmitters ~; ~ PhaseWatcher Vx No.: 6009-1365-D Rev: A ~3-PHA5E Flnallnsp8Ctlon Procedure Date: 10/10/01 Measurements AS Page: 9 of 13 Check the followinG on the PW Vx: TRANSMITTERS Step Inspection Description ItemIRef Nb Check Reap. Sign 6.1.22 DPV Transmitter 7/1 3PM · Check that there is no visible damage · Check that end covers are fully tightened · Check that EEx d bracket is installed · Check that transmitter is zero trimmed after completed pressure testing 6.1.23 PT Transmitter 8/1 3PM · Check that there is no visible damage · Check that end covers are fUlly tightened · Check that EEx d bracket is installed · Check that transmitter is zero trimmed after completed pressure testing 6.1.24 TT Transmitter 9/1 3PM · Check that there is no visible damage · Check that end covers are fully tightened · Check that EEx d bracket is installed Date: Comments : 3PM Signature : CLIENT Signature : "~ PhaseWatcher Vx No.: 6009-1365·D Rev: A ~3-PHASE Final Inspection Procedure Date: 10/10101 Measurements AS Page: 1 0 of 13 6.2 MPFM Cabling and Junction Box Installation Step Inspection Description Item NblRef Nb Check Reap. SIgn 6.2.1 Check that all cables are fitted using plastic 3PM coated stainless steel ties. 6.2.2 Check that sharp edges are protected on 3PM cable trays and that cables are protected aQainst damaQe. 6.2.3 Check that corrosion inhibitor pad (ilCortee") 3PM and Silica Gel bag are fitted in the EEx d Junction Box. 6.2.4 Check that the JB is nitroaen purQed. 3PM 6.2.5 Check that the EEx d junction box and lid 3PM have no scratches or damage in the flame gap seal surfaces. Remove any protective tape at the flame gap surfaces and cover these surfaces with a thin layer of EEx d certified protective grease. FuUv tíghten Jid. Date: Comments: 3PM Sign.: CLIENT Sign.: ~ ~ PhaaeWatcher Vx No.: 6()()9.1365-D ~3-PHASE Rev: A Final Inspection Procedure Date: 10/10/01 Measurements AS Page: 11 of 13 6.3 Labels and Warning Signs Step Inspection Description Item NblRef Check Sign Nb """"" 6.3.1 Check that the Name Plate is fitted and according to 511 FMFL dwg. 6033~OO24~3. Check that SIN Is engraved to engrave (format: "Phase Watcher Vx 88/xx", xx= 20. 21 & 22) SIN 6.3.2 Check that the Gamma Source label is fitted and 7/5 3PM according to dwg. 6009·1115-3. Check that correct Date and SIN is engraved. Record Date: and SIN: 6.3.3 Check that the Warning Labels (2 off) are fitted on the 8/5 3PM source protection cover and that it is according to dwg. 6009·0538·3. 6.3.4 Check that Ex label is engraved on the Gamma 7/4 FMFL Detector Housing. Check that SIN is engraved (format: to engrave wPhaseWatcher Vx 8S/xx". xx= 20.21 & 22). SIN. Ref.dwg. 6009-0177~3 '- - "-' ~- Date: Comments: 3PM Sign.: CLIENT Sign.: PhaseWatcher Vx No.: 6009-1365-D Rev: A ~3-PHASE Final Inspection Procedure Date: 10/10/01 Measurements AS Page: 12 of 13 7.0 PUNCH LIST .úZ 3-PHASE "~AS PUNCH LIST Drg.l Tag No : Description MC Package no : PO No. Manufacturer : Category A: To be completed within milestone Planned Entered Category B: Can be tran8l. 10 later stage complete by Cleared by Punch CAT. DESCRIPTION (Ref. to drawing or Date (Sign) SUPPL 3PM. COMPo DATE item document) ",--i ~ PhaseWatcher Vx No.: 6009-1365-D Rev: A ~3-PHASE Final Inspection Procedure Date: 1 Of1 0/01 Measurements AS Page: 13 of 13 Category A: To be completed within milestone PIaM8Ø Entered Category B: Can be trans!. 10 1atGf' &tàQÐ complete by Cleared by Punch CAT. DESCRIPTION (Ref. to drawing or Date (Sign) SUPPL 3PM. COMPo DATE item document) ,,~ ~ COMMENTS VERIFIED Name Sign. Date Name Sign. Date SUPPLIER 3PM. 8.0 RESULT SHEETS The following shall be attached to the final inspection report upon presentation to the parties for final acceptance and signature: - Above Rauh Sheets completed and signed as applicable. '~ '"-,,ì ~¡ Distribution: Document title: PhaseWatcher Vx ON-SITE HYDROSTATIC PRESSURE TEST PROCEDURE Comments: This procedure is valid for the following specifications: Working pressure: 5000 psia On-Site Test pressure:5000 psia .. .. Maximum recommended on-site test pressure ~ - ~ A ..~ ..- ~~ 10.10.01 JrvLlIW 01 01 19.06.01 IDC DM BP Issue Rev. Date Issued for Ref. Made by Approved by Project number. Project name. PhaseWatcher Vx Customer document number. NA Framo Engineering document number. No. of pages. ~3-PHASE 6009-1522-D 8 Measurements AS - ~3-PHA5E MULTI PHASE FLOW METER Doc. No.: 6009-1522-0 Mea5lRll1erlts AS Page: 2 of 8 PhaseWatcher Vx Rev:A ON-SITE HYDROSTATIC Date: 10/10/01 PRESSURE TEST PROCEDURE LIST OF CONTENTS 1. JNT ROD U cn ON ............................................................... ............... ..........................................................................3 1.1 CAUTION ...... .......... ............ .... ... ..... ... ... ......... ........ .... ........ ........ ........ .... .... ............ ......... ................ ....... ..... ............ 3 1.1 PURroSE ............................................... .................... ......................................................................... ....................3 1.2 APPLICABLE STANDARDS AND SPECIFICATIONS .... ............ ............. ........................ ........ ....................... ..... ............3 1.3 ABBREVIATIONS.. ......... .............. ........ .......... ............ .............................. ................... .............. .................. ....... ......3 2. REFEREN C ES ......... ........... ............... ..... .... ........... ....... ...... ...... ..... .... .... ........... .... ......... .................... ....... ..... .......... ...J 3. D ESCRIMI 0 N ... ........ .... .... ........... ..... .... ....... .... ....... ...... ........... .... ...... ...... ........... ...... ......... .............. ............ ..... ........4 3.1 MECHANICAL DESCRIPTION... ................ ... ..... ........ ........... .... .................. .......... ............ .... .... ........ .... ....... .... ..........4 3.2 DESIGN REQUIREMENTS............................................................................................ .............................................4 4. TEST EQUI PM ENT .......... .... ......... .... ....... ....... ........ ..... .... .... .... ........... ............. ......... ........... .... ........... ....... ..... ..........4 S. SA FE TY I SPEC IA L G UID ELINES .... .... ....... .... ..... .... ........ ... .......... ...... ............. ..... ........ .................. ........ ....... ....... 5 6. PREP A RA TORY C HEC KS... ........... ....... .... ............... ......... ...... ........ ...... ............... ............. .... .... .... ....... ..... ........ ...... 5 6.1 BOLTS TORQUING. ..................... .... .... .... ............ ............... .... ...... ........... .................... .... ......... ......... .... ..... ........... ...5 6.2 PRECEDING QUALTrY CONTROL ACTIVITIES.... ........ ....... ........... ... ....... ..... ...... ................... .... ................... ..... .........6 7. TEST PROCEDURE I RESULT SHEETS ...............................................................................................................6 7 .1 HYDROSTATIC PRESSURE TESTING: .......... ........ ........ ....... .... ........... ............. .... ....... ........... ............. ....... ................6 8. TEST RESULTS.. ........ .... .... .... ........... ........... ..... ............. ............. .... .... ......... .... .... ......... .... ................ .... ............. ..... ...8 ·~ ,./ MUL TIPHASE FLOW METER Doc. No.: 6009·1522·D ~3-PHA5E Page: 30f8 Measurements AS PhaseWatcher Vx Rev: A ON-SITE HYDROSTATIC Date: 10/10/01 PRESSURE TEST PROCEDURE 1. INTRODUCTION 1.1 Caution This document as to be considered as a help tool only. Local, Government and Client own procedures will apply when existing. 1.1 Purpose The purpose of this test procedure is to verify the Multiphase Flow meter connection's structural Integrity once installed on the permanent piping. In & out piping will be pressure tested at the same time as the Multiphase Flow meter. It is estimated in this document that the test pressure will be 100% of the Multiphase Flow meter Working Pressure (5000 Psia x 100% = 5000 Psia). This is following the recommendation of the API 6A. However local practices may vary from working pressure up to 120% of working pressure. Another common practice is to use 110% of WP. Duration of time under pressure & fluid medium could be different from the ones indicated in this document. 1.2 Applicable Standards and Specifications The MPFM·Vx design is complying with the following standards: API Specification 6A for flowheads, valves and chiksans API RP 14E and API 6A for choke manifolds API RP 14E and/or ANSI 831.3 for piping API RP 14C for surface safety systems API Specification 14A and 14D for surface safety shutdown valves, and ESD systems NACE MR-0175 for all H2S service equipment. '- 1.3 Abbreviations MPFM-Vx WP TP Multlphase Flow Meter PhaseWatcher Vx Working Pressure Test Pressure - '- 2. REFERENCES Latest revision of the following drawings and documents are referred to in this procedure and shall be made available during hydrostatic pressure test : Documentation Name PWVx88 PWVx52 PWVx29 Standard Block&bleed Standard LV PWVx GENERAL ARRANGEMENT LOM 6009-0746-4 6009-1551-4 6009--154&-4 6009-1589-4 6009-1603-4 PWVxGENERALARAANGEMENT 6009-0734-3 6009-1549-3 6009-1544·3 6009-1586-3 6009-1602·3 "- . Vx 29 mm-L V is the long Venturi version which is full compatible with the Vx 52 mm (Same outside dimensions). ~3-PHASE MULTI PHASE FLOW METER Doc. No.: 6009-1522-D MeaSurements AS PhaseWatcher Vx Page: 4 of 8 Rev:A ON-SITE HYDROSTATIC Date: 10/10/01 PRESSURE TEST PROCEDURE 3. DESCRIPTION 3.1 Mechanical Description Each MPFM-Vx Assembly comprises the following components: Vx-section Blind Tee ** Instrumentation MPFM-Vx Junction Box mounted on to brackets on Vx-section Inlet Hub Graylock : 3" for PWVx2.9, 5" for PWVx2.9 LV and PWVx52, 8" for PWVx88 Outlet Hub Graylock: 3" for PWVx2.9, 5" for PWVx2.9 LV and PWVx52, 8" for PWVx88 .. Provided by 3 Phase Measurements upon request 3.2 Design Requirements WORKING PRESSURE (WP) : HYDROSTATIC PRESSURE TEST (MHP) : TEST TEMPERATURE: P = 5000 pala P = 5000 pala Ambient 4. TEST EQUIPMENT The following test equipment is required and checked prior to start of the operation : DESCRIPTION SIZElRANGE REMARKS TEST INSTRUMENT CALIBRATION CERT REF. Pressurisina Unit. Min. 11000 psia NA Test medium: Fresh water. NA Pressure gauges Accuracy: ± 0,5 % Test pressure: Within 25 - of full scale ranae 75% of full Dressure range Temperature Accuracy: ± 1.6 % Range: 0 - 100 deg C recorder of calibrated ranQe Chart recorder Accuracy: ± 0,5 % Test pressure: Wìthin 25- of full scale range 75% of full Dressure ranoe NOTE: All measuring equipment used shall be provided with valid calibration certificates. All measuring equipment shall be labelled to indicate calibration status. Calibration shall be traceable to national standard. .-.,¡ , -.......-' MUL TlPHASE FLOW METER Doc. No.: 6009-1522..0 ~UHA5E PhaseWatcher Vx Page: 50f8 Measurements AS Rev: A ON-SITE HVDROSTATIC Date: 10/10/01 PRESSURE TEST PROCEDURE CAUTION: 5. SAFETY I SPECIAL GUIDELINES ~ CAUTION: CAUTION: '-- CAUTION: CAUTION: CAUTION: All safety regulations applicable at hydrostatic pressure test on site shall be adhered to by all personnel attending. Personnel must wear safety equipment At no stage shall the vessel be approached for close inspection unless actual pressure has positively been reduced to a level lower than that previously attained. Max pressure whilst inspecting: 95% of pressure already attained and held for minimum 15 minutes. Only authorized people may be working nearby the equipment while the pressure test is under progress. Always decrease the pressure below 5000 psi to visually check piping and connections for leaks. Always decrease the pressure back to zero before re- tightening. Special care must be taken during pressure testing to avoid injuries to personnel and equipment. A clearly visible sign shall be posted to inform of ongoing activities. Responsible person shall ensure that only authorised personnel have access to test area. 6. PREPARATORY CHECKS The Multiphase meter shall be fully installed and connections torqued up before proceeding with the pressure test: 6.1 Bolts torquing The following torque shall be applied during assembly prior to pressure test. Operator to sign accordingly. Dimension Required torque Location Operator Remarks (ASTM A320 GA.L7) Sign. 1" - 8UNC-2 190 Nm Gravlock clamÐs, 5" Date: Comments : Operator Sign.: CUent Sign.: DnV sign: ~3-PHA5E MUL TIPHASE FLOW METER Doc. No.: 6009-1522-0 Measurements AS PhaseWatcher Vx Page: 6 of 8 Rev: A ON-SITE HYDROSTATIC Date: 10/10/01 PRESSURE TEST PROCEDURE 6.2 Preceding Quality Control Activities The following activities for the test object shall be successfully completed and documented prior to commencement of test: I. Item I Inspection Description I Check I Sign 6.2.1 Material Certificates for pressure retaining parts: Reviewed and accepted by Client 6.2.2 Check that valid calibration certificates are available for test instruments 6.2.4 Check that all nuts and bolts are tightened to the specified torque listed in the table in section 6.1. 6.2.5 Check by visual inspection that Test set-up is technically sound & acceDtable Date' Comments: Operator Sign.: Client Sign.: DnV./StamD: 7. TEST PROCEDURE I RESULT SHEETS 7.1 Hydrostatic Pressure Testing: Equipment Serial No.: Equipment tag no.: The following shall be verified and recorded as described : Item Inspection Description Design R ulrement 7.1.1 Start Temperature recorder na 7.1.2 Start Pressure recorder na 7.1.3 Record ambient temperature na 7.1.4 Increase pressure to approx. 33 % of test pressure Pmax = 1700 psia :t 50 Dsia 7.1.5 Allow pressure to stabilise +/- 50 psia Verify pressure drop is within limits as specified. Record Df'essure for a D8rìod of 2 minutes. 7.1.6 Increase pressure gradually in steps of approx. Step: 500 psia 500 pSia until 66% max. test pressure is reached. Pmax = 3300 psla Date: Comments: Operator Sign.: Client Sign.: DnV.lStamp: ~ 3-PHASE ~easurements AS MUL TIPHASE FLOW METER PhaseWatcher Vx ., .,/' Doc. No.: 6009-1522-0 Page: 7 of 8 Rev: A ON-SITE HVDROSTATlC PRESSURE TEST PROCEDURE Date: 10110/01 Inspection Description Design R ulrement 7.1.7 Allow pressure to stabilise Verify pressure drop is within limits as specified. +/- 50 psia Record pressure for a period of 2 minutes. 7.1.8 Increase pressure gradually in steps of approx. Step: 500 pSia 500 psia until 1 00% max. test pressure is reached. Pmax :: 5000 psia 7.1.9 Allow pressure to stabillse Verify pressure drop is within limits as specified. ± 50 psia Record pressure for a period of 4 minutes. 7.1.10 Reduce pressure to atmospheric pressure - 14.7 Dsia 7.1.11 Increase pressure gradually in steps of approx. Step: 1000 psia 1000 psia until 1 00% max. test pressure is reached. Pmax = 5000øsia 7.1.14 Maintain max. test pressure until pressure is Pmax :: 5000 pSia stabilised. Adjust as relevant. ± 50 psia 7.1.15 Check at chart recorder that pressure drop is within Pmax :: 5000 psia limits as specified for a period of 15 minutes. ± 50 psia Date: Comments: Operator Sign.: Client Sign.: DnV.lStamp: ~ 3-PHASE Measurements ÞS MUL TIPHASE FLOW METER Phase Watcher Vx Doc. No.: 6009~1522-D Page: 8 of 8 Rev:A ON-SITE HYDROSTATIC PRESSURE TEST PROCEDURE Date: 10/10/01 7.1.16 Reduce pressure to 95% of Working Pressure Pmax = 4750 psia ± 50 osla 7.1.17 Maintain max. test pressure until pressure is stablUsed. Pmax = 4750 psla Adjust as relevant. ± 50 osia 7.1.18 Check at chart recorder that pressure drop is within limits Pmax = 4750 psia as specified for a period of 15 minutes. :t 50 psla Inspect e<Jpt for any leakaae under pressure 7.1.19 Reduce pressure to atmospheric pressure - 14.7 psia 7.1.20 After successful completion of test, verify pressure is atmospheric - 14.7 psia - Bteed off the test eouipment. 7.1.21 Pr...ur. recording chart: To be marked as follows, and signed by all attending parties: - Unit serial no: - Date: - Ambient temperature: OC - Operator name and signature: 7.1.22 All records as signed shall be attached to the test report 7.1.23 Certifying Authority to stamp Name Plate on Phase Watcher Date: Comments: Operator Sign.: Client Sign.: DnV.lStamp: 8. TEST RESULTS A test report shall be issued as a record of above pressure tests. The pressure test report shall comprise a pressure test certificate and all signed off sheets from this procedure. The following shall be attached to the pressure test report upon presentation to the parties for final acceptance and signature : - Above Result Sheets completed and signed as applicable. - Chart recorder graphs duly signed by a responsible person according to procedure. - Copies of valid Calibration Certificates for all test Instrumentation. ·- "........./ '~ - I I . . " I ~ ,)A' r ÃI11/ N / I - A 19-Nov-2003 For Information M BAE E 00 09-0ct-2003 For Information AFo MJ ET 02 12-JUL-2002 IDC HAs ED/BP 01 10-JUL-2002 IDC HAs/Bla ED/BP Rev.: Date: Issued for: Made by: Checked: Approved: TiUe. On Site Installation Procedure for PhaseWatcher Vx Project number Document number. 6010-0087 -D Customer I Supplier document number. No. of pages. ~3-PHA5E 10 ~easurennents~ -- - No: 6010-0087-0 ~3-PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 2 of 10 1. INTRODUCTION This document describes the procedure for on site installation of the Phase Watcher Vx. The on site installation is intended as the physical connection/installation of the PhaseWatcher Vx to the client production and piping system. The onside installation procedure cover all p~ysical aspects related to communication and electrical hook up of the meter to the client system After the installation process, the PhaseWatcher Vx must undergo the On site Commissioning Procedure for PhaseWatcher Vx. 1.1 REFERENCE DOCUMENTS Gamma Radiation And Source Handling Guildelines to Health, Safety and Environment FA T/Function Test Procedure for Phase Watcher Vx On Site Commissioning Procedure for Phase Watcher Vx Interconnection Diagram for Phase Watcher Vx Phase Watcher Client Serial Link Inteñace, Modbus RTU \. \. / -- -- No: 6010-0087-D ~3-PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 3 of 10 2. SAFETY Please note that it is imperative that the reference document Guidelines to Safety, Health and Environment has been read, and necessary precautions taken prior to commencing this operation. - "-' No: 6010-0087 -D ~3.PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 4 of 10 3. INSTAllATION AND SITE INTEGRATION 3.1 PREPARATIONS 3.1.1 Preparatory checks In order to ensure a smooth installation process for PhaseWatcher Vx, good communication and clarification on responsibilities is required between Client and Schlumberger/FE representatives. These can be achieved after reviewing and mutual agreement on different tasks emerging from the review of this procedure and the referenced documentation Below is a general guideline listing some of the main preparatory checks to be taken into account for a PhaseWatcher Vx installation: Prior to the Installation process for PhaseWatcher Vx, a complete review of actual documents and drawing versus PhaseWatcher Vx scope of delivery and design dossier needs to be done. Any deviation needs to be reported an action plan created in order to correct it to prevent delays in the installation process. Once everything is in accordance with the scope of delivery, an additional meeting needs to be arranged in order to perform a field visit review. P&ID and PhaseWatcher Vx installation sketch needs to be agreed before the filed visit. The field visit is intended to verify spacing, dimensions, electrical supplies, communication interfaces, etc INSTALLATION CHECK liST COMMENTS STATUS 1. Meeting Review of field visit report. Ensure a meeting with the following personnel in order to review the additional point presented in this Installation check list: · Client project representative · Client electrician lelectrical engineer · Client instruments engineer and communication expert (SCADA expert) · Schlumberger representative involve in the filed visit 2. Is all the referenced documentation from this procedure ready and reviewed for the installation? 3. Have both client and SLB/FE representatives been designated for the Installation/commissioning project? 4. Is the On site Electrician, Instrumentation man, Communication man for SCADA notified for the installation job? \... .,;i '..... j' No: 6010-0087 -D ~3-PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 5 of 10 - 5. Are P&ID and general arrangements for piping and zone classification ready and reviewed as per reference documentation? 6. Drawing and dimensions verification against the physical components for the installation 7. Is the commissioning material and spares Inventoried and physically counted? · PhaseWatcher VX, Radioactive source · Blind Tee · Cable for communication · Cable for power supply · Cable glands · Piping connections, flanges, cross-over, Seal ring, o-rings, · PW Installation and commissioning spares · Samples, bottle samples, torque wrench, tool box, etc 8. Is the radioactive documentation and transport arrangements completed? 9. Check meter and piping Physical dimensions I Accessibilitv 10. Check Piping I inlet & outlet connections, material, size, paintina reQuirement. spectacle blind... 11. Check requires Mechanical support for the installation 12. Check Grounding (weld extra pad eyes...) 13. Are the Operational procedures and JSAlHazop already approved? 14. Review Location of nearest power supply and PW/Remote communication system for power requirements 15. Review Rooting to connect the Meter to the Power supply source (cable dimensions) 16. Inspect the junction box of power source, check terminals type, specification & spares 17. Check Client certification requirements & checklist? 18. Check Client QHSE requirement (people and equipment, RA source logistics & Handling and permits) 19. Is Transportation & Accommodation arranged? 20. Is the Work permit completed as per client reQuirement? 21. Is the formal permit for camera approved? No: 6010-0087-0 ~3-PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 6 of 10 3.1.2 DOCUMENTATION AND EQUIPMENT Documentation: · Ensure all reference documentation from section 1.1 is available for PhaseWatcher Vx Installation Verify, using the field visit report, that all information required has been addressed during the visit. If any activity has not been completed, ensure that all additional information equipment and tools needed are available. · Radiation Instrumentation and Monitorina: The source is intend to be installed during the PhaseWatcher Vx Commissioning stage. If installed during Installation process, follow the guidelines set up in Gamma Radiation and Source Handling Procedure. . Tools and Consumables: · Service computer · 24 VDC power supply · Lifting equipment · Standard I general hand tools · Calibrated torque wrench Range: Up to 500 Nm · Allen keys (metric): M10 & M16 · Wrench spanners (imperial): 1" & 11/4" · Electric Multi-meter · HART Communicator · Pressure test pump & Test pressure control equipment 3.1.3 ON-8ITE AUTHORISATION Authorisation required: · Radioactive source handling if the source is intend to be transported during installation stage (logistic convenience). · Mechanical/ pressure system isolation and depressurisation. · Electrical system isolation. · Electrical 'Hot Work' permits. The permit(s) to work authorising the above activities will specify the installation specific precautions to be followed by the operator. The installation may require additional documentation to be presented prior to authorisation being granted, this could include risk assessments, pr&job safety meetings, detailed job specific operational procedures and contingency planning, copies of equipment and operator certification. Authorisations needed: · Electrical Installation authorisation · Work permits \. ./ ''''". ./ No: 6010-0087-D ~3-PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 7 of 10 3.2 INSTAllATION REQUIREMENTS 3.2.1 Access Requirements, Orientation, Erection, Flowline Connection Prior to installation and site integration of the PhaseWatcher Vx, the Interface Drawing should be studied. The Interface Drawing includes: · Overall dimensions · Connections sizes · Design specifications recap Important note: · The flow direction is so that the Blind Tee is upstream the PhaseWatcher Vx · Be advised what's installation limits for piping regarding nozzle loads & orientation of flow meter. · Note special requirements regarding Blind Tee 1 installation I interface with flow meter (orientation pin). No: 6010-0087-D ~3-PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV -2003 Measurements AS Page: 8 of 10 3.3 PHYSICAL INSTAllATION 3.3.1 Positioning The verticality of the PhaseWatcher Vx, must be respected. A to high offset, may affect measurements, resulting in inaccuracies. 8.1.1 Mechanical connection Important note: special requirements exist regarding Blind Tee installation I interface with flow meter (particularly dimensions and orientation). The Blind Tee shall be manufactured according to design input from 3PM given in the following reference drawing: Required Blind Tee Arrangement Inspect the Seal rings to ensure it is within specification for use. Assemble the connections between PhaseWatcher Vx and piping. Ensure that the proper torque is applied to bolts using the proper torque wrench. The clamp bolts should be evenly torque. Never over-torque clamp bolts; it may damage the Seal Ring resulting in a leak. PhaseWatcher Stud 80lt size Average torque model Inch Ft. -Lb Nm Vx29 %" -10 UNC-2 55 75 Vx 29-L V 1" -8 UNC-2 140 190 Vx52 1" -8 UNC-2 140 190 Vx88 1 %"-8 N-2 290 393 NBI In order to perform fluid in situ measurements during the commissioning stage. it will be required to have the outlet piping of the PhaseWatcher Vx removed. Take this note into account during the installation process. 3.3.2 Electrical connectlon& Power Requirements The PhaseWatcher Vx power and voltage requirements are stated in the Interconnection Diagram for Phase Watcher Vx. Electrical hook-up shall be according to this document: It is the Client's responsibility to provide cabling and glands that satisfy both site hazardous area installation requirements and the requirements stated in the above reference. It is not permissible to perform any changes to the EEx d certified Junction Box or its contents other than installing interconnecting cables, replacing blanking plugs with EEx d certified glands. "'- j' '"' / - No: 6010-0087 -0 ~.3-PHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 9 of 10 Before connecting the interconnection cabling (either end), perform the following checks: Item Inspection Description Value Sign 3.3.1.1 Continuity checks of the cable using a multimeter (ohm function for each wire + screen) 3.3.1.2 Test the cable using a megger (each wire and screen vs. all other wires/screens in same cable) 3.3.1.3 Check that the power supply has the correct output voltage: 24 VDC +/- 2 VDC. Than: 3.3.1.4 Connect the power supply cable in the junction box and measure the voltage using a multimeter 3.3.1.5 Connect the serial link cables to the Service Computer and check that the communication is OK. 3.3.1.6 Connect the serial link cables to the Customer Supervisory System and check that the communication is OK Connect all Instrumentation cabling in the EEx d junction box according to Inteconnection Drawing for Phase Watcher Vx 3.3.3 Connecting the PhaseWatcher Vx to Client's Supervisory System Connecting the PhaseWatcher Vx to Client's Supervisory System shall be according to the following reference documents : Interconnection Diagram for PhaseWatcher Vx Phase Watcher Client Serial Link Interface, Modbus RTU The PhaseWatcher Client Serial Link Interface, Modbus RTU document describes the set-up of the Modbus interface to Client's supervisory system. 8.1.2 Installing the radioactive source If agree during the PW installation preparation that the source is to be installed during the this stage, follow the guidelines in the reference document Gamma Radiation and Source Handling Procedure No: 6010-0087-D ~3.pHASE On Site Installation Procedure Rev.: A for PhaseWatcher Vx Date: 19-NOV-2003 Measurements AS Page: 1 0 of 10 4. FUNCTION TEST Once the installation of the PhaseWatcher Vx to the client production system is completed, a physical inspection and system test shall be performed. The purpose of this test is to ensure that the system performs all specified functions satisfactorily. The test will be performed with the complete system installed. There will be no process flow during the function test. Section 7, 8, 9.1-9.5, 9,11 and 9.12 of the reference document FA T/Function Test Procedure for Phase Watcher Vx. should be checked. Please record the results from this function test to be used as a reference documentation during the commissioning stage. 00 01 27 -APR-03 27 -FEB-03 Rev.: Project number Date: ~. INFORMATION IDC 3-PHASE Measurements AS ""-"/ AC CaC Issued for: Title. Made by: Checked: Approved: On Site Commissioning Procedure For PhaseWatcher Vx Document number. 6010-0088-D Customer I Supplier document number. No. of pages. 23 ~-_.~---~._. 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 2 of 11 TABLE OF CONTENTS 1. INTRODUCTION ... ..... ............................................................. .............. ...... ..... .......... ................ ............ 3 1 .1 REF ERE NeE DOC U M E NT S .......................................................................................................... 3 1 .2 ABBREViATIONS........... ..... ............................ ................ ............... ......... ..................... ........... ........ 3 2. SAFETY PRECA UTIO NS................... .................. "... ............................ ........ ......................"........ ......... 4 3. PR E P A RATIO N ............ ............. ................ ................. .................. ......... ........ ....... ........ ............... ........... 5 3.1 DOCUMENTATION AND EQU IPMENT ...... ...... ........................... ....................... ................ ...... ...... 5 3.2 ON-SITE AUTHORISA TION.............................. ........ ................................ ........... ................. .......... 6 3.3 COMMISSION ING REQUI REMENTS... ......................... ....... ...... .......... ........ ...... ........ .................... 6 3.3.1 ELECTRICAL HOOK-UP & POWER REQUIREMENTS............................................................. 6 3.4 SYSTEM CHECKS............... ...... .................................... ............................... ......... ..... ........... ......... 6 3.5 SYSTEM CONFIGURATION........ ...... ................... ................. ................ ............ ................. ..... ....... 7 3.5.1 MASTER EMPTY PIPE REFERENCE. ....................................................................................... 7 3.5.2 WATER AND OIL REFERENCE POINTS (linearized Mass Attenuation points) .......................8 3.5.3 GAS REFERENCE POINT (linearized Mass Attenuation points)................................................ 8 4. SYSTEM TEST......... ....... ........... ........ ...................... .................................. ........... ...... ............... ....... ..... 9 5. PR ESSUR E TEST....................... ...... ....... ......... .................................................. ....... ........ ....... ........... 10 6. FINAL TESTING.. ................ ....... ........................ ............ ...................... ................... ........... ...... ............ 11 6.1 DATA VALIDATION / FI RST FLOW............................... ...................................................... ......... 11 Appendix 1 Commissioning Handover Document >"'-"' ~ 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 3 of 11 1. INTRODUCTION This document describes the procedures that will be carried out by Framo Enginneering or Schlumberger when Commissioning a PhaseWatcher Vx at the client site. The onsite commissioning scope includes the post-installation functional test and field set up of the PhaseWatcher prior to initial flow. The commissioning test will ensure that the system performs all specified functions satisfactorily. The test will be performed with the complete system installed. Power and communication will be tested during the commissioning process to ensure the reliability of the installation. Complete meter 'set up' will be performed (instrumentation readings review, zero trim of required transmitters, empty pipe and fluid reference points). N8! Normally there will be no process flow during the commissioning phase. 1.1 REFERENCE DOCUMENTS On Site Installation Procedure for Phase Watcher Vx Gamma Radiation and Source Handling for Phase Watcher Service Computer Software User Manual In Situ Fluid Reference Measurement Procedure Empty Pipe Reference Procedure Procedure for Update of DAFC, Software Configuration of DAFC Mk1 Serial Ports 1.2 ABBREVIA TIONS DAFC MRB PW RTU SC Data Acquisition Flow Computer Manufacturing Record Book PhaseWatcher Vx Remote Terminal Unit Service Computer PC 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27-APR-2003 4 of 11 2. SAFETY PRECAUTIONS It is imperative that the reference document Guidelines to Safety, Health and Environment has been read, and necessary precautions taken prior to commencing this operation. ""-' -_. ~3-PHASE On Site Commissioning No: 6010-0088-0 Procedure For PhaseWatcher Rev.: 00 Date: 27 -APR-2003 Measurements AS Vx Page: 5 of 11 3. PREPARATION Verify that the installation handover form has been completed and signed off. If any activity has not been completed ensure that all the additional tools/parts/procedures needed are available. 3.1 DOCUMENTATION AND EQUIPMENT Documentation: -Confirm source test report and certificate of origin is available onsite. -Source datasheet -Risk Assessment for source handling operations. -Barium Source Handling procedures. -Copy of PhaseWatcher Vx radiation survey form -Local rules for radiation handling. -Emergency contact details of the area Radiation Protection Officer and line manager, or relevant responsible person. -Copy of training certificate (ensure that the level of training complies with the local regulations). -Copy of classified worker radiation medical certificate. -Handover I status report from the installation phase including the location of the source key. -Valid leak/Wipe test report ~ Radiation Instrumentation and Monitoring: -Valid Personal dosimeter (radiation badge). -Calibrated Dose Rate Meter with a copy of the calibration certificate. -Calibrated Contamination Monitor with a copy of the calibration certificate. -- Tools and Consumables: -Service Computer PC. -PhaseWatcher software, including Legacy if OAFC version is unknown, on CD. -CD-writer or alternative method to backup commissioning data files. -PW Commissioning tool kit. -Digital Multimeter. -Leak test kits, minimum 2- off, (Schlumberger: pin: C011594 (NAM) or C-1191 0.) -Gloves: surgical and heavy work. -Suitable non-oil based solvent for leak tests. (Possibly from the facility itself.) -Plastic sheeting to cover work area during leak tests. -Reference Tool with spare o-rings. -Brushes and cleaning equipment (rags, duct tape etc.) to perform the liquid reference points. -Additional standard hand tools as appropriate. """"" From the client: -Liquid samples for reference points. -PVT fluid properties. 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 6 of 11 3.2 ON-SITE AUTHORISA TION Authorization required: -Radioactive source handling. -Mechanical/pressure system isolation and depressurisation. -Electrical system isolation. -Electrical 'Hot Work' permits. The permit(s) to work authorising the above activities may specify certain installation specific precautions to be followed by the operator. The installation may require additional documentation to be presented prior to authorisation being granted, this could include risk assessments, pre-job safety meetings, detailed job specific operational procedures and contingency planning, copies of equipment and operator certification. 3.3 COMMISSIONING REQUIREMENTS 3.3.1 ELECTRICAL HOOK-UP & POWER REQUIREMENTS Electrical hook-up, power test and communication test should have been carried out during installation of the PhaseWatcher. This may be verified from the Installation Handover Document. 3.4 SYSTEM CHECKS 1) If not done during the installation phase, taking all necessary precautions, perform a source leak test and install the Barium 133 gamma source holder in the PhaseWatcher source housing, in accordance with the procedure Gamma Radiation and Source Handling for PhaseWatcher 2) Thoroughly clean and dry the venturi throat. Cover the top of the venturi with plastic sheeting to prevent objects/rain entering the throat. 3) Connect the PhaseWatcher Service Computer to the PhaseWatcher via the RS422 to RS232 adapter. Power up the Service Computer. 4) Power up the PhaseWatcher system. After 3 minutes, start the PhaseWatcher Service Computer program on the PhaseWatcher Service Computer. 5) Push the "Modbus -> Configuration" button and check that the Modbus Configuration settings are set in accordance with the client specification. If default values are to be used, check that the default parameters listed in reference document Service Computer User Manual are set. Please refer to reference document Configuration of DAFC Mk1 Serial Ports if it is necessary to download a new Modbus Configuration. 6) Push the "Modbus -> Connect" button. Check that the start-up routine on the Service Computer is performed without any error-messages. ",,-,. '~ ~3-PHASE On Site Commissioning No: 6010-0088-0 Rev.: 00 Procedure For PhaseWatcher Date : 27 -APR-2003 Measurements AS Vx Page: 7 of 11 7) Let the system run for two minutes. From the diagnostics tab, check that the latest version of the OAFC software is installed and record version number on the commissioning handover form. 8) If the latest OAFC is not loaded, please refer to reference document Procedure for Update of DAFC, Software for information on how to perform an update. 9) Verify that there is communication with all the transmitters and that there are no unexpected alarms (Nuclear Interpretation Model Error will be present due to no valid Fluid, Gas References, Dynamic Op-Low, and Nuclear Linarisation Model Error will be present due to no flow conditions). Ensure that all transmitters are addressed correctly and that values are correct and in accordance with operating conditions. 10) From the parameters tab, check that time/date data transmitted by the OAFC corresponds to the time/date setting on the Service Computer. Synchronise OAFC and Service Computer clocks with the facility reference time. 11) If a display unit is installed on the PhaseWatcher, check that time/date data displayed locally on the PhaseWatcher unit corresponds to the time/date setting on the Service Computer. Check that production data, count rates, pressure and temperature data are being updated at regular intervals on the display. 12) Check and sign that all the values in the 'parameters' tab match those on the Commissioning Handover form, Appendix 1 . -Venturi size -Gamma detector parameters -Transmitter alarm limits -Gamma detector alarm limits 13) Verify that the gamma detector has reached the set temperature (± 0.5 °C) selected. 14) Temporarily, change the set temperature to check that the temperature control system is working correctly. 15) Return the set temperature to the correct value and allow stabilising at ± 0.5 °C of the selected temperature. 3.5 SYSTEM CONFIGURATION 3.5.1 MASTER EMPTY PIPE REFERENCE. Perform a Master Empty Pipe measurement as per reference procedure Empty Pipe Reference Measurement Procedure. Once the empty pipe reference is validated, record the final total count rates, count rates for each energy level and their corresponding standard deviations in the Client Commissioning Handover, Appendix 1 (CI. 2.0). Once the required standard deviation is reached, before ending the session take a 'print screen' and save the image using appropriate computer application (word, excel, MS Paint or MS PowerPoint etc.). ~'_~'-M'_~__'_'__ 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-D 00 27-APR-2003 8 of 11 .--,- ------~~- 3.5.2 WATER AND OIL REFERENCE POINTS (linearized Mass Attenuation points) Please refer to reference document In-Situ Fluid Reference Measurement Procedure, if In-Situ Reference Measurement is to be periormed. Please refer to reference Service Computer User Manual if calculation of reference points NB! It is advised that the water reference point is logged before the oil point, as it is easier to clean the venturi throat after the water reference than it is for oil. After the Water or Oil point reference is validated, record the required data in the Client Commissioning Handover, Appendix 1 (CI. 3.2 for Water, CI. 3.4 for Oil): Take a 'print screen' and save the SC image using appropriate computer application (word, excel, MS Paint or MS PowerPoint etc.). Save the configuration file to the SC hard disk. If the meter is to be set up with multiple well profiles, change the well profile number from the 'File' pull down menu, you will have to reboot the DAFC, rename the configuration and ensure that the empty pipe reference has been retained. 3.5.3 GAS REFERENCE POINT (linearized Mass Attenuation points) Enter the gas specific gravity and composition from the latest representative PVT analysis and compute the mass attenuations. After validation, record the required data in Client Commissioning Handover, Appendix 1 (CI. 3.1). In-situ Measurement may be performed instead of computing the gas mass attenuations through a PVT analysis. A pressure of at least 40bar is recommended during in-situ measurement. Make sure all air are flushed, and that the temperature and pressure has stabilized before starting the in-situ measurement. The typical acceptance criteria are a variation in Mass Attenuation of less than 0.0003 m2/kg. Please see reference document Service Computer Software User Manual for details. \~ 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 9 of 11 4. SYSTEM TEST Check that all readings from the OAFC to the Customers Supervisory System are correct and that they are updated. Check the continuity of the communication system over an appropriate period to identify the quality of the communication link (cable, satellite or radio link). "'-' ,,""-~,-,.-._---~-~ 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27-APR-2003 1 0 of 11 5. PRESSURE TEST On site pressure testing falls under the responsibility of the client and shall be performed according to client's procedure. Furthermore, all safety precautions, when required, must be reinforced by SLB/FE representatives performing the commissioning in order to minimize risk associated with the equipment pressure test It is however, strongly recommended that the onsite test pressure does not exceed the PhaseWatcher working pressure. The preferred test medium is a non-volatile liquid, preferably water / glycol or similar. Recommended Step by Step procedure: -Connect high pressure pump unit to PhaseWatcher installation piping. -Rig up a chart recorder appropriate for the required test pressure. -Ensuring that the system to be tested is open to the atmosphere at the highest available point, flush through with test liquid until all the air is expelled. -Close the bleed point and slowly increase the pressure to 35 bar. Allow the pressure to stabilise and hold for 5 minutes with no drop on the chart recorder. -Once the pressure is brought up to test pressure, it should be allowed to stabilise, and then if necessary (due to compressibility of the test fluid, i.e. air in the system), pressure increased again to test pressure. -This pressure should be held until it has stabilised, and the last 15 minutes of testing should shows a drop of less than 1 % of the actual applied pressure. ~ ,,~ '~ ~ 3-PHASE WMeasurements AS On Site Commissioning No : Procedure For PhaseWatcher ~:~~: : Vx Page: 6010-0088-0 00 27 ~APR-2003 11 of 11 6. FINAL TESTING 6.1 DATA VALIDATION I FIRST FLOW Once all commissioning activities have been completed it is recommended that a thorough quality check of the first flowing data through the meter is undertaken to ensure consistency of results. Remember to log all raw data during the flow period. Please refer to reference document Service Computer Software User Manual Sign off the cl.1 .2 of the Client Commissioning Handover, Appendix 1. _.~,-- ~.~--~-'.'--_._-- 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx Appendix 1 No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 1 of 1 2 Commissioning Handover Document The following must be completed and signed off by designated commissioning representative '~ ~. - ~3-PHASE On Site Commissioning No: 6010-0088-0 Procedure For PhaseWatcher Rev.: 00 Date: 27 -APR-2003 Measurements AS Vx Page: 2 of 12 1. SYSTEM START UP Description Value Signed Source leak test performed, contamination detected: 370 MBq Barium 133 gamma source installed, serial no: 3PM Ref: Radiation survey conducted, maximum dose rate recorded: Modbus configu ration correct: COM port: Baudrate: Databits: Parity: Stopbits: Slave address: Modbus timeout: Max retransmissions: Max data bytes: SC Connects to DAFC without error. Yes DAFC, Service Computer, (display) clocks synchronised to Yes reference time. 1.1 "Parameters" folder Service Computer Software Venturi Dimensions I Value Signed -- Venturi Size selected: I 1 Gamma Detector Parameters Value Signed Gamma detector parameter 1 P1 - -0.0887 Gamma detector parameter 2 P2 - -0.0145 Gamma detector parameter 3 P3 - +0.0491 Gamma detector parameter 4 P4 - -0.0236 Gamma detector parameter 5 P5 - -0.0193 Transmitter Alarm Limits Value Signed Venturi DP - high - mbar Dynamic DP - low - mbar Line pressure - high - bara Line temperature - high - °C Line temperature - low - °C Ambient temperature - high - °C Ambient temperature - low - °C 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 3 of 12 L_ Description Parameter ID Gamma Detector Alarm Limits N32 - high - cps 1e 10 ,-"-- N32 - low - cps -1 ---.__.- 1 e10 N81 - high - cps N81 - low - cps -1 ....w___.._______,_.___ 1e 10 N356 - high - cps N356 - low - cps -1 N Total - high - cps 1 e 10 N Total -low - cps -1 Offset - high - mVolt Offset - low - mVolt High Voltage - high - Volt High Voltage - low - Volt Crystal temperature - high - °C Crystal temperature - low - °C Board temperature - high - °C Board temperature - low - °C Chamber temperature - high - °C Chamber temperature - low - °C ~ .~. "--~~ ~3-PHASE On Site Commissioning No: 6010-0088-0 Procedure For PhaseWatcher Rev.: 00 Date: 27 -APR-2003 Measurements AS Vx Page: 4 of 12 2. FIRMWARE I SOFTWARE VERSIONS Description Record the following software Version numbers and hardware Serial numbers: Signed OAFC application software, Version number: ...................................... Nuclear linearization model, Version number: ..................................... Interpretation model, Version number: ........................... ....... ..... ......... Gamma detector, Serial number: .. ....................... ........... ....... ............. HART and analogue modem card, Hardware version: ........................... Firmware version: ........................... Serial number: ................................ Record the following OAFC diagnostic parameters: Input voltage: .................................. Volt ISO supply: ..................................... Volt +5, ±12 internal: .............................. OAFC temperature: ......................... °C Activate the push button "Update Status" and verify that all transmitters are communicating and report without any alarms. Wait 30sec before activating the "Stop Update" button. Description Signed Record the software revision on the running PhaseWatcher. Press "Help -> About" to view Service Computer Version ........................................ --- ---, ,--,-,. .-._-.-.'----~ No: Rev.: Date: Page: 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx 3. EMPTY PIPE REFERENCE 6010-0088-0 00 27-APR-2003 5 of 12 Description Signed Record the following values from the "Empty pipe reference window". Linearísed count rates: LE: .................................. cps st de v: .. . . . . . . . . . . . . .. . .. .. . . . . . . .. . 0/0 HE: ................................ cps st de v: .. .. . . . . .. . . .. . .. . . .. .. .. . .. . . 0/0 356: .................................. cps st de v: .. .. . . .. .. .. .. .. . . . . .. . .. . .. . . 0/0 Total: ................................... cps Oaterrime:.......................... ... ~. ~ ~ 3-PHASE FMeasurements AS On Site Commissioning No : Procedure For PhaseWatcher ~:~~:: Vx Page: 6010-0088-D 00 27 -APR-2003 6 of 12 4. FLUID REFERENCES 4.1 GAS MASS ATTENUATIONS 4.1.1 GAS PVT PARAMETERS The following values shall be entered prior to calculating the gas reference. Description Value Signed Model Gas specific gravity CH4 C2H6 C3H8 C4H10 CSH12 C6H14 C7H16 C8H18 C9+ CO2 H2S N2 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 7 of 12 4.1.2 GAS COMPUTED MASS ATTENUATION Description Signed Mass attenuations calculated after parameter entry. Record the following values from the 'gas reference window, 'operator input', mass attenuation: LE: ............................... mass attenuation HE: ............................... mass attenuation 356: ............................... mass attenuation 4.1.3 GAS ACQUIRED REFERENCE POINT (If applicable) Description Signed Meter purged of all liquid. Verify that the gamma detector has reached the set temperature (± 0.5 °C) selected. DP hydrostatic offset ................... mBar Operator line temperature entered: ........................... degC Record the following values from the "gas reference window". Linearised count rates: LE: ...... ......................... cps st dev:.............................. % HE: ........ ....................... cps st dev:.............................. % 356: ............. .... .............. cps st dev:.............................. % Total: .. ... .. .... . . . .. . ........ . ..... cps Daterri me:............................. Gas - Reference is selected for computation. Yes / no (delete as applicable). - .~ \_~j;'"' ~3-PHASE V Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date; Page: 6010-0088-0 00 27-APR-2003 8 of 12 4.2 WATER MASS ATTENUATION 4.2.1 WATER PVT PARAMETERS The following values shall be entered prior to performing any water reference pOint. Description Value Signed Water model Water specific density (kg/m3) 4.2.2 WATER COMPUTED MASS ATTENUATION Description Signed Mass attenuations calculated after parameter entry. Record the following values from the 'water reference window, 'operator input', mass attenuation: LE: ............................... mass attenuation HE: ... ...... ............... ....... mass attenuation 356: .......... ............ ......... mass attenuation 4.2.3 WATER ACQUIRED REFERENCE POINT Description Signed Verify that the gamma detector has reached the set temperature (± 0.5 °C) selected. OP hydrostatic offset: .................. mBar Operator line temperature entered: ........................... degC Record the following values from the 'water reference window', linearised count rates: LE: ............................... cps st dev:.............................. 0/0 HE: ............................... cps st dev:.............................. 0/0 356: ... ....................... ..... cps st dev:.............................. % Total: ...... .................... ..... cps Oateffime:........................... .. ----..._..__.._._-~--~- 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 9 of 12 Water - Reference is selected for computation. Yes I no (delete as applicable). 4.3 OIL MASS ATTENUATION 4.3.1 OIL PVT PARAMETERS The following values shall be entered prior to performing any oil reference point. Description Value Signed PVT Model selected (if using 'Client PVT' attach hard copy) Viscosity inversion point Viscosity transition band Oil model Oil specific density (kg/m3) Oil viscosity (cP) Oil viscosity temperature (degC) S, (Sulphur) concentration entered C6H12 4.3.2 OIL COMPUTED MASS ATTENUATION Description Signed Mass attenuations calculated after parameter entry. Record the following values from the 'oil reference window, 'operator input' , mass attenuation: LE: ............................... mass attenuation HE: ......"....................... mass attenuation 356: ......"....................... mass a tten uation .~ On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 1 0 of 12 4.3.3 Oil ACQUIRED REFERENCE POINT Description Signed Verify that the gamma detector has reached the set temperature (± 0.5 °C) selected. DP hydrostatic offset: ,........,,,,,..,... mBar Operator line temperature entered: ........................... degC Record the following values from the "oil reference window". Linearised count rates: LE: ............................... cps st dev:.............................. % HE: ......... ...... .... ... ......... cps st dev:............ .................. 0/0 356: .......... ...... ...... ......... cps st de v:.............................. 0/0 Total: .. .. . . . . . . . . . .. . . . .. . . . .. . . .. " cps DatefTïme:............... .............. Oil - Reference is selected for computation. Yes / no (delete as applicable). 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 11 of 12 5. FINAL SYSTEM CHECKS I SOFTWARE CONFIGURATION Description Signed Check there are no active alarms. ("Nuclear Linearisation Model Error" alarm will be active if a full set of references has not been completed, "Dynamic DP -low" alarm will be active due to no-flow conditions) DAFC has updated all parameter changes without errors. Readings on the client supervisory system are correct. Hard copy of OAFC configuration has been printed. Raw data from reference logging has been backed up onto CO The Service Computer software will start a new log file each day at: . ...... ... . . hh. " . ..... mm.. ........ .ss Disk space warning level: .......... MB, disk full at: ............. MB remaining. When the hard disk is full the Service Computer will: Stop logging / delete old log files (delete as applicable). The Service Computer, if part of the delivery, has been configured to auto- connect: The Service Computer, if part of the delivery, has been configured to start logging automatically: The Service Computer software terminates without errors and command is returned to Windows. COMMENTS VERIFIED 3PM CLIENT Name Sign. Date 6010-0088-0 00 27 -APR·2003 12 of 12 On Site Commissioning ~o : Procedure For PhaseWatcher D:~~:: Vx Page: ~I ---..--. ._--_._-~._- 3-PHASE Measurements AS On Site Commissioning Procedure For PhaseWatcher Vx No: Rev.: Date: Page: 6010-0088-0 00 27 -APR-2003 8 of 11 3.5.2 WATER AND OIL REFERENCE POINTS (linearized Mass Attenuation points) Please refer to reference document In-Situ Fluid Reference Measurement Procedure, if In-Situ Reference Measurement is to be performed. Please refer to reference Service Computer User Manual if calculation of reference points NB! It is advised that the water reference point is logged before the oil point, as it is easier to clean the venturi throat after the water reference than it is for oil. After the Water or Oil point reference is validated, record the required data in the Client Commissioning Handover, Appendix 1 (CI. 3.2 for Water, CI. 3.4 for Oil): Take a 'print screen' and save the SC image using appropriate computer application (word, excel, MS Paint or MS PowerPoint etc.). Save the configuration file to the SC hard disk. If the meter is to be set up with multiple well profiles, change the well profile number from the 'File' pull down menu, you will have to reboot the OAFC, rename the configuration and ensure that the empty pipe reference has been retained. 3.5.3 GAS REFERENCE POINT (linearized Mass Attenuation points) Enter the gas specific gravity and composition from the latest representative PVT analysis and compute the mass attenuations. After validation, record the required data in Client Commissioning Handover, Appendix 1 (CI. 3. 1). ~ '~ ~ -~ Distribution: CUSTOMER I FILE Comments: 00 16.02.01 ISSUED FOR INFORMATION HRG ~f?b ---"'"""'~ BV~ ~ ,,- . 01 18.01.01 ISSUED FOR IDC HRG ED BVH Rev. Date Description Made by Checked Approved Title PhaseTester/PhaseWatcher with Barium Source Radiation Survey Project number: Doc. Number 6010-0014-D ~3-PHASE Purchaser's Doc. No.: No of sheets 14 Measurements AS .~ "'-- - '-' "-' h:\support\safety\radioactive source documents\6010-00140-d.doc '~ 3-PHASE Measurements AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 2 PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 TABLE OF CONTENT 1 GENERAL INTRODUCTION 3 2 GENERAL SURVEY INPUT 3 3 THE PHASETESTER I PHASEWATCHER 4 4 MONITORING PROCEDURE - SOURCE HOUSING 5 4.1 Summary of Results 6 4.2 Details of the Measurements 7 5 MONITORING PROCEDURE - DETECTOR HOUSING 8 5.1 Summary of Results 9 5.2 Details of the Measurements 10 6 MONITORING PROCEDURE - INLET, OUTLET AND PYTHON PORT 11 6.1 Summary of Results 13 6.2 Details of the Measurements 14 h:\document file\601 0\601 0-0014-d revOO.doc \.... .,/ \. "'" ~3-PHASE I'""" 3-PM Doc. 6010-0014-0 MUL TIPHASE FLOW METER Page: 3 Measurements AS PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 1 GENERAL INTRODUCTION This radiation survey procedure allows locations to perform radiation surveys of PhaseTesters and PhaseWatchers. The frequency requirements for performance of such a survey will vary from location to location, and will as well be dependent on client requirements when the meter is installed in the field. This document is made to be used for PhaseTesters and PhaseWatchers with Barium sources installed. The signed version of this document must be filed after the survey has been performed. 2 GENERAL SURVEY INPUT Meter Model Meter Serial Number Project Client Reason for Survey Survey Date Survey Radiation Meter Model Survey Radiation Meter SIN Survey Radiation Meter Calibration Date Calibrated by h:\document file\601 0\601 0-0014-d revOO.doc MUL TIPHASE FLOW METER 3-PHASE asurements AS 3-PM Doc. 6010-0014-0 Page: 4 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 3 THE PHASETESTER I PHASEWATCHER Figure 1: The PhaseTester Figure 2: The PhaseWatcher. h:\document file\601 0\601 0-0014-d revOO.doc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . ~ 3-PHASE FMeasurements AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 5 PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 4 MONITORING PROCEDURE - SOURCE HOUSING · Wear standard PPE. · The radioactive source is installed and the meter is set up as normal (either connected in the field or with inlet/outlet blind hubs on). · Perform the measurements as close as possible to the source housing/venturi connection (see figure 3 on next page). · Record the highest reading per point. 1) Source cover front 1A) At source cover front 1 B) 0.1 m away from source cover front 1 C) 1 meter away from source cover front 2) Top side of source housing 2A) At top side of source housing 2B) 0.1 m above top side of source housing 2C) 1 meter above top side of source housing 3) Left hand side of source housing 3A) At left hand side of source housing 3B) 0.1 m left from left hand side of source housing 3C) 1 meter left from left hand side of source housing 4) Right hand side of source housing 4A) At right hand side of source housing 4B) 0.1 m right from right hand side of source housing 4C) 1 meter right from right hand side of source housing 5) Bottom side of source housing 5A) At bottom side of source housing 5B) 0.1 m below bottom side of source housing 5C) 1 meter below bottom side of source housing h:\document file\601 0\601 0-0014-d revOO.doc 3..PHASE Measurernents AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 6 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · PHASETESTERfPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 Figure 3: The source housing connected to the Venturi section. 4.1 Summary of Results The reading must comply with lATA Dangerous Goods Regulations for Air Transportation as: "Radioactive Material, Excepted Package, - Limited Quantity of Material" and general regulations for encapsulatedfinstalled radioactive material which state the following: .. The surface radiation on the meter should be less than 1.0 µSv/h. Highest Reading (µSv/h) Background Radiation Reading (µSv/h) Highest Net Reading (µSv/h) Performed by Done at Date, Signature h:\document file\6010\6010-0014-d revOO.doc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . ~. 3-PHASE MUL TIPHASE FLOW METER .Measurements AS 3-PM Doc. 6010-0014-0 Page:? PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 4.2 Details of the Measurements Reference 1 2 3 4 5 Location 1A 2A 3A 4A 5A Units Radiation measured (µSv/h) Reference 1 2 3 4 5 Location 1B 2B 3B 4B 5B Units Radiation measured (µSv/h) Reference 1 2 3 4 5 Location 1C 2C 3C 4C 5C Units Radiation measured (µSv/h) COMMENTS: 3RD PARTY VERIFIED SUPPLIER INSPECTOR Name Sign. Date VERIFIED CONTRACTOR CLIENT Name Sign. Date h :\document fi Ie \601 0\601 0-00 14-d revOO .doc I: 3-PHASE FMeasurements AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 8 · · · · · · · · · · · · · · · · · · · · · · · · · · · '. · · · · · · · · · I. · · · · · · . PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 5 MONITORING PROCEDURE - DETECTOR HOUSING · Wear standard PPE. · The radioactive source is installed and the meter is set up as normal (either connected in the field or with inlet/outlet blind hubs on). · Perform the measurements as close as possible to the detector housing/venturi connection (see figure 4 on next page). · Record the highest reading per point. 1) Detector housing front 1 A) At detector housing front 1 B) 0.1 m away from detector housing front 1 C) 1 meter away from detector housing front 2) Top side of detector housing 2A) At top side of detector housing 2B) 0.1 m above top side of detector housing 2C) 1 meter above top side of detector housing 3) Left hand side of detector housing 3A) At left hand side of detector housing 3B) 0.1 m left from left hand side of detector housing 3C) 1 meter left from left hand side of detector housing 4) Right hand side of detector housing 4A) At right hand side of detector housing 4B) 0.1 m right from right hand side of detector housing 4C) 1 meter right from right hand side of detector housing 5) Bottom side of detector housing 5A) At bottom side of detector housing 5B) 0.1 m below bottom side of detector housing 5C) 1 meter below bottom side of detector housing h:\document file\601 0\601 0-0014-d revOO.doc · · · · · · · · · · · · · · · · · · · · · · · · Ie · 3-PHASE Measurements AS MUl TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 9 PHASETESTER/PHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 Figure 4: The detector housing connected to the Venturi Section. · · · · · · · · · e) · · · · · · · 5.1 Summary of Results The reading must comply with lATA Dangerous Goods Regulations for Air Transportation as: "Radioactive Material, Excepted Package, - Limited Quantity of Material" and general regulations for encapsulatedlinstalled radioactive material which state the following: · The surface radiation on the meter should be less than 1.0 µSv/h. Highest Reading (µSv/h) Background Radiation Reading (µSv/h) Highest Net Reading (µSv/h) Performed by Done at Date, Signature h:\document file\6010\6010-0014-d revOO.doc ~3-PHASE FMeasurements AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 10 · · · · · '. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Ie · · · · · · · . PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 5.2 Details of the Measurements Reference 1 2 3 4 5 Location 1A 2A 3A 4A 5A Units Radiation measured (µSv/h) Reference 1 2 3 4 5 Location 1B 2B 3B 4B 5B Units Radiation measured (µSv/h) Reference 1 2 3 4 5 Location 1C 2C 3C 4C 5C Units Radiation measured (µSv/h) COMMENTS: 3RD PARTY VERIFIED SUPPLIER INSPECTOR Name Sign. Date VERIFIED CONTRACTOR CLIENT Name Sign. Date h:\document file\601 0\601 0-0014-d revOO.doc · · · · · · · · · · · · · · · · · '. · · · · · · · · · · · · · '. · · · · · · · · .! · · · I: 3-PHASE r Measurements AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 11 PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 6 MONITORING PROCEDURE - INLET, OUTLET AND PYTHON PORT · Wear standard PPE. · The radioactive source is installed, the inlet and outlet hubs are removed and the Python plug is removed (see figure 5 and 6 on next page). · Record the highest reading per point. 1) Meter inlet 1A) At meter inlet 18) 0.1 m away from meter inlet 1 C) 1 meter away from meter inlet 2) Meter outlet 2A) At meter outlet 28) 0.1 m away from meter outlet 2C) 1 meter away from meter outlet 3) Python port 3A) At Python port top 38) 0.1 m above python port 3C) 1 meter above python port h:\document file\601 0\601 0-0014-d revOO.doc 3..PHASE Measurements AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 12 · · · · · · · · · · · · · · · · · · · · · · · · · · · · '. · · · · · · · · · · · Ie · · · PHASETESTER/PHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 Figure 5: Inlet and outlet connections. h:\document file\601O\601 0-0014-d revOO.doc ~ \. j ~3-PHASE 3-PM Doc. 6010-0014-0 MUL TIPHASE FLOW METER Page: 13 Measurements AS PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 Figure 6: Python Port. 6.1 Summary of Results The reading must comply with lATA Dangerous Goods Regulations for Air Transportation as: "Radioactive Material, Excepted Package, - Limited Quantity of Material" and general regulations for encapsulatedlinstalled radioactive material which state the following: . The surface radiation on the meter should be less than 1.0 µSv/h. Highest Reading (µSv/h) Background Radiation Reading (µSv/h) Highest Net Reading (µSv/h) Peñormed by Done at Date, Signature "'- h:\document file\601 0\601 0-0014-d revOO.doc 3-PHASE Measurements AS MUL TIPHASE FLOW METER 3-PM Doc. 6010-0014-0 Page: 14 PHASETESTERlPHASEWATCHER WITH Rev.: 00 BARIUM SOURCE RADIATION SURVEY Date: 16.02.01 6.2 Details of the Measurements Reference 1 2 3 Location 1A 2A 3A Units Radiation measured (µSv/h) Reference 1 2 3 Location 1B 2B 3B Units Radiation measured (µSv/h) Reference 1 2 3 Location 1C 2C 3C Units Radiation measured (µSv/h) COMMENTS: 3RD PARTY VERIFIED SUPPLIER INSPECTOR Name Sign. Date VERIFIED CONTRACTOR CLIENT Name Sign. Date h :\docu ment file \6010\6010-00 14-d revOO .doc ~ , ~ j;(G v-/~ q ~A /.' ""-- ?fft:JJi. ~ 'BAE NJ I " A 14 AUG 2003 Revision ~ 00 07 MAY 2003 Information BAE FH ED 01 04 Oct 2001 IDC JR BP Rev.: Date: Issued for: Made by: Checked: Approved: Title. Empty Pipe Reference Measurement 1 Procedure Project number Document number. 6010-0042-D Customer I Supplier document number. No. of pages. ~3-PHASE 6 Measurements AS I:" 3-PHASE No: 6010-0042-0 Empty Pipe Reference Rev.: 00 Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 2 of 6 TABLE OF CONTENTS 1 INTR ODU CTIO N ........................................................................................................................................ 3 1 .1 ASSREV A TIONS ..... .................................................... ...................................... ................................. 3 1 .2 REFERENCE OOCU MENTS ..................................................................................... .................... ..... 3 2 SA FETY WARN I NG ... ...... ............... ....... ...................... ....... ...... ............... ...... ........ .......... ...... ............. ....... 4 3 1M PORT ANT NOTE. ............... ............... .............. ....... ........ ............... ................... .......... ....... .......... .......... 5 4 E a U IPME NT NEEDED ... ........ ...... ...................... ................ .............. ............. ........ ........ ........ .................... 5 5 EM PTY PI PE R EFE RENC E PROCEDU R E.. ....... ....... ................... ........... ............ ......... ................ ...... ...... 6 '~ ~3-PHASE No: 6010-0042-D Empty Pipe Reference Rev.: 00 Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 3 of 6 ~ 1 INTRODUCTION The scope of this document is to describe step by step, how to prepare for and perform the Empty Pipe Reference Measurement for topside PhaseWatcher Vx. However it does not cover radiation safety and how to handle the radioactive source or any of the software operations needed to be able to perform the measurement. The purpose of the Empty Pipe Reference Measurement is to find No for the 3 energy levels: - (32Kev) - (81 Kev) - (356Kev) No represent the energy levels of a barium source, expressed in counts per second (cps) under vacuum conditions. The Empty Pipe Measurement is perlormed using Air at atmospheric conditions, or N2 under pressurized conditions. No is then found by calculating back to vacuum conditions using a known equation. 1.1 ABBREVATIONS Vx Meter PhaseTester with Sa 133 radioactive source, or Phasewatcher Vx Windows The two pressure barriers, of low attenuation material, in the radiation path inside the venturi. 1.2 REFERENCE DOCUMENTS -Service Computer Software User Manual -Gamma Radiation and Source Handling - Health, Safety and Environment Guidelines Vx Meters 2 SAFETY WARNING Empty Pipe Reference Measurement Procedure No: Rev.: Date: Page: 6010-0042-0 00 14-AUG-2003 4 of 6 Please note that it is imperative that the reference document Health, Safety and Environment Guidelines Vx Meters has been read, and necessary precautions taken prior to commencing this operation. Do NOT remove the Windows from the venturi when commencing the cleaning of the Windows operation according to this procedure. The Windows are pressure-retaining parts! ~3-PHASE No: 6010-0042-D Empty Pipe Reference Rev.: 00 Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 5 of 6 3 IMPORTANT NOTE The Empty Pipe Reference Measurement is the single most important measurement. This is because the result of this measurement is used in the equations and calculations of both Fluid/Gas References and of course general flow measurement. A high quality Empty Pipe Reference Measurement is especially important for High GVF Wells. Once the reference measurement has been done, the PhaseWatcher should not be moved until the job is completely finished. The Barium source must stay in the same position during the entire period. Make sure the temperature of the detector has stabilized before starting the Empty Pipe reference 4 eQUIPMENT NEEDED "-' To perform an Empty pipe calibration, the following equipment is required: D Cleaning material D Service Computer, Power Supply Unit, and cables. 3-PHASE Measurements AS Empty Pipe Reference Measurement Procedure No: Rev.: Date: Page: 6010-0042-D 00 14-AUG-2003 6 of 6 5 EMPTY PIPE REFERENCE PROCEDURE 1) Isolate the Vx Meter from the process. Make sure the meter is depressurised! 2) Open the reference port in the outlet spool if any, or disconnect the upper venturi hub from the process pipes. 3) Make sure that the Line Pressure Transmitter is zero trimmed, and that the Temperature Transmitter is showing the correct value. Zero trim the Line Pressure transmitter, with the venturi subjected to atmospheric conditions, as follows: PhaseWatcher: Follow the guidelines in the ref. document Service Computer Software User Manual. PhaseT ester: Make sure the impulse liners are completely filled with Frioge!. This is done by slowly pumping the Enerpac pump 8 strokes or more. Than follow the guidelines in the ref. document Service Computer Software User Manual. 4) Clean the Windows inside the venturi throat. Make also sure there is no moisture left above the Windows, and that no droplets may fall into the venturi from equipments placed above. Do not put your hands inside the venturi due to radiation hazard! 5) If Empty Pipe Reference is to be performed with Air, go to step 7. If performed with N2, test hubs must be installed on each side of the venturi. The test hubs must be fitted and equipped in such a way as to make it possible to flush N2 through, and to trap N2 inside the venturi. 6) Flush the venturi with N2 for 5 min. The operation is to be performed by increasing the N2 pressure very slowly, until the appropriate pressure is reached. This will ensure that no dirt or moisture from inside the blind tee is deposited on the Windows. Apply the N2 from the lower test hub to ensure that no air is trapped in the venturi. Close the outlet flushing port after 5 min and increase the pressure slowly to at least 10bar. Maintain this pressure during the reference measurement. 7) Perform the Empty Pipe Reference measurement in accordance with guidelines found in the ref. document Service Computer Software User Manual. The necessary preparative Software operations prior to the test are also described in this document. (If running "PhaseWatcher Mode", make sure the "Raw Data" box is ticked in the "Define PW Logging Window" of the Service Computer software) 8) The empty Pipe Reference measurement should be long enough to reach a standard deviation of 3 cps for all energy levels. However it is recommended to extend the measurement period, to obtain more accurate results. This is especially recommended for high GVF applications, where a standard deviation of 1 cps for all energy levels should be pursued. 9) It is strongly recommended that a second Empty Pipe Reference Measurement is carried out, to quality check your first result: 32 (2)-N32 (1) < 3 Cps N81 (2)-N81 (1) < 3 Cps N356 (2)-N356 (1) < 3 Cps Bear in mind the radioactive source decay should the time between the two recordings be long. 10) Keep track of all the parameters used on your multiphase flow meter throughout its lifetime. ~ \--/ A 14 AUG 2003 Revision ',-, 00 07 MAY 2003 Information "'-" 01 04 OCT 2001 IDC Rev.: Date: Issued for: Title. JR BP Made by: Checked: Approved: In Situ Fluid Reference Measurement Procedure Project number Document number. 6010-0043-D Customer I Supplier document number. No. of pages. 3-PHASE Measurements AS 8 ~ 3-PHASE No: 601 0-0043- 0 In Situ Fluid Reference Rev.: A Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 2 of 8 TABLE OF CONTENTS INTRODUCTION.,...... ,..........,..' ..................... ...........,........,.............. ................ ....., .................. ..... ............ 3 1.1 ABBREV A TIONS ....... ........ ................. .............. .................................... ..... .............. ........ ........ ....... .... 3 1 .2 REF ERE NeE DO CUM E N T S ...... . .. . . .. .. . . . .. .. . .. . . . . . . . . .. .. . .. . . .. .. . .. . . .. . .. .. .. . . .. . .. .. .. . . .. . .. . . . .. . .. . .. . . . .. .. .. . .. .. .. . .. .. 3 2 SA FETY WAR N IN G ..............,......... .................,..................................., ............ ...... ........ ....... ......... ........... 4 3 DESCRIPTION AND USE OF REFERENCE/CALIBRATION TOOL ....................................................... 5 4 EQUI P ME NT NEEDED..................................... ......................................... ........ .................... ......... ...... ..... 6 5 FLUID REFERENCE MEASUREMENT STEP BY STEP ......................................................................... 7 ~ ~3-PHASE No: 6010-0043-0 In Situ Fluid Reference Rev.: A Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 3 of 8 1 INTRODUCTION The scope of this document is to describe in a step by step fashion, how to perform in situ Fluid Reference Measurements. However this document does not cover radiation safety and how to handle the radioactive source nor does it cover the software operations needed to be able to perform the measurement. The purpose of Fluid Reference Measurements is to find the Mass Attenuation coefficients for water and oil. The mass attenuation coefficients are used during flow measurements to calculate the fraction of oil, water and gas at the throat of the venturi. In situ Reference Measurement can be performed by one of the following two methods: - The Vx Meter can be filled up with the relevant fluid to a level where the Windows are covered (+1 Ocm). - A Reference Tool can be provided to make it possible to perform in situ. 1.1 ABBREV A TIONS ~~ OAFC Data Acquisition Flow Computer Windows The two pressure barriers, of low attenuation material, in the radiation path inside the venturi. Vx Meter PhaseTester with Sa 133 radioactive source, or topside / subsea Phasewatcher ""-' 1.2 REFERENCE DOCUMENTS -Service Computer Software User Manual -Gamma Radiation and Source Handling -Guidelines to Health, Safety and Environment "'-' ~ 3-PHASE No: 6010-0043-0 In Situ Fluid Reference Rev.: A Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 4 of 8 2 SAFETY WARNING Please note that it is imperative that the reference document Health, Safety and Environment Guidelines Vx Meters has been read, and necessary precautions taken prior to commencing this operation. Do not put your hands inside the venturi due to radiation hazard! Do NOT remove the Windows from the venturi when commencing the cleaning of the Windows operation according to this procedure. The Windows are pressure-retaining parts! ~3-PHASE No: 6010-0043-0 In Situ Fluid Reference Rev.: A Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 5 of 8 3 DESCRIPTION AND USE OF REFERENCE/CALIBRATION TOOL The Reference Tool is composed of a hollow rod (2) with a sampling container (1) at the end. An O-ring (3) acts as seal between the sampling container, and the sides of the venturi. There is a hole drilled through the top of the hollow rod that is exactly in line with the aperture in the sampling container through which the radioactive beam passes. This guide makes it possible for the Tool to be inserted into the venturi and aligned exactly by ensuring that the drilled hole through the top of the rod is aligned in parallel with the detector and source housings mounted on the sides of the venturi. When inserting the tool, a certain amount of force may have to be applied in order to get the Tool into position, due to the friction between the O-ring and the venturi throat. When inserted properly, the aperture in the sampling container should be aligned between the two Windows (radiation path) in the venturi. NB! Before inserting the Tool: - ensure that the sampling container and the internal rod are cleaned and dried. - inspect the O-rings for damage. - DO NOT LUBRICATE THE 0 RINGS AS DOING SO MAY SOIL THE WINDOWS HOLE TO BE [lRIU[[f AHU ASSUi8U"-\ ED - Typical Reference Tool ~ 3-PHASE WMeaSurements AS In Situ Fluid Reference Measurement Procedure No: Rev.: Date: Page: 6010-0043-0 A 14-AUG-2003 6 of 8 4 EQUIPMENT NEEDED - Service Computer, Power Supply Unit and cables - Cleaning Material - Reference Tool (Optional PhaseWatcher) (Also called Calibration Tool): · Reference Tool for 29.25mm Venturi throat, 3PM Part N° : 6009-1477-4 O-Ring PARKER #2-119 - Type: 23.47x2.62 - VITON V747-75 · Reference Tool for 52mm Venturi throat, 3PM Part N° : 6009-1479-4 O-Ring PARKER #2-134 - Type: 47.29x2.62 - VITON V747-75 · Reference Tool for 87.5mm Venturi throat, 3PM Part N° : 6009-1572-4 O-Ring PARKER #2-235 - Type: 78.97x3.53 - VITON V747-75 · Reference Tool for 29.25mm PhaseTester Venturi throat, 3PM Part N° : 6009-1482-4 O-Ring PARKER #2-119 - Type: 23.47x2.62 - VITON V747-75 · Reference Tool for 52mm PhaseTester Venturi throat, 3PM Part N° : 6009-1485-4 O-Ring PARKER #2-134 - Type: 47.29x2.62 - VITON V747-75 The recommended Volume of Fluid Sample to use for a Reference Tool is approximately: · Vx 87.5 mm: 295 cc · Vx 52 mm: 70 cc · Vx 29.25 mm: 30 cc "- ~ ~~ ~' ~3-PHASE No: 6010-0043-0 In Situ Fluid Reference Rev.: A Measurement Procedure Date: 14-AUG-2003 Measurements AS Page: 7 of 8 5 FLUID REFERENCE MEASUREMENT STEP BY STEP 1) Isolate the Vx Meter from the process. Ensure that the meter is depressurized! 2) Open the reference port of the outlet spool if any, or disconnect the upper venturi hub from the process pipes. 3) Make sure that the Line Pressure Transmitter is zero trimmed, and that the Temperature Transmitter is showing the correct value. Zero trim the Line Pressure transmitter, with the venturi subjected to atmospheric conditions, as follows: PhaseWatcher: Follow the guidelines in the ref. document Service Computer Software User Manual. PhaseTester: Make sure the impulse liners are completely filled with Friogel. This is done by slowly pumping the Enerpac pump 8 strokes or more. Then follow the guidelines in the ref. document Service Computer Software User Manual. 4) Clean the Windows inside the venturi. Ensure that there is no moisture left above the Windows. DO NOT put your hand inside the venturi during the process, due to radiation hazard! . In cases where a fluid reference is to be carried out without a Reference Tool, please jump to step 6b. 5) To check for correct alignment of the Reference tool, an Empty Pipe reference measurement must be performed before and after entering the tool, according to the following procedure: a) Perform an Empty Pipe Reference for 15 min, without updating the DAFC. Write down the results. Updating the OAFC will flush the original Empty Pipe Measurement. b) Then insert the Reference Tool as described in chapter 3, and perform an additional Empty Pipe Reference measurement the same way for 5 min without updating the OAFC. Compare the two results to verify that the Reference Tool has been inserted properly, and to ensure that nothing is obscuring the Windows. The difference in numbers count should be less than 20 cps for each energy level. 6) If both oil and water fluid reference measurement is to be performed, start with the water measurement to ease to cleaning of the venturi between the two measurement. a) Pour the liquid sample inside the Reference tool. The Use of a funnel is recommended. When the sample is a high viscosity liquid, it may be heated first to aid flow characteristics. If heated, make sure that the temperature is allowed to be stabilized before performing the reference measurement. b) In cases where a fluid reference is to be carried out without a Reference Tool, enough fluid must be poured into the venturi to cover the Windows by approx.1 Ocm. 7) Perform the Fluid Reference measurement according to the ref. document Service Computer Software User Manual. The necessary preparative Software operations prior to the test are also described in this document. (If running "PhaseWatcher Mode", make sure the "Raw Data" box is ticked in the "Define Pw Logging Window" of the Service Computer software) Visually check the level of liquid in case of leaks. NOTE: The software will not compensate for temperature changes. Do not start the measurement until the temperature of the fluid is stable. Make sure the temperature is stable during the whole measurement period. 8) The typical acceptance criteria for a fluid point reading is a standard deviation of less than 0.000003m2/kg. 9) It is recommended that a second Fluid reference Measurement be taken, to double check that the variations of Mass attenuations for the 3 energy levels are less than 0.00001 m2/kg. On completion compare the two measurements. In Situ Fluid Reference Measurement Procedure 3-PHASE Measurements AS No: Rev.: Date: Page: 601 0-0043- 0 A 14-AUG-2003 8 of 8 10) An additional verification can be performed if required, by starting a 5-minute flow period. This process is described in ref. Doc. Service Computer Software User Manual. The operating point shown in the "Triangle" window of the Service Computer Software, should be at the same spot as the relevant fluid reference point. 11) Remove the Reference Tool and clean it thoroughly. Start again from Step 3 if a new reference Measurement involving another fluid is to be performed. '-" '- lÞrI/ (y{fn ~7 ß-?5 . 00 07 -MAY -2003 INFORMATION BAE DRD ED 01 28-APR-2003 IDC BAE DRD Rev.: Date: Issued for: Made by: Checked: Approved: Title. Maintenance & Troubleshooting Manual PhaseWatcher Vx Project number Document number. 6010-0140-D Customer I Supplier document number. No. of pages. "" 3-PHASE 18 Measurements AS ~ "- '-' ~,._--- ~.~,"-.,-- 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07 -MA Y -2003 2 of 1 8 TABLE OF CONTENTS 1. I NTRODU CTION .. ...................... ................. ............... ..... ..... ........................ .... n....... ......... ..... ....... ........ 3 1.1 SCOPE............. ..................... ...... .......... ....................... ............................................ ............. .............. 3 1 .2 ABBREVIATIONS. ................... ......................................................... ............... .......... ......................... 3 1.3 DOCUMENT REFER ENCES .................. ........ ....... ........ ........... ....... ................ ............... .................... 3 2. SAFETy......... ................ ................................... ..................................................... ............... .................. 4 3. G EN ERA L............. ......... ............ ..... .......... ........ ....... ........ ......... .... .................... ... ...... ........... ............ ...... 5 3.1 VISUAL INSPECTION........... ......... .............. .......... ..... ....... ... ............ ........................ ..................... ..... 5 4. PR EVENT A TIVE MA INTE NANCE... .......... ........ ......................................... ................ ....... .................... 6 4.1 GREASINGfTlGHTENINGfTORQUE CHECKING OF BOLTS/LUBRICATION ................................. 6 4.2 VALVE MAINTENANCE.... ............ ...................... ....... ......................... .... ...... ........... ........................... 6 5. REM E DIAL MAINTE NANCE ........................... ......................... ............. ........... .......... ..... ................ ...... 7 5.1 SOURCE HOUSING .............. ................. .... .......... ....... ............ ........... .......... ................................ ...... 7 5. 1. 1 REMO VING THE SOURCE HOUSING....................................................................................... 7 5. 1.2 INSTALLING THE SOURCE HOUSING...................................................................................... 7 5.2 DETECTOR HOUSI NG.. ............. ......... .................. ...... ........ ..... ........... ...... ......... ................................ 7 5.2. 1 REMOVING THE DETECTOR HOUSING..... ........ ............ ........ .......... .................... ...... ......... ..... 7 5.2.2 INSTALLING DETECTOR HOUSING......................................................................................... 8 5.3 DIS-ASSEMBL Y / ASSEMBLY PROCEDURE CLAMPS ................................................................... 8 5.3.1 DIS-ASSEMBL Y PROCEDURE FOR THE CLAMP .................................................................... 8 5.3.2 ASSEMBLY PROCEDURE FOR THE CLAMP ........................................................................... 8 5.4 WIN DO WS .......................................................................................................................................... 9 5.4.1 Braced tablet Window (BT) .......................................................................................................... 9 5.4.2 Monolithic Window (MW) . ............... ......... ....... ........... ................. ............. ............................ ........ 9 5.5 TRANSMITTERS ........ .......... .................... ............... .... ......... ............... ................................ ..... .......... 9 5.5.1 DP TRANSMITTER..... ..... ...... ......... ..... ....................... ............... ............. ............ ..... .................... 9 5.5.2 PT TRANSMITTER... ...................... .................. ...... .................. .... ............ ................................. 11 5.6 SOURCE ASSEMBLY INSTALLATION/REMOVAL... ...... ....... ............. ................. ............... ...... ...... 11 5.7 J U N C T ION BO X .. . . .. . . . . .. .. .. . . .. .. .. .. .. .. . . . .. .. .. .. . . . .. .. . . . . .. .. .. . . .. .. .. . .. .. .. . . .. .. . . .. .. .. . .. .. .. .. .. . . . . .. .. . .. . .. . .. . .. . .. . .. .... 1 2 5.8 DOUBLE BLOCK AND BLEED VALVE (OPTIONAL) ...................................................................... 12 6. PE R IODIC MAINTE NANCE......... .... ....... ..... .......... ......... ................ ....... ....... .... ........ ........ ...... ............. 13 7. TROU B LE SHOOTING . .................... ............. ................. ................. ...... ..................... ........ ...... ........... 14 7.1 OPERATING OUTSIDE OPERATING ENVELOPE .... ............ .......... ...... ..... .......... ....... ..... .............. 14 7.2 ERRON EOUS WLR-MEASUREMENT ... ............... ...... ..... ............ ............ ........ ....... ......... ................ 14 7.3 ER RON EOUS G VF-MEASU REME NT .................................................................... ...... ................... 14 7.4 DR I FT IN WLR .................................................................................................................................. 1 5 7.5 ERROR IN NUCLEAR LINEARIZATION MODEL ............................................................................ 15 7.6 ERROR IN INTERPRETATION MODEL .......................................................................................... 16 7.7 HART COMM U N ICA TION ERROR.......................................................................... ........................ 16 7.8 VENTURI DIFFERENTIAL PRESSURE FAULTY ~P-READINGS .................................................. 16 7.9 VENTURI LINE PRESSURE EXCEEDS LIMIT ................................................................................ 16 7.10 LINE/AMBIENT TEMPERATURE EXCEEDS LIMIT ..................................................................... 17 7.11 DEFECT IN RA SOURCE ASSEMBL Y ......................................................................................... 17 8. TOR au E TAB LE............ .......... ........ ............................................... ....... ...................... ............... ......... 18 .'-'. ~ -~""""--'~.-- ~.. 3-PHASE v Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-D 00 07-MA Y -2003 3 of 18 1. INTRODUCTION 1.1 SCOPE The scope of this Maintenance Manual is to provide a technical description of the required Maintenance program. Detailed descriptions of how to install/remove any parts and Troubleshooting in case of failure, is also included in the scope. References are made to relevant documents where applicable. Descriptions in this manual and its references may differ slightly from the actual PhaseWatcher Vx meter(s) delivered in the case of Client specified options. In case of conflicts between documents, the MRB documents should be considered the most accurate for each individual PhaseWatcher. This book is delivered with each PhaseWatcher Vx to the Client. 1.2 ABBREVIATIONS DAFC DBB DP GVF HART LOM MRB WINDOWS Source Assembly Source Housing Data Acquisition Flow Computer Double Block and Bleed Valve Differential Pressure Gas Volume Fraction Highway Adressable Remote Transducer List of Materials Manufacturing Record Book The two pressure barriers, of low attenuation material, in the radiation path inside the venturi. 133Ba gamma source installed in a source holder The shielded housing mounted on the measuring section of the Vx Meter, in which the Source Assembly is installed. 1.3 DOCUMENT REFERENCES Schedule of Electrical Equipment in Hazardous Area for Phase Watcher Vx. Gamma Radiation & Source Handling for Phase Watcher Vx Installation/Removal Procedure for Smarl Gamma Detector NamePlate Drawing Interconnection Drawing Phase Watcher Vx General Arrangement Drawing Health, safety and Environment Guidelines Vx Meter Note! All Document references are referred to by title, in Italics ! """----. i I ~A~-PHASE ~asurements AS 2. SAFETY ~---_.~~ --. -,_.~~---~~-~- Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07-MAY-2003 4 of 1 8 Please note that it is imperative that the reference document Guidelines to Safety, Health and Environment has been read, and necessary precautions taken prior to commencing this operation. · · · · · -- · · · · "-" . ~ I: 3-PHASE WMeasurements AS No: Rev.: Date: Page: 601 0~0140-D 00 07 -MA Y -2003 5 of 18 Maintenance & Troubleshooting Manual PhaseWatcher Vx 3. GENERAL 3.1 VISUAL INSPECTION It is recommended to perform the following visual inspection on a monthly basis: . Check all electrical installations on the PhaseWatcher Vx unit for mechanical damage. . Check that equipment and cable tags are in place and legible on all instrumentation, cables and junction boxes installed on the PhaseWatcher Vx unit. Transmitter/Detector - 1 tag on equipment and 1 at mounting position. Junction Box - 1 tag mounted on Junction Box. Cables - 1 tag at each end. The relevant Tag Nos. can be found in the Interconnection Drawing Phase Watcher Vx. Check that all instrument items and junction boxes on the PhaseWatcher Vx unit are mounted properly, and that the mountings are secure and have not loosened. Check that all cables are properly mounted on the PhaseWatcher Vx unit. Check that all cable glands installed on the PhaseWatcher Vx unit are of correct type. Ref. Interconnection Drawing Phase Watcher Vx. Check legibility of labelling on all instruments and junction boxes installed on the PhaseWatcher Vx unit. (Ref. Schedule of Electrical Equipment in Hazardous Area for Phase Watcher Vx.) Check that the gamma detector housing is fitted with a red warning sign for radioactive radiation. "DO NOT REMOVE HOUSING BEFORE THE BARIUM SOURCE HAS BEEN REMOVED" and that this sign is easily legible. Check that the metal cover on the gamma source is fitted with a Radioactive Material identification sign and that the sign is legible. Check that the cover is sealed with two off seal strings. Check that the PhaseWatcher Vx Nameplate is fitted and legible. Ref. Nameplate Drawing. Check that Pipe Supports are correctly and securely connected, and that no structural damage or loosening has taken place. Check for visible leakage/seepage around tubing connectors, pipe joints, valve flanges etc. -.. . - ---_._._-~-- 3..PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07 -MA Y -2003 6 of 1 8 -I I 4. PREVENTATIVE MAINTENANCE 4.1 GREASINGrrlGHTENINGrrORQUE CHECKING OF BOL TS/LUBRICA TION As part of the Preventative maintenance program, all fastenings should be checked for correct torque settings, tightened appropriately and lubricated or greased regularly. Torque details are available in Section 8.0 of this document. All threads should be lubricated, and fastenings open to the elements should also be greased. A US spec bolting kit (Millimetre to Inch adapter) is available on request. NB! All bolts supplied, except for US Junction Box, will have Millimetre threads. 4.2 VALVE MAINTENANCE If Double Block and Bleed (DBB) option has been chosen, the following routines are recommended. Regular opening and closing of the valves will prevent any build up of 'silt' and ensure smooth problem free opening/closing when required for process control. '~ '~ 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-D 00 07 -MA Y -2003 7 of 1 8 5. REMEDIAL MAINTENANCE Only use spare parts according to the specifications for the PhaseWatcher Vx delivered. All spare part components must must be obtained from Schlumberger I Framo, or the accuracy of the measurement and the warranty guaranteed by Schlumberger I Framo may be revoked. 5.1 SOURCE HOUSING 5.1.1 REMOVING THE SOURCE HOUSING Before commencing this operation, ensure that radioactive source assembly has been removed (ref. Gamma Radiation & Source Handling for Phase Watcher Vx) Remove housing by removing 4 x 16mm Allen bolts, using a 14mm Allen key. 5.1.2 INSTALLING THE SOURCE HOUSING 1) Ensure the source housing is clean and without any damage. 2) Ensure that the gamma ray path is clean and no grease, fluid or dust present (Window, back flange). 3) Put Chesterton grease on the full length including threaded area, of the four 16mm socket heads bolts. This will prevent friction when bolts are passed through the Source Housing. 4) Place the complete source housing in position, Ensuring that the 0 ring between the source housing and venturi is properly in place. 5) Put the four 16mm bolts in place, and tighten them with an 14mm Allen key using a torque of 197Nm. 6) Remember to stamp the warning label on the source housing, with the radioactive source serial number and test date (See Gamma Radiation & Source Handling for Phase Watcher Vx). 5.2 DETECTOR HOUSING 5.2.1 REMOVING THE DETECTOR HOUSING 1) Remove radioactive source assembly according to reference document: Gamma Radiation & Source Handling for Phase Watcher Vx, 2) Remove detector and secure detector housing top according to reference document Installation/removal Procedure for Smart Gamma Detector) 3) Remove housing by removing 4 x 16mm Allen bolts, using a 14mm Allen key. 1---- 3-PHASE ~easurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07 -MA Y -2003 8 of 18 5.2.2 INSTALLING DETECTOR HOUSING 1) Ensure the detector housing is clean and without any damage. 2) The contact surfaces between the venturi and the detector housing must be checked for any scratches or other form of damage. If any visible damage are found, must the detector housing not be mounted until the relevant part is repaired/replaced. This due to the Hazardous Area Certification. 3) Ensure that the gamma ray path is clean and no grease, fluid or dust present (Window, back flange). 4) Put Chesterton grease on the threaded area of the four socket heads bolts. 5) Place the complete Detector housing including collimator in position, Ensuring that the 0 ring between the housing and venturi are properly in place. 6) Put the four 16mm bolts in place, and tighten them with a 14mm Allen key using a torque of 197Nm. 7) Remember to stamp the Shielding Plate on the Detector Housing with PhaseWatcher serial number. 5.3 DIS-ASSEMBL Y I ASSEMBLY PROCEDURE CLAMPS 5.3.1 DIS-ASSEMBL Y PROCEDURE FOR THE CLAMP Check that the line is depressurised. Never assume that the line has been depressurised. Gradually loosen clamp. Lightly shock the clamp segments with a suitable hammer. This should release the seal ring contact and allow the clamps to freely rotate and/or rock about the hubs. Do not proceed until clamps are free to rotate or rock. 5.3.2 ASSEMBLY PROCEDURE FOR THE CLAMP Inspect the component prior to assembly. Hubs and seal ring surfaces must be clean and free from foreign matter. Damage to hub seal surface is not acceptable, and should be rectified before assembly. Seal rings are coated which acts as lubricant during the make-up. If required light oil can be used. Take care that no solid particles are present in the lubricant. Check the seal ring stand off, the seal ring should rock slightly against the hub face. Hubs should be aligned so that seal rings can be installed between hubs. Do not attempt to correct badly misaligned piping by clamping face alone, piping pulling forces should only be released when clamp is fully assembled. Install the seal ring into the hub groove, and assemble the clamps around the hub. Lubricant applied to the Hub/Clamp contact area will aid assembly. The clamps should be fitted such that the spherically faced nuts are located into the spherical seats of the clamps. Lubrication of the nut faces and bolt threads is recommended. The clamp bolts should be tightened in a uniform manner. Bolting should be lightly. Keep the spacing between clamp halves approximately equal. Clamp segments should be shocked with suitable soft-faced hammer to aid assembly. Always re-tighten bolts after shocking. See section 8 for bolt torque. ~' ",-,J Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07-MAY-2003 9 of 1 8 5.4 WINDOWS To identify which Window type the PhaseWatcher Vx is fitted with, please look at the General Arrangement Drawing. In the Title Field will the type of Windows be stated, BT or MW Windows. The windows shall NOT be removed unless it is required due to failure of the Windows, due to the pressure integrity of the PhaseWatcher. If there is a suspicion that the pressure integrity of the Window on the Source assembly side has failed, do NOT perform ANY work on the meter. The integrity of the Barium radioactive may have failed, due to high pressure. The reference document Gamma Radiation and Source Handling Phase Watcher Vx, gives guidelines and instructions of actions to be performed. 5.4.1 Braced tablet Window (BT) NB! These items are pressure-retaining parts and must not be removed before pressure is bled off. Remove: 6 x 1 Omm Allen Bolts, using 8mm Allen key and pull out window assembly (c/w metal seal). Install: Place new metal seal in the metal seal groove of the Window. Place unit in position, check that metal seal is correctly aligned, install bolts and tighten - torque to 47Nm. Use Chesterton 785 on the threads of the bolts. NOTE! Pressure test must ALL WAYS be performed after installation of new Window 5.4.2 Monolithic Window (MW) Please contact FRAMO/SLB should this operation become necessary. 5.5 TRANSMITTERS Removal/installation for the different transmitters shall be performed according to the flowing procedures: 5.5.1 DP TRANSMITTER Removal: 1) Switch off power to PhaseWatcher, and ensure that the meter is depressurised - Ref. Client procedures. 2) With optional Double Block and Bleed Valve: a. With this option it is unnecessary to bleed off pressure to the whole system prior to valve operation. b. Close Block valve nearest the Venturi. c. Open Bleed Valve. 3) Remove Transmitter cable - ensuring protection of cable end against ingress of water. 4) Remove the two Remote seals by removing the 8 x 16mm Nuts on each remote seal flange. NB! Remote seal face must immediately be protected from accidental damage. -~, ---...__..__._~~-- 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07 -MAY -2003 1 0 of 1 8 -~--.-~~ 5) Loosen and remove (Hex bolts 4 x M8) DP Transmitter housing together with bracket from the Venturi body. Installation: 1) Ensure that power is switched off. 2) Treat Hex bolts (Hex bolts 4 x M8) with Loctite 243 or similar. 3) Bolt DP Transmitter housing together with bracket in position. 4) In case of DBB option, make sure the drain is bled off, and both Block valves are closed before going to next step 5) Clean Venturi Remote Seal ports or DBB Remote Seal port (if applicable) and metal seal grooves with spirit. 6) Place C-Rings in their respective positions. 7) Place the Remote Seals carefully in position on top of C-Rings. Ensure that High Pressure Seal is installed in lower port position and low pressure Seal at Venturi throat. (Capillary tubes to be positioned with a horizontal orientation towards DP-Transmitter). 8) Ensure that Remote Seals are centred before torque is applied. 9) Treat Nuts with Loctite or equivalent. Torque nuts (8 x M16) to 197Nm. NOTE! This is a pressure barrier. 10) Perform pressure test. 11) Attach Cable to gland in accordance with gland specification. 12) +/- Wires to be connected to Transmitter Terminal. Earth wire is to be a floating earth on transmitter side - not terminated. 13) If DBB is installed close Bleed valve and open Block valve. 14) Power up system, ensure contact through Service Computer, and perform Zero trim. See Service Computer User Manual. ""-'" , 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-D 00 07-MAY-2003 11 of 1 8 5.5.2 PT TRANSMITTER Remove 1) Switch off power to PhaseWatcher. 2) Ensure that the meter is depressurised - Ref. Client procedures. 3) With optional Double Block and Bleed Valve: With this option it is unnecessary to bleed off pressure to the whole system prior to valve operation. Close Block valve nearest the Venturi. Open Bleed Valve. 4) Remove Transmitter cable - ensuring protection of cable end against ingress of water. 5) Loosen and remove Pressure Tube from Transmitter Pressure Port. 6) Loosen and remove (Hex bolts 4 x M8) PT Transmitter housing together with bracket from the Venturi body. Install 1) Ensure that power is switched off. 2) Treat Hex bolts (Hex bolts 4 x M8) with Loctite 243 or similar. 3) Bolt PT Transmitter housing together with bracket in position. 4) Connect Pressure Tubing to Transmitter Pressure Port. 5) Perform pressure test 6) Attach Cable to gland in accordance with gland specification. 7) +/- Wires to be connected to Transmitter Terminal. Earth wire is to be a floating earth on transmitter side - not terminated. 8) If DBB is installed close Bleed valve and open Block valve. 9) Power up system, ensure contact through Service Computer, and perform Zero trim. See Service Computer User Manual. 5.6 SOURCE ASSEMBLY INSTAllATION/REMOVAL Please see reference document: Gamma Radiation and Source Handling for Phase Watcher Vx. No: Rev.: Date: Page: 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx 601 0~0140-D 00 07 -MAY -2003 1 2 of 1 8 5.7 JUNCTION BOX When maintenance or repair requires the Junction Box to be opened, then the Corrosion inhibitor pad and Dessicant must be replaced. Flame Gap surfaces are to be cleaned and inspected prior to closing. Should damage be found, visible scratches etc., repair or replacement must take place. A thin layer of Chesterton grease must be applied to the Flame Gap surface prior to closing. 5.8 DOUBLE BLOCK AND BLEED VALVE (OPTIONAL) If leakage or seepage is observed, check bolt torques, open and close valves (having first ensured isolation from process), to ensure that no build up has taken place, and that the valve ports are closing correctly, if this fails to give results the valve should be replaced. \~ ."-" 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07 -MA Y -2003 13 of 18 6. PERIODIC MAINTENANCE Activity Description Ref. Document Routine Maintenance Radioactive Gamma Radiation & Source Handling Replace radioactive source approx. Source every 10 years Replacement: Visual Inspection: See Chapter 3.1 Every month: Perform equipment visual inspection Junction Box Dessicant and Replace every two years Corrosion inhibitor Transmitters Calibration Transmitter Calibration Procedure Every 12 months DP and PT Transmitter Zero Trim Service Computer SW User Manual At start/completion of every metering period: Perform DP and PT transmitter zero trim Fraction Meter Reference Service Computer SW User Manual Every 6 months and at start/completion Measurements of every metering period: In-Situ Fluid Referance Measurement Procedure Perform reference measurements of gas water and oil Empty pipe Reference Service Computer Software User At start/completion of every metering Measurements Manual period: Empty Pipe Referance Measurement Perform empty pipe reference Procedure measurement Fluid and Gas Property Values Service Computer Software User Every 12 months, or when there is a Manual, suspicion that properties may have changed: Check and update fluid and gas property values Wipe test Gamma Radiation & Source Handling Suspect source integrity: PhaseWatcher Perform wipe test procedure ~_._._.---- 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07 -MA Y -2003 14 of 1 8 7. TROUBLE SHOOTING Metering problems are usually connected to a failure in oil, water or gas references, problems related to the electronics or to errors in the set up of the meter for the specific application. Trouble with the electronics can usually be traced to one of the transmitters or to the Multi Energy Fraction Meter. 7.1 OPERATING OUTSIDE OPERATING ENVELOPE ALARM: Venturi Differential Pressure > 5 bar Venturi Differential Pressure < 50 mbar Description: Venturi Differential Pressure Exceeds Limits. Gas Volume Fraction and WLR measure not affected. Venturi Differential Pressure measurement exceeds 5 bar Limit. Venturi Differential Pressure measurement exceeds 50 mbar Limit. Possible reasons PhaseWatcher Vx operating outside its envelope. Line Pressure too low or Flow Rates not in Meter Operating Envelope. All Flow Rate calculations are underestimated. All Flow Rate calculations have larae uncertainties. How to repair Verify against Operating Envelope. If necessary and possible, change the choke position in order to get inside the Operating Envelope i.e. decrease Venturi Differential Pressure to less than 5 bar, then increase the line pressure - close the choke. 7.2 ERRONEOUS WLR-MEASUREMENT How to repair Erroneous WLR-measurement - outside ex ectations WLR is outside ex ectations, differs from sam Ie measurements Typical erroneous salinity and/or empty-pipe. In case of high sulphur content the oil and as mass attenuation coefficients mi ht be wron . If possible take a liquid sample from the flow through the PhaseWatcher Vx to verify if the Vx is wrong. Measure the salinity and compare with current values in the Vx. Schlumberger/FRAMO can provide a re-computing service with updated mass attenuation coefficients. ALARM: Descri tion: Possible reasons 7.3 ERRONEOUS GVF-MEASUREMENT How to repair Erroneous GVF-measurement - outside ex ectations The Gas-Li uid Ratio is ossibl wron Give attention to oil and water density. The PhaseWatcher Vx is less sensitive to as densit . If possible take a liquid sample from the flow through the PhaseWatcher Vx to verify the oil and water density. Then manually introduce the density parameters for oil and water. ALARM: Oescri tion: Possible reasons "-'~ ,-,,' -_.... ~3-PHASE Maintenance & No: 601 0-0140~D Troubleshooting Manual Rev.: 00 Date: 07-MAY-2003 Measurements AS PhaseWatcher Vx Page: 15 of 18 7.4 DRIFT IN WLR Description: WLR is increasing or decreasing continuously and does not correspond with WLR from sam les taken a ainst time. The PhaseWatcher Vx ends up showing 100% or O%WLR. Oil and Water flow rates are wron ,Gas and total Ii uid flow rates OK. This could be a scaling problem. It could also be change of water properties due to breakthrou h of in'ected fresh water. Descalin should solve this roblem. ALARM: Possible reason How to re aÎr 7.5 ERROR IN NUCLEAR LINEARIZATION MODEL ALARM: Numerical Error nuclear IinearÎzation model in the Alarm & Events screen. Description: An illegal mathematical operation was about to be executed. Possible reasons This error may have been caused by a bad 'empty pipe' reference. A faulty Gamma Detector. How to repair A bad empty pipe reference can be corrected by performing an On-Site Empty Pipe Reference Measurements. If this does not cure the problem, the Gamma Detector and the wiring must be investigated. ~" ....~....,__.·4_"·_4_____~ 3-PHASE Measurements AS Maintenance & Troubleshooting Manual PhaseWatcher Vx No: Rev.: Date: Page: 6010-0140-0 00 07-MAY-2003 1 6 of 1 8 7.6 ERROR IN INTERPRETATION MODEL How to repair Numerical Error inter retation model in the Alarm & Events screen. An ille al mathematical 0 eration was about to be eriormed. This error may be caused by an inaccurate empty pipe reference, PVT setting, fault transmitter or corru ted IN! file. An inaccurate empty pipe reference can be corrected by performing On-Site Empty Pipe Reference Measurement. A fault in PVT setting can be observed by the fluid point reference located outside the triangle, and can be corrected by investigating the empty pipe reference and eriormin a new Fluid Point Reference Measurement. ALARM: Oescri tion: Possible reasons 7.7 HART COMMUNICATION ERROR Possible reasons Common Alarm (CA), transmitter Present Not Defined (PND) and Response Timeout RT alarms for s ecific transmitter in the Dia nostic screen. The transmitter is detected by DAFC, but is not configured. The actual transmitter has failed to res ond to 3 consecutive re uests for data. The transmitter has faulty HART-address according to the system confi uration, the transmitter ma be fault or corru t INI file. Check the transmitters HART-address in the HART Communication screen, the configuration shall be according to document /23/. Correct the HART-address for the actual transmitter, download the updated address and restart the DAFC. ALARM: Description: How to repair If this does not cure the problem, the transmitters and the wiring must be investi ated. 7.8 VENTURI DIFFERENTIAL PRESSURE FAUL TV i1P-READINGS ALARM: None, but the reading of the Differential Pressure Transmitter is not as expected from historical data. Description: Venturi Differential Pressure Exceeds Limits. Fractions will not be affected by this, but the flow rates will be wrong and indicate wrong values. Possible reasons for alarm Drift in transmitter over time or improper use of the transmitter. 7.9 VENTURI LINE PRESSURE EXCEEDS LIMIT ALARM: Venturi Absolute Pressure Exceeds Limit Description: This alarm is set if the Venturi line pressure exceeds the limits set in ALARMS. A faulty pressure reading will influence both the flow rates and the fraction measurements as well as the density calculations. Possible reasons The pipeline pressure is higher or lower than expected. The pre-set alarm limits set at the start of the meterinQ period can be chanqed. ""-' '"",-"I ~3-PHASE Maintenance & No: 6010-0140-0 Troubleshooting Manual Rev.: 00 Date: 07-MAY-2003 Measurements AS PhaseWatcher Vx Page: 17 of 1 8 By pass valve and outlet isolation valve closed. Faulty reading caused by transmitter failure or faulty wiring. Pressure Line breakage. How to repair Investigate the actual value from the transmitter and compare with the limits set under ALARMS. Compare reading with analogue pressure meter and any other meters installed. If the pressure in the pipeline has increased or decreased, and the new pressure is acceptable, the limits can be changed and the system restarted. If this does not cure the problem, the transmitters and the wiring must be investigated. 7.10 LINE/AMBIENT TEMPERATURE EXCEEDS LIMIT ALARM: Line or Ambient Temperature Exceeds Limit Description: This alarm is set if the process line temperature exceeds the limit set in ALARMS. Influences the densities of the single phases at line conditions, minor effect on the fraction measurements and the flow rates. Possible reasons The well stream temperature is higher or lower than expected and this results in a temperature measurement that falls outside the pre-set alarm limits set in ALARMS. Faulty reading caused by transmitter failure, by temperature element failure, or faulty wiring. How to repair Investigate the actual value from the Temperature Transmitter and compare with the limits set in ALARMS. If the temperature in the well stream has increased or decreased, and the new temperature is acceptable, the limits can be changed and the system restarted. If this does not cure the problem, the transmitters and the wiring must be investigated. 7.11 DEFECT IN RA SOURCE ASSEMBLY Possible Reasons: N/A Sudden and unexpected variation in flow measurement or large variation in em tie. 1) A solid object has flowed into the venturi and got stuck. 2) A material has deposited on the Windows 3 The source assembl is dama ed. 1) Ensure the venturi is free from debris. 2) Ensure the windows are clean. 3 Periorm a 'wi e test' on the source. ALARM: Description: How to Repair: Maintenance & Troubleshooting Manual PhaseWatcher Vx 3..PHASE Measurements AS No: Rev.: Date: Page: 601 0-0140~D 00 07-MAY-2003 1 8 of 1 8 8. TORQUE TABLE -- Dimension Required Torque Location -----" US ~pec. Junction Box Y2" 93Nm M12 90Nm Detector Penetrator Housinq M16 197Nm Remote Seal Flanges Detector Housing Source Housinq 1" - 8UNC~2 190Nm Clamps 5" 1 14" - 8N-2 407Nm Clamps 8" NOTE: These torques applies for standard bolt/nut material selection according to Phase Watcher Vx Data Sheet. ~ ~ Vx Fluids ID Procedure / F í ::Tï::t- «// ~/ \ R¥ q 00 29 Jul 2005 Information JET p=T Rev.: Date: Issued for: Made by: Chec~ed: Approved: Title. Vx Fluids ID Procedure Document number. 601 0-0268-D Customer I Supplier document number. No. of pages. ~3-PHASE 15 Measurements AS ~3-PHASE No: 6010 - 0268-0 Rev.: 00 Vx Fluids ID Procedure Measurements AS Date: 29-Jul-2005 Page: 2 of 1 5 TABLE OF CONTENTS INTRODUCTION............................................................................................................................. 3 1 .1 PURPOSE................................................................................................................................... 3 1.2 SCOPE......................................................................................................................... .............. 3 1 .3 DEFINITIONS .............................................................................................................................. . 3 1 .4 REFERENCE DOCUMENTS............................................................ .................................................. 4 1 .5 REVISION HISTORY ...................................................................................................................... 4 2 RESPONSIBILITIES AND RESOURCES .......................................................................................... 5 2.1 RESPONSIBILITIES ...... ......... .......... ........ ....... ......... ............. ..... ........ ............. ........ ..... ............... ...5 2.2 RESOURCES REQUiRED................................................................................................................ 5 3 FLOW CHART.... ..... ................................................................................................. .......................6 4 PROCEDU RE .................... ....................................... ....................................................................... 7 4.1 CHECKING THE PVT DATA FILE.... ........... ....................................................................................... 7 4.2 ENTERING THE REQUIRED PVT DATA INTO THE. CNF FILE....... ....... ........ ........ .............. ..... ............ ...... 8 4.3 VERIFY. CNF FILE FUNCTIONALITY................................................................................................. 12 4.4 VERIFY PERFORMANCE OFVX FLUIDS 10 MODEL IN THE Vx SOFTWARE .............................................. 14 5 APPENDIX - POLYNOMIAL COEFFICIE NTS ..................................................................................15 ~ I I I I 3-PHASE I MeaS\RlT1ents AsI "-" .~ No: Rev.: Date: Page: 6010 - 0268-0 00 29-Jul-2005 30f15 Vx Fluids ID Procedure 1 INTRODUCTION 1.1 PURPOSE The first purpose of this document is to provide a flow chart that describes the Vx Fluids 10 decision and implementation process: Oetermining if Vx Fluids 10 should be used, how the PVT data is obtained and validated, and how the data is integrated into the Vx software and validated. The second purpose is to provide the procedure for validating PVT data that will be incorporated into Vx meter software and used as the Vx Fluids 10 PVT model. This procedure does not cover sampling plans, sample analysis, or generation of EOS. The starting input is the appropriate PVT data file. The third purpose of this document is to describe the procedure for incorporating Vx Fluids 10 PVT data into a .cnf file for a Vx meter. Included is how the incoming PVT data file is quality checked, how the necessary PT data is entered into the .cnf file for the Vx meter, and how the resulting .cnf file is validated for functionality and accuracy. Some troubleshooting procedures are included if the file does not function properly. 1.2 SCOPE This procedure applies to Vx Fluids 10 as used with both PhaseWatcher Vx and PhaseTester Vx with software version 2.45 or later. 1.3 DEFINITIONS .cnf Black Oil Model EOS Fluid property matix/table Gas Mode .MNbin .MTbin Oil Mode PL Polynomial coefficients PT PVT PVT data file The file extension for a Vx meter configuration file; maintains fluid property data, Vx meter hardware configuration & settings, Vx software to be used BOM; PVT model that is based on the fluid properties of "black oils". Model combines the results of several Black Oil PVT studies to provide a general model. Equation Of State A table that lists the values of a given fluid property across a range of temperatures and pressures or WLR; also called PT table Vx software mode that can be used when the flow is 90-100% GVF at line conditions; it provides very good accuracy for gas flow rate measurements Metering Nuclear binary file. A file produced by the Vx meter during a metering period that records the nuclear measurements Metering Transmitter binary file. A file produced by the Vx meter during a metering period that records the transmitter measurements Vx software mode that can be used when the flow is 0-98% GVF at line conditions; it provides very good accuracy for liquid flow rate measurements The absolute pressure in the flowline pipe at the Vx meter during the metering The coefficients of a polynomial function that computes the values of a particular fluid property; derived from a fluid property table; also referred to as fitting coefficients Pressure Temperature Pressure Volume Temperature .xls file created by a fluids PVT laboratory that contains data describing PVT behaviors of oil, water, and gas from a particular well or reservoir. The file contains fluid property tables that list the fluid property values at different temperatures and pressures or water No: 6010 - 0268-D ~3-PHASE Measurements AS Rev.: 00 Vx Fluids ID Procedure Date: 29-Jul-2005 Page: 4 of 1 5 SW TL Vx Fluids ID Vx meter WLR cuts. It also contains corresponding sets of coefficients for polynomials that can be used to calculate the fluid behaviors described in the PT tables. Further details are contained in the body of this document Software The temperature of the fluid mixture in the flowline pipe at the Vx meter during the metering The service offered by Framo Engineering or Schlumberger for using a tailored PVT model in the Vx meter calculations; the PVT model is based on fluid sample analysis and is typically valid for a particular wellstream or possibly a field. The term used in the Vx meter software that designates 11 sets of polynomial coefficients that are curve fits for 11 PVT fluid properties (in software version 2.45 the term is "Client PVr) The term to collectively refer to PhaseWatcher Vx and PhaseTester Vx multiphase flow meters 1.4 REFERENCE DOCUMENTS Water-Liquid Ratio PVT Express Validator's Procedure PhaseTester Service Computer user's manual 6010-0271-D Vx Fluids ID Process Overview and Input Requirements 1.5 REVISION HISTORY Revision ChanQe Description 00 Initial release ~ \~ ~ i No: 6010 - 0268-0 3-PHASE I Vx Fluids ID Procedure Rev.: 00 Measurements ~ Date: 29-Jul-2005 Page: 5 of 1 5 2 RESPONSIBiliTIES AND RESOURCES 2.1 RESPONSIBILITIES Executing this entire procedure will be a joint effort between the fluids PVT analysis laboratory and the Vx community. Hence, it is important to note the responsibilities. It should be noted that the Vx community will coordinate the effort to generate the Vx Fluids 10 service and the fluids PVT analysis laboratory will supplement it. Schlumbergers Oilphase-OBR fluids PVT laboratories are the preferred laboratories as they have extensive experience with sampling, analysis and generating Vx Fluids 10 data sets. Task Responsibility Owner of the Vx Fluids 10 service Vx operations and sales personnel Coordinate the effort to secure and provide the Vx operations and sales personnel Vx Fluids 10 service Representative fluid samples collection and Fluids PVT laboratory or appropriate 3rd party§ analysis Generation of fluid property tables & polynomial Fluids PVT laboratory or designee§ coefficients Validation of fluid property tables & polynomial Fluids PVT laboratory or designee§ coefficients Quality check of fluid property tables & Vx operations and sales personnel polynomial coefficients .cnf file generation Vx operations and sales personnel .cnf file functionality and performance validation Vx operations and sales personnel § Fluid sampling and/or analysis typically bears additional cost to the client In the flow chart of section 3, responsibilities are indicated by the color of the process box. Grey indicates local Vx personnel; white indicates PVT lab personnel; dual tone indicates both, as shown below: local Fluids PVT lab personnel 2.2 RESOURCES REQUIRED The following resources will be required to perform this procedure: 2.1. PVT data file containing fluid property tables and associated polynomial coefficients obtained from EOS (this .xls file should have been generated by a fluids PVT laboratory) Expected Pl and Tl for the Vx job Vx Service Computer software Vx Post Processor software 2.2. 2.3. 2.4. 2.5. 2.6. 2.7. Raw data files (.MTbin and .MNbin) from previous Vx meter job with similar conditions (Pl, Tl)* .cnf file from previous Vx meter joblinstallation that used Vx Fluids 10 and ran successfully** Calculator * If there is not a previous job at similar P & T, a previous job at a different P & T can be used. ** If this is the first Vx Fluids 10 job for the district, a few data files are in InTo uch tickets. Vx Fluids ID Procedure No: 6010 - 0268-0 Rev.: 00 Date: 29-Jul-2005 Page : 6 of 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 3 FLOW CHART This flow chart describes the steps required to determine if a Vx Fluids 10 PVT model is required for a PhaseWatcher Vx or PhaseTester Vx job, how the PT matrices and coefficients are created and how the corresponding .cnf file is generated and validated. " " " " " ¡ ~ !; ",'" " " .." .1 ",Ik ,," Ii! " '" .. Ii' " " - c· -- ~ IE" )þ jt' :;¡¡, .. <,:¡,,¡ ;.:¡ .%$ "" jií/f ". (bill · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . ~ 3-PHASE : ~easurementsAS Vx Fluids ID Procedure No: Rev.: Date: Page: 6010 - 0268-0 00 29-Jul-2005 7 of 15 4 PROCEDURE 4.1 CHECKING THE PVT DATA FILE (to be performed by the Fluids PVT laboratory or designee) This section is illustrated in the Section 3 Flow Chart as the last two steps of Phase 2. 4.1.1. Receive the PVT analysis document from the analysis laboratory for the fluids of the intended Vx meter job. 4.1.2. Verify that 11 fluid property tables are in the document with the correct units and arrangement, as described in Table 1 below: An example of one fluid property table is show in Table 2, below: 640.418 649.228 658.199 667.649 677.421 687.512 698.245 712.821 729.32 750.305 807.651 640.258 649.228 658.359 667.81 677.581 687.833 698.565 713.142 729.641 750.785 806.209 640.098 649.068 658.199 667.649 677.581 687.993 698.725 713.462 730.121 751.106 804.928 639.777 648.748 657.878 667.489 677.421 687.833 698.885 713.622 730.442 751.426 803.806 .137 648.107 657.398 667.169 677.26 687.833 698.885 713.783 730.602 751.746 802.845 38.336 647.466 656.757 666.528 676.78 687.512 698.725 713.783 730.762 751.906 802.044 37.375 646.505 655.956 665.727 676.139 686.872 698.405 713.783 730.922 752.067 801.564 X,p!636.093 645.224 654.835 664.766 675.178 686.231 697.924 713.462 730.922 752.227 801.243 .."634.491 643.782 653.393 663.485 674.057 685.27 697.123 713.142 730.762 752.227 800.923 .$0,» ~.. !..'. 631. 768 640.899 650.67 660.922 671.814 683.347 695.682 712.181 730.442 752.227 800.763 Table 2: example of a fluid property table for one fluid property 4.1.3. Verify that 11 sets of polynomial coefficients for polynomials that algebraically "describe" the values in each fluid property table are in the document. 4.1.4. Verify that the units and column & row arrangements of the coefficient sets are the same as listed in Table 1. An example of a coefficient set is given in Table 3, below. (these correspond to Table 2 data) Note: this table was created using PVTPro. This software uses notation "P^4.00" to denote p4, "T^2.00" to denote r, and so on. The polynomial coefficient is 1.28589E-30 for the p4 r term. -4.44185E-23 2.50361E-20 -3.84246E-18 5.34947E-16 -2.9981E-13 4.62202E-11 -2.82105E-09 1.60823E-06 -0.00026144 0.00318481 -1.82240427 1063.395142 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · No: 6010 - 0268-D ~3-PHASE ! Mea~ffiU AS Vx Fluids ID Procedure Rev.: 00 Date: 29-Jul-2005 Page: 8 of 15 . . Table 3: example of PT coefficients for a fluid property For a further explanation of polynomial coefficients, see 5. 4.1.5. Obtain the expected PL and TL for the pending Vx meter job from the Vx operations personnel. Contact them if the information has not been provided. 4.1.6. Verify that the fluid property tables include standard pressure and temperature in their ranges of P and 1. (Verify that the minimum P and T on the fluid property tables are no higher than standard P and T.) In table 2, the minimum pressure is 101325 Pa, which is atmospheric P and the minimum temperature is 280.37 K which is lower than standard temperature. 4.1.7. The expected PL and TL need to be within the pressure and temperature ranges of the fluid property tables. Compare the PL and TL to the P and T maximums of the fluid property tables. PL and TL need to be less than the P and T maximums in the tables, not on the limits or beyond. 4.1.8. If either requirements in 4.1.6 or 4.1.7 are not met, notify the PVT data provider and ask for new tables and polynomial coefficients that meet these requirements. 4.1.9. The accuracy of the coefficients needs to be validated. Calculate algebraically the oil density at the expected PL and TL by using the oil density coefficients and the PL & TL. See section 5 for further information. 4.1.10. Determine the value of the oil density in the fluid property table for this PL and TL (interpolation may be required if the exact PL is not a column and/or if the TL is not a row). 4.1.11_ Compare the calculated oil density and the fluid property table oil density. If they are >1 % apart, new coefficients are needed. 4.1.12. Repeat 4.1.9 - 4.1.11 for gas density, Z, bo, bw, and bg. 4.1.13. Repeat 4.1.9 - 4.1.11 for water density. If they are more than 0.5% apa rt, new water density coefficients are needed. 4.1.14. Repeat 4.1.9 - 4.1.11 for rgmp, Rst, Rwst and liquid viscosity. If they are more than 5% apart, new coefficients are needed. 4.1.15. Generate or request the generation of new coefficients for those that did not meet the accuracy requirements. This may require contacting the person or department that generated the coefficients and informing them of the accuracy needed at PL and TL for the coefficient sets identified. 4_1.16. Repeat 4.1.9 - 4.1.15 until all 11 sets of coefficients meet the accuracy requirements. 4.1.17. Deliver the complete set of accurate PT tables and polynomial coefficients to the Vx operations personnel in an .xls file. 4.2 ENTERING THE REQUIRED PVT DATA INTO THE .CNF FILE (to be performed by the Vx operations personnel) This section is illustrated in the Section 3 Flow Chart as the first two steps of Phase 3. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 4.2.1. 4.2.2. 4.2.3. 4.2.4. 4.2.5. 4.2.6. 4.2.7. 4.2.8. Vx Fluids ID Procedure No: Rev.: Date: Page: 6010 0268-0 00 29-Jul-2005 9 of 15 Receive the PVT data file in an .xls file from the fluids PVT laboratory or client that describes the fluids of the pending Vx meter job (referred to as the ".xls file" for the remainder ofthe document). This file contains fluid property tables and polynomial coefficients. Determine if the fluid property tables and coefficient sets in the file were validated following the procedure in section 4.1. If not, perform this validation. This is most likely the case if the fluid property file was not created by Oilphase-DBR. If section 4.1 validation is performed now, steps Verify that the 11 fluid property tables listed in Table 1 above are in the .xls file. An example table is given in table 2. Verify that 11 sets of polynomial coefficients that algebraically "describe" the 11 fluid property tables are in the .xls file (see table 3 above for an example table). The fluid property p:)lynomial coefficients now need to be entered into the .cnf file for the job. Open the Vx Service Computer software application on a computer. If the .cnf file for the job has already been created it, open it. If it has not, create a new file following the standard procedure, filling in as much information as is known. On the PVT sheet in the Service Computer, select "Vx Fluids 10" from the PVT model drop down menu at the top center of the sheet (in Service Computer version 2.45 the term is "Client PVT"). Click on the "Vx Fluids 10" button (or "PVT Client" in version 2.45) directly below the drop down menu. This will open up a new window in which the coefficients and their exponents can be entered. Most of the window is a block of cells (one row of 9 cells and nine rows of 10 cells) into which the coefficients and corresponding exponents can be entered. In the top left corner of this new window is a drop down pick list that should currently display "Oil density". The drop down lists the eleven fluid properties and the validity ranges for the coefficients (12 options). An example of the window is below: 4.2.9. 4.2.10. 4.2.11. 4.2.12. Depending on the history of the .cnf file, some or all of the fluid properties may have coefficients and exponents currently in the cells,. Before entering the new fluid property coefficients, any old numbers need to be removed from the cells. For each of the 12 choices on the drop down list replace all non-zero values in the cells with "0". Verify that all cells in each of the 12 options on the drop down menu are"O". Select "Oil density" from the drop down menu. The oil density polynomial coefficients and exponents will be entered into these cells. The top row of the cells is intended to contain the exponents for the pressure (P) variable. In the first cell from the left, enter the numerical value of the first pressure exponent from the oil density coefficient set in the PVT data file. If the data in Table 3 was being entered, the number "4" would be typed in the top row cell, first from the left. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 3-PHASE Vx Fluids ID Procedure No: Rev.: Date: Page: 6010 0268-0 00 29-Jul-2005 10 of 15 4.2.13. In the second-from-Ieft cell of the top row, enter the second numerical pressure exponent of the coefficient set If the data in Table 3 was being entered, "3" would be typed in the top row second cell from the left and the screen would now look like this: 4.2.14. Continue entering the remaining pressure exponents in the same way. 4.2.15. The first column on the left side is intended to contain the exponents of the temperature (T) coefficients. In the top-most cell, enter the numerical value of the temperature exponent from the oil density coefficient set If the data in Table 3 was being entered, "2" would be typed in the left column top cell. 4.2.16. Into the cells directly below, enter each remaining temperature coefficient of the PT coefficient set If Table 3 was being entered, the screen would now look like this: 4.2.17. Now each coefficient needs to be entered into the correct cell. To reduce the risk of errors, copy and paste each oil density coefficient from the PT coefficient set into the corresponding cell of the oil density sheet If Table 3 was being entered, it would now look like this: · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Vx Fluids ID Procedure No: Rev.: Date: Page. 6010 - 0268-0 00 29-Jul-2005 11 of 15 4.2.18. Repeat steps 4.2.11 through 4.2.17 for each of the remaining 10 sets of coefficients. Note that for the liquid viscosity coefficients, the top row of cells contains the exponents for WLR, not P. The next step is to determine the validity ranges of the fluid property coefficients. From the fluid property tables, identify the minimum and maximum pressures and temperatures used on the tables. In table 2, the validity range for pressure is 101325 Pa - 15269738 Pa and the validity range for temperature is 280.37 K - 333.15 K. Select the twelfth option "Validity range and reference densities" from the drop down menu. 4.2.19. 4.2.20. 4.2.21. For pressure, temperature, and WLR, enter the minimum ("low") and maximum ("high") values for which the coefficients are valid (the validity ranges). As described in Table 1, the WLR minimum should be 0 (O%)and the WLR maximum should be 1 (100%). If the liquid viscosity data is only valid for a narrower range of WLR, enter the valid range. In the same screen, enter the reference densities for oil and water at standard conditions. These values can be determined from the oil density and water density fluid property tables by finding or calculating the densities that correspond to standard temperature and pressure. (Interpolation may be required) Calculate the gas specific gravity using the gas density fluid property table. 4.2.23.1. In the gas density fluid property table, determine the gas density at 288K and 101325 Pa. Interpolation may be needed. 4.2.23.2. Divide the gas density by 1.223 kg/m3 (the density of air at 288K and 101325 Pa). The result is the gas specific gravity. Enter the gas specific gravity into the appropriate cell on the right side. 4.2.22. 4.2.23. 4.2.24. . . · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ ! No: 6010 - 0268-0 3-PHASE Rev.: 00 Measurements J Vx Fluids ID Procedure Date: 29-Jul-2005 Page: 12 of 15 4.2.25. Verify that all coefficients and exponents of the 11 fluid properties and the validity ranges and densities have been entered correctly. 4.2.26. Click the "OK" button to close the Vx Fluids 10 window. 4.2.27. "Save as" the .cnf file. 4.3 VERIFY .CNF FILE FUNCTIONALITY (to be performed by the Vx operations personnel) This section is í/Iustrated in the Section 3 Flow Chart as the third and fourth steps of Phase 3. 4.3.1. 4.3.2. 4.3.3. 4.3.4. 4.3.5. 4.3.6. 4.3.7. 4.3.8. 4.3.9. 4.3.10. 4.3.11. 4.3.12. 4.3.13. 4.3.14. 4.3.15. 4.3.16. 4.3.17. After all other necessary information has been entered into the .cnf file (venturi size, detector heater setting,...), it needs to be verified that the file runs in the Vx software. This is not an exhaustive troubleshooting guide but provides some guidance. Any information that can be added to this document will be welcomed. Please submit to InTouch or 3-Phase as a best practice. To post process the .cnf file being validated, the file needs an empty pipe reference. Either post process the .cnf file with an old empty pipe file or carefully copy and paste the empty pipe reference from the cnf file from previous Vx meter job/installation into the file being validated. Open the Vx Post Processor software. Choose to open a flow period. Select the .cnf file that is to be validated. Select the .MNbin nuclear file (with corresponding .MTbin file) from the previous Vx job/installation that had similar PL and TL. Click the "!" button to post process the flow period. If the post processing cannot start and the following error message is received "Numerical error in interpretation model! Continue?", select "Cancel". Using the Service Computer, open the .cnf file being validated. On the PVT sheet, change the PVT model to "Black oil". "Save as" the file. Return to the Post Processor. Try to post process this new .cnf file by repeating 4.3.4 through 4.3.7. If this file post processes, there is an issue with at least one set of PVT coefficients. If the file does not post process and the same error is received, it is not due to the Vx Fluids 10 coefficients. Troubleshooting will need to be performed on the .cnf file that is beyond the scope of this procedure. If the file post-processes using the Black Oil model but not with the Vx Fluids 10 model, the following points can be checked: Verify that all exponents, coefficients, and validity ranges are entered in the Vx Fluids 10 sheets correctly. Verify that the dynamic OP in the .Mtbin file is > 5 mbar. Verify on the Reference sheet that an empty pipe reference exists. Verify on the Reference sheet that mass attenuations exist for the three fluids. For basic fluids without heavy components such as sulfur or salts, the low energy mass attenuations are typically -0.024 m2/kg (hydrocarbons) to -0.035 m2/kg (water), high energy mass attenuations are typically -0.017 to -0.020 m2/kg, and the 356 mass attenuations are typically around -0.011 m2/kg. No: 6010 - 0268-D ~ 3-PHASEJ Rev.: 00 Measurements ¡ Vx fluids ID Procedure Date: 29-Jul-2005 Page: 13 of 15 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . 4.3.18. Check the calculated low and high energy linear attenuations of the three fluids on the Triangle sheet. Compare these with the expected values calculated from the fluid densities at PL & TL (obtained from the fluid property tables) and the mass attenuations (shown on the Reference sheet). The linear attenuation is the product of the mass attenuation and the density at PL & TL. 4.3.19. 4.3.20. 4.3.21. 4.3.22. 4.3.23. 4.3.24. 4.3.25. 4.3.26. 4.3.27. 4.3.28. 4.3.29. 4.3.30. 4.3.31. 4.3.32. Example: A generic dead oil with no sulfur can have a low energy mass attenuation of -0.0246621 m2/kg. If the oil density at PL & TL is 770 kg/m3, the low energy linear attenuation would be (-0.0246621 m2/kg). (770 kg/m3) = -18.99 m-1 As a first-order rule of thumb, the low and high energy linear attenuations of fluids without heavy components such as sulúr or salts should be in the following ranges: gas (O/m to -31m), oil (- 5/m to -251m), water (-151m - 40/m). The high energy linear attenuation is often approximately half the value of the low energy linear attenuation. Particular fluid properties and operating conditions may result in linear attenuations outside these ranges so these should not be considered always correct. If the mass attenuations of a fluid were acceptable but the linear attenuations for the fluid on the Triangle sheet are incorrect, the density coefficients for that fluid are incorrect and need to be corrected or replaced. If the above points have been checked and the .cnf file still does not post process, more in-depth troubleshooting needs to be done. Replace all sets of polynomial coefficients for the pending job (to be referred to as "A" coefficients) with the polynomial coefficients from the .cnf file in 2.6 that are known to run successfully (referred to as "8" coefficients) using the Vx Service Computer or very careful copy-paste from the old file to the new. "Save as" the .cnf file. Post process this file and verify that it runs. If it does not, it is not due to the Vx Fluids ID coefficients and troubleshooting will need to be performed that is beyond the scope of this procedure. If it runs successfully, replace viscosity coefficients "8" with viscosity coefficients "A" and "Save as". Attempt to post process this file. If it does not run successfully, note that this coefficient set did not run and revert to the last successful version of the .cnf file (that has viscosity coefficients "A"). If the .cnf file runs successfully, replace oil density coefficients "8" with oil density coefficients "A" and "Save as". Attempt to post process this file. If it does not run successfully, revert to the last successful version of the .cnf file. If it runs successfully, repeat 4.3.27 through 4.3.29 until the 11 sets of coefficients in the Vx Fluids ID are a combination of all "A" coefficients that will run and "8" coefficients for those that will not. Notify the PVT data file provider of all the "A" coefficient sets that need to be regenerated because the original sets would not run in the Vx software (they may need to generate coefficients for lower order polynomials). When replacement coefficients have been provided, repeat the replacement-validation process above until a functional .cnf file is obtained. 4.3.33. "Save as". . ~~J . · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Vx Fluids ID Procedure No: Rev.: Date: Page: 6010 - 0268-0 00 29-Jul-2005 14 of 15 4.4 VERIFY PERFORMANCE OF VX FLUIDS ID MODEL IN THE VX SOFTWARE (to be performed by Vx operations personnel) This section is illustrated in the Section 3 Flow Chart as the last two steps of Phase 3. 4.4.1. 4.4.2. 4.4.3. 4.4.4. 4.4.5. 4.4.6. 4.4.7. 4.4.8. 4.4.9. 4.4.10. The next step is to validate the performance of the coefficients in the Vx meter software. Post process the functional .cnf file from 4.3.33 with raw data files (nuclear and transmitter metering files) that are close to the expected operating conditions of this job. If the .cnf file post processes but the value of every flow rate on the results page is "-1.#IND", It could be due to the viscosity coefficients. If you have another set of viscosity coefficients, replace them, post process and determine if the error persists. If it does not, the viscosity coefficients for the pending Vx meter job/installation need to be replaced. On the Results sheet, note the PL, TL and the oil density. Look up the value of the oil density for this PL æd TL in the oil density fluid property table in the .xls file (interpolation may be required if the exact PL is not a column and/or if the TL is not a row). Compare the Post Processor oil density and the fluid property table oil density. If they are >1% apart, validate that the coefficients were entered correctly. If they were not, correct them and repeat. If they were, new coefficients are needed. Repeat 4.4.3 - 4.4.5 for gas density, Z, bo, bw, and bg (the latter four are listed on the Service Computer PVT sheet). Repeat 4.4.3 - 4.4.5 for water density. If they are more than 0.5% apart, new coefficients are needed. Repeat 4.4.3 - 4.4.5 for rgmp, Rst, Rwst (on the PVT sheet) and liquid viscosity. If they are more than 5% apart, new coefficients are needed. Notify the PVT data file provider of the coefficients that need to be regenerated to improve their accuracy. When replacement coefficients have been provided, repeat the steps above for entering them with the Service Computer and validating their performance and accuracy until a functional .cnf file is obtained. 4.4.11. "Save as". 4.4.12. Load the .cnf file onto the Vx meter. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · Vx Fluids ID Procedure No: 6010 - 0268-0 Rev.: 00 Date: 29-Jul-2005 Page: 15 of 15 5 APPENDIX - POLYNOMIAL COEFFICIE NTS Fluid properties are different at different conditions (P, T, WLR). The values of a fluid property can be displayed as a three-dimensional surface, as illustrated below for a heavy oil: When the oil density at different pressures and temperatures is needed, it can be calculated using a function that describes the oil density behavior. For pressure in units of Pa and temperature in K, the function below will produce the oil density graphed above in units of kg/m3: Oil Density (P,T) [kg/m3] = 7.16x109p-1T1 - 3 x104T1 2.01x10-3PT1 -4.82x107p-1 + 1.23x103 + 6.69x10-6p + 8.22x1 04p-1T - 6.56x1Q-1 T - 1.57x1 0-8pT To determine the oil density at some P & T, the numerical \Blues for P [Pa] and T [K] are put into the above function and the oil density is computed. The calculated oil density at 101325 Pa and 288 K is 940.4 kg/m3 It is very important to ensure that the P & T are in the correct units otherwise the resulting œnsity will be wrong. Instead of writing this function out in its long form, it can also be written as a table: -6.56E -0 1 It is these small tables of coefficients and exponents that are entered into the Vx software so that the oil density and other fluid properties can be calculated for any P & T within the validity range of the coefficients (the ranges of pressure and temperature over which the curve fit applies; see section 4.2.19 for more information.) If the table of coefficients is available and the fluid property at a particular P and T is desired, the value can be calculated by working in the reverse order: the long form of the function can be written from the coefficients table, the numerical values of the P and T inserted, and the fluid property computed. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . Vx Fluids ID Process Overview and Input Requirements #0 iI' t ~~ '~--:> a. I. 00 1-Aug-2005 Information JET RR --- ~ Rev.: Date: Issued for: Made by: Checked: Approted: Title. Vx Fluids ID Process Overview and Input Requirements Document number. 6010-0271-D Customer I Supplier document number. No. of pages. ~ ]-PHASE 22 Measurements AS . . · · · · · · · · · · · · · '. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 2 of 22 IN DEX 1 INTRODUCTION ...... ................ .......... ........... .......... ..................... .......... ....... ...... 3 1.1 Purpose...... ............... .......... .......... ......... ..... .......... ....... ........ .....................3 1.2 Scope .......... ....... .......... .......... .......... ............... .......... ............... ...................3 1.3 Definitions.. ........ ...... ............. ......... .............. .......... .............. ....... ....... ..... ...3 1.4 Reference Documents ........ ................... .............. ............................. .........4 1.5 Revision History ........... ............ ........ ......... .............. .............. ........... .........4 2 GENERAL INFORMATION ................................................................................. 5 2.1 PVT Models ......... ..... .......... ......... .......... ...... ........ .............. .......... ............... 5 2.2 Vx Fluids ID Process Flow Chart.............................................................. 7 2.3 Vx Fluids ID data input requirements ......................................................8 3 FLUID PROPERTIES .......... ........ .................... ..... ......... ............................... .....11 3.1 Oil Properties ...........................................................................................11 3.1.1 Oil Density .....................................................................................11 3.1.2 Oil Volume Factor (bo) .................................................................12 3.1.3 Gas Phase Condensate Gas ratio (r gmp)......................................13 3.2 Gas Properties ....... .......... .......... .......... ....... ........ .............. ......... .............. 14 3.2.1 Gas Density........ ............. ........ ............... ....... ........ ....... ........ ...... ...14 3.2.2 Gas deviation factor .....................................................................15 3.2.3 Gas Expansion factor (bg) ...........................................................16 3.2.4 Stock Tank Gas Oil Ratio (Rst) ....................................................17 3.3 Water Properties......... ....... ............. .......... ....... ........ ............... ........ ..... ....18 3.3.1 Water Density ................................................................................18 3.3.2 Stock Tank Gas-Water Ratio: Rwst .............................................19 3.3.3 Water Volume Factor (bw).... ............. .......... ............. .................. ..20 3.4 Viscosity of the liquid at line conditions ...............................................21 4 POLYNOMIAL COEFFICIENTS... ......... .......... ..... ......... .............. ............ .......... 22 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 3 of 22 INTRODUCTION 1.1 Purpose This document is intended to provide an overview of PVT models, summarize how various fluid properties are used in PhaseWatcher Vx and PhaseTester Vx calculations and to describe the options available in the Vx software for PVT models. This document also provides a flow chart of the general process by which Vx Fluids ID is implemented on a PhaseWatcher Vx or PhaseTester Vx meter and provides the requirements and specifications of the required input data. 1.2 Scope This document applies to PhaseWatcher Vx and PhaseTester Vx. 1.3 Definitions .cnf Black Oil Model Fluid property matix/table Gas Mode Line conditions Oil Mode PL Polynomial coefficients PT PVT PVT data file TL The file extension for a Vx meter configuration file; maintains fluid property data, Vx meter hardware configuration & settings, Vx software settings to be used BOM; PVT model that is based on the fluid properties of "black oils". Model combines the results of several Black Oil PVT studies to provide a general model. A table that lists the values of a given fluid property across a range of temperatures and pressures or WLR; also called PT table Vx software mode that can be used when the flow is 90-100% GVF at line conditions; primary objective is to provide very accurate gas flow rate measurements The pressure (PL) and temperature (TL) of the pipeline at the Vx meter. Vx software mode that can be used when the flow is 0-98% GVF at line conditions; primary objective is to provide very accurate liquid flow rate measurements The absolute pressure in the flowline pipe at the Vx meter during metering The coefficients of a polynomial function that computes the values of a particular fluid property; derived from a fluid property table; also referred to as fitting coefficients Pressure Temperature Pressure Volume Temperature .xls file created by a fluids PVT laboratory that contains data describing PVT behaviours of oil, water, and gas from a particular well or reservoir. The file contains fluid property tables that list the fluid property values at different temperatures and pressures or water cuts. It also contains corresponding sets of coefficients for polynomials that can be used to calculate the fluid behaviours described in the PT tables. Further details are contained in the body of this document The temperature of the fluid mixture in the pipe at the Vx meter during metering . . · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ 3-PHASE No: 6010-o271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 4 of 22 Vx Fluids 10 The service offered by Framo Engineering or Schlumberger for using a tailored PVT model in the Vx meter calculations; the PVT model is based on fluid sample analysis and is typically valid for a particular well or possibly reservoir. The term used in the Vx meter software that designates 11 sets of polynomial coefficients that are curve fits for 11 PVT fluid properties (in software version 2.45 the term is "Client PVT") Vx meter The term to collectively refer to PhaseWatcher Vx and PhaseTester Vx multiphase flow meters WLR Water-Liquid Ratio 1.4 Reference Documents Terminology and Definitions for Multiphase Acquisition Products and Environmental Corrections. EP493597 1.5 Revision History Revision Change DescriDtion 00 Initial release · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · No: Vx Fluids ID Process Overview and Rev.: Input Requirements Date: Page: 6010-0271-D 00 1-Aug-05 5 of 22 3-PHASE Measurements AS 2 GENERAL INFORMATION 2.1 PVT Models Multiphase flow meters are high pressure-high temperature tools that usually operate at pressures well above that of a separator. This is one of their main advantages. The figure below illustrates this: Well Head Multiphase flow meter Separator PWh, Pbhf, ReselVoi wh: well head mp: multiphase sp: separator st: stock tank bhf: bottom hole flowing Figure 1: Schematic of a typical multiphase meter set-up Measured fluid flow rates at one P & T will be different from the measured flow rates at standard P & T. The reasons for this include the compressibility of gas and the fact that gas dissolves in oil and water when pressurized. Flow measurements made at line conditions P & T need to be transformed into equivalent flow rates at standard conditions. This transformation or conversion requires knowledge of various fluid properties. A schematic diagram of how line condition measurements are re-calculated to standard condition flow rates is given below: [Note: The oil industry uses some of the parameters that are described below; to avoid any misinterpretation or miscommunication, conventions are based on the SPE notation for Multiphase Flow Meters (see reference)] qwL qosc · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ]..PHASE Measurements AS Vx Fluids ID Process Overview and Input Requirements No: Rev.: Date: Page: 6010-0271-D 00 1-Aug-05 6 of 22 qgoSC qogsc qwgS R_t qwsc Figure 2: Multiphase Metering Fluid Flow Path On the left are the multiphase flow meter measurements at line conditions. These values are converted to flow rates at standard conditions by taking into account the gas dissolved in various phases. qgLC is the gas volumetric flow rate at line (meter) conditions. This gas is split into two parts at standard conditions: qggsc (gas flow rate) and a qgosc ( oil flow rate) due to the lower pressure. %LC, which is the oil flow rate at line conditions. It is split into two parts: qoosc dead oil at standard conditions and qogsc, which is the gas that is released from the oil when it is brought to standard conditions. qwLC will follow the same path as the oil with qwwsc and qwgsc' It is the sum of the different relevant parts that produces the total volumetric flow rate of gas, oil and water at standard conditions, represented on the right side of the above diagram. To achieve these transformations, the following information is required: Formation volume factors: bo, bw, bg; Densities of oil, water and gas at line and standard conditions Gas phase condensate gas ratio: rgmp Stock tank gas oil ratio: Rst Stock tank gas water ratio Rwst Gas deviation factor (gas compressibility factor), Z. Fluid properties such as density are not constant; they change with pressure and temperature. A PVT model is typically used to provide the necessary fluid property information for all of these calculations. In general, a PVT model is created by taking fluid samples (downhole or at surface); analyzing the fluids in various tests; creating an Equation of State; and generating tables, curves, · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 7 of 22 and/or polynomial coefficients to describe or predict the value of each fluid property at different pressures and temperatures. A fluids PVT laboratory usually performs such work. Because the line conditions in the meter (PL & TL) and the conditions in the separator are typically very different, the standard PVT model developed for the separator may not be suitable for use with the multiphase flow meter. To produce accurate flow measurements, the PVT model must be valid and accurate across the range of line conditions at the meter. It is important to state that the metrological performance of the Vx meter is a direct function of the accuracy of the required input parameters, including the PVT model. One class of PVT models commonly found in the petroleum industry is Black Oil Models (BOM). These models have been developed for decades using the process described above with fluid samples from various "Black Oils". A BOM has been included in the Vx software. Using the BOM as the PVT model for the Vx calculations eliminates the costs associated with fluid sampling and analysis, but the meter's measurement accuracy will be reduced if it is not a suitable model for a given well's fluids. This is particularly true if the produced oil is not a black oil (ex: a condensate, volatile or heavy oil). To provide an alternative and the best possible accuracy, the capability of using a customized PVT model in the Vx software has been developed. Vx Fluids ID allows a PVT model developed for a specific well's fluids to be used in the calculations of that well's flow rates. A Vx meter can be loaded with the PVT models of different wells so that when a particular well is metered, it's unique PVT model is used in the calculations, ensuring the most accurate results. To implement Vx Fluids ID, two sets of data are needed: Fluid property tables and the corresponding sets of polynomial coefficients. A fluid property table is a table that lists the values of a given fluid property (density, bo, liquid viscosity,...) at different temperatures and pressures or WLR. A set of polynomial coefficients is the coefficients of a polynomial equation that algebraically calculates the values in a fluid property table (also referred to as fitting coefficients). To obtain the fluid property tables and corresponding polynomial coefficient sets, the fluids analysis process described above is followed and the fluid property tables and coefficients generated are given to the Vx operations personnel. The polynomial coefficients are then incorporated into the Vx software as the Vx Fluids ID PVT model. The fluid property tables are used to validate the accuracy of the coefficients. It may be possible to use an existing PVT report to generate the necessary fluid property tables and coefficient sets. It may also be possible for the laboratory to analyze existing samples, which are in storage to generate the tables and coefficients. The age of the data or samples, the current reservoir conditions, and the reservoir conditions at which the samples were taken will determine if either of these options can be used or if new samples need to be taken. Oilphase-DBR has extensive experience developing PVT models for Vx Fluids ID and can advise as to the suitability of using existing PVT data and/or samples to generate the required tables and coefficients. It is essential to keep in mind that the Vx meter has no knowledge of what processes are located downstream of its measuring section. The effective shrinkage for example, may differ significantly depending of the number of stages of separation and their respective pressures. It is the client's responsibility to ensure that the PVT model tables and coefficients correctly represent the volumetric factors used for the conversion from line conditions to standard conditions. Creating the PVT model from appropriate analysis of appropriate samples ensures this. 2.2 Vx Fluids ID Process Flow Chart 3...PHASE easurernents AS Vx Fluids ID Process Overview and Input Requirements No: Rev.: Date: Page: 6010-0271-0 00 1-Aug-05 8 of 22 · · · · · · · · · · · · · · · · · · · · · · · · · · · This flow chart summarizes the main steps involved in determining if a Vx Fluids 10 PVT model is required for a PhaseWatcher Vx or PhaseTester Vx job, how the fluid property tables and coefficients are obtained, and how the corresponding configuration file that is used in the Vx software (.cnf file) is created and validated. · · · · · · · · · · · · · · · · 2.3 Vx Fluids ID data input requirements There are a total of 11 pairs of fluid property tables and polynomial coefficient sets needed to correctly configure the Vx software and validate its performance. The coefficients are incorporated in the Vx software for use in the various calculations and conversions. The fluid property tables are · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . ~3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 ~easurernents~ Page: 9 of 22 used to verify the accuracy of the coefficient sets. It is of the utmost importance that the tables and coefficients are in the correct arrangement for columns and rows and use the correct units. The following table describes the 11 fluid properties needed, the necessary arrangement, and the correct units: Below is an example of a fluid property table. Each column provides the oil density at one pressure and different temperatures: 640.418 649.228 658199 667.649 677.421 687512 698.245 712.821 729.32 750.305 807.651 640.258 649.228 658.359 667.81 677.581 687833 698565 713.142 729.641 750.785 806.209 640.098 649068 658199 667.649 677.581 687.993 698.725 713462 730.121 751.106 804.928 639.777 648.748 657.878 667.489 677.421 687.833 698.885 713.622 730.442 751 426 803.806 639.137 648.107 657.398 667.169 677.26 687.833 698.885 713.783 730.602 751.746 802.845 638.336 647.466 656.757 666.528 67678 687.512 698725 713.783 730.762 751.906 802.044 637.375 646.505 655956 665.727 676139 686.872 698.405 713.783 730.922 752.067 801564 636.093 645.224 654.835 664.766 675.178 686.231 697924 713462 730.922 752227 801.243 634.491 643.782 653.393 663.485 674.057 685.27 697.123 713.142 730.762 752.227 800.923 631.768 640.899 650.67 660.922 671.814 683.347 695682 712181 730.442 752227 800.763 Below is an example of a corresponding polynomial coefficient set. Note: This table was created by a software that uses notation "P^4.00" to denote p4, "T^2.00" to denote T2, and so on. For this polynomial, 1.28589E-30 is the coefficient of the P4T2 term. For further explanation, please see section 4. 1 .28589E-30 -7.30517E-28 1.12221 E-25 2.50361 E-20 -3.84246E-18 -2.9981 E-13 4.62202E-11 1.60823E-06 -0.00026144 -1.82240427 1063.395142 It is extremely important that the PVT simulations are performed not only close to expected line temperatures and pressures, but also at standard temperature and pressure. The fluid property table and corresponding polynomial coefficients above are valid from 280.37 K - 333.15 K and 101325 Pa - 15269738 Pa. The coefficient set for each fluid property table should be fitted to the relevant fluid property table. The accuracy of the coefficients at the expected line conditions should be the primary objective. All fluid property tables and coefficients should be presented in one or two .xls files that include the operator's name, well 10 and the expected line conditions. The following pages provide more detailed information about the required fluid property tables. Some general comments: . . · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 1 0 of 22 . The tables are defined with a Lower Limit and Upper Limit in terms of pressure and temperature, identified as PLL, PUL, TLL and TUL. The lower limit values for pressure and temperature should be no higher than standard conditions. The upper limit values should be higher than the expected line conditions and allowing for some variation. The range from the lower limits to the upper limits will be the validity range of the PVT model. If for any reason the operational conditions are outside the domain, the software will not extrapolate the PVT behaviour, but will use the closest valid values. P.Ref and T.Ref refer to the standard conditions or the reference conditions used to calculate the final flow rate. Usually Standard conditions refer to 14.7 psia and 60 Deg F or respectively 101353 Paa and 288.7 K. For the fluid property tables and coefficient sets, it does not matter if the columns and rows increase or decrease from left to right or top to bottom. Below are conversion factors between field units and International Unit (SI): . . . Pressure: 14.5038 psi = 100000 Pa = 1 bar Temperature: 100 DegF = (-32 + 100) *5/9 DegC = 273.15 + (-32 + 100) *5/9 K · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · (e · · · · · · · · · · · · . . ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 11 of 22 3 FLUID PROPERTIES 3.1 Oil Properties 3.1.1 Oil Density The Vx meter uses the oil density to calculate the flow rates of oil, water and gas at both line conditions and at standard conditions. The necessary information is represented here below; RHO OIL PLL P1 TLL Rhooil(PLL, TLL) Rhooil(P1, TLL) T1 Rhooil(PLL,T1 ) Rhooil(P1 ,T1) P. Ref Pj PUL Rhooil(Pj,TLL) Rhooil(PUL,TLL) Rhooil(Pj, T1) Rhooil(PUL,T1 ) Rhooil(Pref,TLL) Rhooil(Pref,T1 ) Rhooil(Pref, Tref) Rhooil(Pj,Tref) Rhooil(PUL,Tref) Rhooil(PLL, Tref) Rhooil(P1, Tref) I Ti I Rhooil(PLL,Ti) I Rhooil(P1,Ti) [U Rhooil(Pref,Ti) Rhooil(Pj,Ti) Rhooil(PUL,Ti) I TUL I RhOOil(PLL,TUL) Rhooil(P1 ,TUL) [ Rhooil(Pref,TUL) Rhooil(Pj,TUL) Rhooil(PUL,TUL) Where: 1) P. Ref is the standard pressure in Paa 2) T. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature Rhooil is the density of the oil at line conditions expressed in kg/m3. It should be given with 4 significant digits (example: 893.6 kg/m3) There is no need to have equally spaced pressure or temperature but the table must be completely filled. . . ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 12 of 22 It should be noticed that the minimum date set required is: Density at line conditions (Line Temperature and Pressure) and density at standard conditions. Obviously this is not desirable but it is the minimum. 3.1.2 Oil Volume Factor (bo) The oil volume factor is used to perform the computation of the flow rate at standard conditions from the flow rate at line conditions: bo (Pline, Tline) is the oil volume factor. Note that this also called shrinkage factor: bo(Pline,Tline) = SHR(Pline,Tline) Note that bo is a function of the process conditions downstream of the meter, and can vary significantly for light oil, condensate and gas effluent, depending on the number of separation stages and conditions (pressure / temperature). The required information is represented below: bo PLL P1 TLL bo(PLL,TLL) bo(P1,TLL) T1 bo(PLL, T1 ) bo(P1 ,T1) Pj PUL bo(Pj,TLL) bo(PUL,TLL) bo(Pj,T1) bo(PUL,T1) P. Ref bo(Pref,TLL) bo(Pref,T1 ) I T. Ref I bo(PLL,Tref) I bo(P1,Tref) [I bo(Pref,Tref) [] bo(Pj,Tref) bO(PUL,Tref) I Ti I bo(PLL,Ti) I bo(P1,Ti) [I bo(Pref,Ti) [] bo(Pj,Ti) I bo(PUL,Ti) TUL I bo(PLL,TUL) I bo(P1,TUL) [}O(pref,TUL) [] bo(Pj,TUL) bO(PUL,TUL) Where: 1) P. Ref is the standard pressure in Paa 2) 1. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature bo is the oil volume factor in Sm3/m3. It should be given with 3 significant digits (example: 0.893). · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · .¡ · · · · .: · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . ~3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 13 of 22 Note that the bo table is similar to the traditional 80 factor used for reservoir analysis work, but should cover also the range of lower pressure and temperatures encountered in the meter at surface conditions. 3.1.3 Gas Phase Condensate Gas ratio (rgmp) The necessary information is represented below rgmp PLL P1 TLL rgmp(PLL, TLL) rgmp(P1,TLL) T1 rgmp(PLL, T1) rgmp(P1 ,T1) P. Ref Pj PUL rgmp(Pj,TLL) rgmp(PUL,TLL) rgmp(Pj, T1) rgmp(PUL, T1) rgmp(Pref, TLL) rgmp(Pref,T1 ) I T. Ref [ rgmp(PLL,Tref) I rgmp(P1,Tref) [. rgmp(Pref,Tref) rgmp(Pj, Tref) rgmp(PUL,Tref) I Ti I rgmp(PLL,Ti) I rgmp(P1,Ti) [I rgmp(Pref,Ti) [] rgmp(Pj,Ti) I rgmp(PUL,Ti) I I TUL I rgmp(PLL,TUL) I rgmp(P1,TUL) [)rgmp(pref,TUL) [] rgmp(Pj,TUL) rgmp(PUL,TUL) I Where: 1) P. Ref is the standard pressure in Paa 2) T. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature rgmp (liquid condensing from the free gas at line conditions) should be given with 3 significant digits (example: 0.000123) and expressed in m3/m3. Rho gas PLL P1 TLL Rhogas(PLL,TLL) Rhogas(P1,TLL) T1 Rhogas(PLL, T1) Rhogas(P1 ,T1) P. Ref Pj PUL Rhogas(Pj, TLL) Rhogas(PUL,TLL) Rhogas(Pj,T1 ) Rhogas(PUL, T1) · · · · · · · · · · ¡e · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 14 of 22 3.2 Gas Properties 3.2.1 Gas Density The necessary information is represented below. Rhogas(Pref,TLL) Rhogas(Pref,T1 ) Rhogas(PLL,Tref) Rhogas(P1,Tref) J Rhogas(Pref,Tref) [ Rhogas(Pj,Tref) Rhogas(PUL,Tref) I Ti I Rhogas(PLL,Ti) [ Rhogas(P1,Ti) [] Rhogas(Pref,Ti) [I Rhogas(Pj,Ti) I Rhogas(PUL,Ti) I TUL Where: . . I Rhogas(PLL,TUL) I RhOgaS(P1,TUL)[)RhogaS(pref,TUL) [ Rhogas(Pj,TUL) Rhogas(PUL,TUL) 1) P. Ref is the standard pressure in Paa 2) T. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature The Gas Density should be reported with 3 significant digits (example: 10.8). Even if a relationship exists between the deviation (Z) factor and the gas density (see below), the compressibility factor table is required for quality control. Rho G = p * M/(Z * R * T) Where: Rho G is the density of the gas at line conditions (kg/m3) p is the pressure in Pa M is the molecular weight of the gas in g/mole · · · · .' · · · · · · · · · · · · · · · · · · · · · · · .' · · · · · .' · · · · · · · · · . . ~3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 15 of 22 Z is the deviation-factor (dimensionless) T is the absolute temperature (K) R is the universal gas constant 3.2.2 Gas deviation factor Z PLL P1 TLL Z (PLL,TLL) Z (P1 ,TLL) T1 Z (PLL,T1) Z (P1 ,T1) P. Ref Pj PUL Z (Pj,TLL) Z (PUL,TLL) Z (Pj,T1) Z (PUL,T1) Z (Pref,TLL) Z (Pref,T1) I T. Ref I Z (PLL,Tref) I Z (P1 ,Tref) [] Z (Pref,Tref) [] Z (Pj,Tref) Iz (PUL,Tref) I Ti I Z (PLL,Ti) I Z(P1,Ti) [I Z (Pref,Ti) [] Z (Pj,Ti) I Z (PUL,Ti) I TUL I Z (PLL,TUL) I Z (P1 ,TUL) [} (Pref,TUL) [] Z (Pj,TUL) Iz (PUL,TUL) Where: 1) P. Ref is the standard pressure in Paa 2) T. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature Z is the deviation factor of the gas (evolved from a flash of the reservoir fluid) at line conditions. It should be given with 3 significant digits (example: 0.893). . . #f.,,3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 16 of 22 3.2.3 Gas Expansion factor (bg) The Gas expansion factor could be computed using the Z-factor. The necessary information is represented here below, bg PLL P1 TLL bg (PLL,TLL) bg (P1 ,TLL) T1 bg (PLL,T1) bg (P1,T1) P. Ref Pj PUL bg (Pj,TLL) bg (PUL,TLL) bg (Pj,T1) bg (PUL,T1) bg (Pref,TLL) bg (Pref, T1) I T. Ref I bg (PLL,Tref) I bg (P1 ,Tref) [] bg (Pref,Tref) [] bg (Pj,Tref) I bg (PUL,Tref) I Ti bg (PLL,Ti) I bg (P1,Ti) [I bg (Pref,Ti) [] bg (Pj,Ti) [ bg (PUL,Ti) I TUL Where: bg (PLL,TUL) I bg(P1 ,TUL) []b9 (Pref,TUL) [] bg (Pj,TUL) I bg (PUL,TUL) 1) P. Ref is the standard pressure in Paa 2) 1. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature bg is the gas volume factor in Sm3/m3. It should be expressed in 3 significant digits (example: 123). Note that the bo table is similar to the traditional 80 factor used for reservoir analysis work, but should cover also the range of lower pressure and temperatures encountered in the meter at surface conditions. · · · · '. · · · · · · · · · · · · · · · · · · · · · · · r. · · · · · '. · · .' · · · · · · · · · · · .' · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . #w. 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 17 of 22 3.2.4 Stock Tank Gas Oil Ratio (Rst) Rst is highly a function of the downstream process conditions (number of separation steps, pressure and temperature of such steps, in particular if any liquid stabilisation process is used. The following table shall be filled, using more customary units: The necessary information is represented here below Rst PLL P1 TLL Rst (PLL,TLL) Rst (P1 ,TLL) T1 Rst (PLL,T1) Rst (P1 ,T1) Pj PUL Rst (Pj,TLL) Rst (PUL,TLL) Rst(Pj,T1) Rst (PUL,T1) P. Ref Rst (Pref,TLL) Rst (Pref,T1) I T. Ref I Rst (PLL,Tref) I Rst (P1 ,Tref) [I Rst (Pref,Tref) ,m Rst (Pj,Tref) Rst (PUL,Tref) I Ti I Rst (PLL,Ti) I Rst (P1 ,Ti) [I Rst (Pref,Ti) I Rst (PUL,Ti) I TUL I Rst (PLL,TUL) I Rst (P1 ,TUL) []Rst (Pref,TUL) [] Rst (Pj,TUL) I Rst (PUL,TUL) Where: 1) P. Ref is the standard pressure in Paa 2) 1. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature Rst is the gas evolved from oil at line conditions, Gas to Oil Ratio 2 (gas evolving from the oil at line conditions). It is highly a function of the downstream process conditions (number of separation steps, pressure and temperature of such steps, in particular if any liquid stabilisation process is used). It should be expressed with three significant digits (example: 123), in units of m3/m3. . . ~3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 18 of 22 3.3 Water Properties 3.3.1 Water Density The Vx meter uses the water density at line pressure and temperature to estimate the flow rates of oil, water and gas under line conditions. The necessary information is represented here below, RHOW PLL P1 TLL Rhow(PLL,TLL) Rhow(P1,TLL) T1 Rhow(PLL,T1 ) Rhow(P1 ,T1) P. Ref Pj PUL Rhow(Pj,TLL) Rhow(PUL, TLL) Rhow(Pj,T1) Rhow(PUL,T1 ) Rhow(Pref,TLL) Rhow(Pref, T1) I 1. Ref Rhow(PLL,Tref) I Rhow(P1,Tref) [ Rhow(Pref,Tref) Rhow(Pj,Tref) Rhow(PUL,Tref) I Ti Rhow(PLL,Ti) I Rhow(P1,Ti) [I Rhow(Pref,Ti) [] Rhow(Pj,Ti) I Rhow(PUL,Ti) I TUL I Rhow(PLL,TUL) I Rhow(P1,TUL) []RhOW(pref,TUL) [] Rhow(Pj,TUL) RhOW(PUL,TUL) I Where: 1) P. Ref is the standard pressure in Paa 2) 1. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature Rhowater is the density of the water at line conditions expressed in kg/m3. It should be given with 5 significant digits (example: 1000.6 kg/m3) There is no need to have equally spaced pressure or temperature. The table must be completely filled. · · · · · '. · · · · · · · · .1 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · .' · · · · · · '. · · · · · · .' · · · · · · · · · · · . . ~3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 ~easurennents~ Page: 19 of 22 3.3.2 Stock Tank Gas-Water Ratio: Rwst Rwst is the gas that is dissolved in water at line conditions that is liberated at standard conditions. It is highly a function of the downstream process conditions (number of separation steps, pressure and temperature of such steps, in particular if any liquid stabilisation process is used) and can be ignored in most of the cases -if no C02 is present. The necessary information is represented below, Rwst PLL P1 TLL Rwst(PLL, TLL) Rwst(P1,TLL) T1 Rwst(PLL,T1) Rwst(P1,T1) P. Ref Pj PUL Rwst(Pj,TLL) Rwst(PUL,TLL) Rwst(Pj,T1 ) Rwst(PUL,T1 ) Rwst(Pref,TLL) Rwst(Pref, T1 ) I T. Ref I Rwst(PLL,Tref) I Rwst(P1,Tref) [ Rwst(Pref,Tref) Rwst(Pj,Tref) Rwst(PUL,Tref) I Ti I Rwst(PLL,Ti) I Rwst(P1,Ti) [I Rwst(Pref,Ti) [] Rwst(Pj,Ti) I Rwst(PUL,Ti) I TUL I Rwst(PLL,TUL) I Rwst(P1,TUL) []Rwst(pref, TUL) [] Rwst(Pj,TUL) IRwst(PUL,TUL) I Where: 1) P. Ref is the standard pressure in Paa 2) T. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature The above table shall be filled, using m3/m3 units. It should be expressed with 3 significant digits (example: 12.3) in m3/m3. . . ~3-PHASE No: 6010-0271-D VX fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 20 of 22 3.3.3 Water Volume Factor (bw) The water volume factor (bw) is used to perform the computation of the flow rate at standard conditions from the flow rate at line conditions. Note that bw is a function of the process conditions downstream of the meter, and can vary significantly if C02 and H2S is present and depending on the number of separation stages and conditions (pressure / temperature). The necessary information is represented below, bw PLL P1 TLL bw(PLL,TLL) bw(P1,TLL) T1 bw(PLL,T1 ) bw(P1 ,T1) P. Ref Pj PUL bw(Pj,TLL) bw(PUL,TLL) bw(Pj,T1 ) bw(PUL,T1 ) bw(Pref,TLL) bw(Pref,T1 ) I 1. Ref I bw(PLL,Tref) I bw(P1,Tref) [] bw(Pref,Tref) [] bw(Pj,Tref) I bw(PUL,Tref) I Ti I bw(PLL, Ti) I bw(P1,Ti) [I bw(Pref,Ti) [] bw(Pj,Ti) I bw(PUL,Ti) I TUL I bw(PLL,TUL) I bw(P1,TUL) [}W(pref,TUL) [] bw(Pj,TUL) bW(PUL,TUL) Where: 1) P. Ref is the standard pressure in Paa 2) T. Ref is the standard temperature in K 3) Pj is the jth Pressure in Paa in the range of pressure expected in normal flow conditions. 4) Ti is the ith Temperature K in the range of temperature expected in normal flow conditions. In other words, Pi and Tj represent the area where the meter operates most of the time 5) PLL : Pressure Lower Limit -should be lower or equal to standard pressure. 6) TLL :Temperature Lower Limit - should be lower or equal to standard temperature. 7) PUL : Pressure Upper Limit - should be greater than the highest expected line pressure 8) TUL : Temperature Upper Limit - should be greater than the highest expected line temperature bw is the water volume factor in Sm3/m3. It should be given with 3 significant digits (example: 0.893). Note that the bw table is similar to the traditional Bw factor used for reservoir analysis work, but should cover also the range of lower pressure and temperatures encountered in the meter at surface conditions. · · · · Ie · · · · · · · · · · · · · · · · · · · · · · · · · · · '. · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · . . ~ 3-PHASE No: 6010-0271-D VX Fluids ID Process Overview and Rev.: 00 Input Requirements Date: 1-Aug-05 Measurements AS Page: 21 of 22 3.4 Viscosity of the liquid at line conditions The Vx meter requires viscosity behaviour at line conditions for the proper modelling of viscous fluids. The liquid mixture is not only a function of pressure, temperature and WLR (Water Liquid Ratio), but also a function of the mixing and potential presence of de-emulsifiers, de-foamers, surfactant, or diluents that may be injected upstream the meter. Two approaches are possible: using the extended Einstein or Brinkman-Taylor mixing laws to determine the viscosity of the mixture of the two liquid phases or alternatively entering the data in a tabulated format. The table form is highly simplified, and is limited to a function of only temperature and WLR. Note that the liquid viscosity table shall be well described, as the table presents large discontinuities around the phase inversion point (which is also a function of temperature). The table shall cover the full range of WLR, from 0% to 100 % water. The necessary information is represented here below, WLRref WLRi WLR=100 ~ Liq vis (WLRO,Tref) liq vis (WLR1 ,Tref) [] Liq vis (WLRref,Tref) [] Liq vis (WLRi,Tref) I Liq vis (WLR100,Tref) I . - . W Liq vis (WLRO,Tj . . ~iq vis (WLR1,Tj) [::¡ Liq vis (WLRref,Tj) [] Liq vis (WLRi,Tj) I Liq vis (WLR100,Tj) ¡ - - c:æ!J Liq vis (WLRO,TUL) liq vis (WLR1,TUL)[] Liq vis (WLRref,TUL) I:] Liq vis (WLRi,TUL) LiqViS(WLR100,TUL)1 1) WLR is the Water to Liquid ratio at line conditions in percent (%) 2) T. Ref is the standard temperature in K 3) Tj is the jth Temperature K in the range of temperature expected in normal flow conditions 4) TLL :Temperature Lower Limit should be lower or equal to standard temperature 5) PUL : Pressure Upper Limit is set at 35 000 000 Paa 6) TUL : temperature Upper Limit is set at +425 K 7) WLRi is the ith WLR in percent (%) Liq vis is the liquid viscosity at line conditions expressed in Pa·s. It should be expressed with 3 significant digits (example: 0.123). There is no need to have equally spaced WLR or temperature but the table must be completely filled. 3..PHASE Measurements AS No: Vx Fluids ID Process Overview and Rev.: Input Requirements Date: Page: 6010-0271-D 00 1-Aug-05 22 of 22 · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · 4 POLYNOMIAL COEFFICIENTS Fluid properties are different at different conditions. The values of a fluid property can be displayed as a three-dimensional surface, as illustrated below for a heavy oil: Pro Result: Rho oil When the oil density at different pressures and temperatures is needed, it can be calculated using a function that describes the oil density behaviour. For pressure in units of Pa and temperature in K, the function below will produce the oil density graphed above in units of kg/m3: Oil Density (P,T) [kg/m3] = 7.16x109p.1r1 - 3 x104r1 - 2.01x10·3pr1 - 4.82x107p.1 + 1.23x1 03 + 6.69x10·6p + 8.22x1 04p.1T - 6.56x1 0·1T - 1.57x1 O·SPT To determine the oil density at some P & T, the numerical values for P [Pa] and T [K] are put into the above function and the oil density is computed. The calculated oil density at 101325 Pa and 288 K is 940.4 kg/m3. It is very important to ensure that the P & T are in the correct units otherwise the resulting density will be wrong. Instead of writing this function out in its long form, it can also be written as a table: -6.56E-01 It is these small sets of coefficients and exponents that are entered into the Vx software so that the 11 fluid properties can be calculated for any P & T within the validity range of the coefficients (the ranges of pressure and temperature over which the curve fit applies.) If the table of coefficients is available and the fluid property at a particular P and T is desired, the value can be calculated by working in the reverse order: the long form of the function can be written from the coefficient set, the particular P and T inserted, and the fluid property computed.