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Accurate Measurement Guidelines

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Accurate Measurement Guidelines Accurate Measurement Section I Chapter 2 Guidelines Revision: 1 Introduction This standard is designed to provide production operations personnel with detail information concerning Fieldwood's Measurement Standard Operating Procedures. Included are the following: • Meter Proving Guidelines • Measurement Principles • S&W, Gravity & Temperature • Orifice Plate Holder & Calibration • Custody Transfer Measurement • Meters & Meter Proving • Sampling Procedures • Witnessing Responsibilities Meter Proving & Calibration The purpose of Meter Proving/Meter Calibration is to obtain accurate results so Fieldwood Energy will receive appropriate income for the measured volumes and report correct data/volumes on the morning reports (i.e. Accurate Measurement). The reason meters are proven and calibrated is: • So all parties are treated fairly • It's a tool for troubleshooting • To report exceptions on Morning Reports • Uniformity in Measurement Equipment and Procedures • Fixed Methods for Problem Solving • Repeatable Procedures and Practices Data Retention and Recordkeeping Here are the data retention and recordkeeping requirements: • Well Test Documentation = 2 Years on Platform • Gas & Oil Meter Proving & Run Tickets = 2 Years on Platform • Chart and/or EFM (Electronic Flow Measurement) Data = 2 Years on Platform Note: All inquiries by BSEE for production audit information should be directed to Safety Environmental and Compliance Department. Safe Work Practices Page I-2-1 Accurate Measurement Section I Chapter 2 Guidelines Revision: 1 Gas Measurement Daily gas volumes will be obtained from the Pipeline Gas Sales Meter and note readings on the morning report. All gas FMP points will have a gas sample procured and a gas analysis performed every six (6) months. Copies of the gas analysis will be kept in the gas measurement file on the platform for 2 years. The check meter readings are for backup purposes in the event the pipeline meter(s) fail. Ensure Fieldwood's check meter recording devices have the same parameters as the gas sales meters (i.e. plate size, meter run I D, calculation methods and analytical data). Ideal Beta (β) range is .20 to .60 for Daniels Senior Fittings Beta Ratio = d / D d = Orifice Plate Diameter in Inches (ID) D = Meter Tube Diameter in Inches (ID of meter tube) Below is an example of a meter tube that is oversized and needs to be changed: 3 inches of differential on a 10 tube means we are operating out of the acceptable differential of 10 to 80 inches for EGM and 20 to 80 for Charts. Installing a 1” plate brings the (β) to .10, but will not raise the differential up enough to meet the differential range. Meter tube needs to be downsized. The minimum differential for gas measurement is 20 Inches for charts. (20% of the flow range is recommended) The minimum differential when using smart transmitters EFM (Electronic Flow Measurement) is 10 Inches. Typical Measurement Errors The following table will describe conditions that can cause gas measurement errors and result in loss of income or over measurement. Safe Work Practices Page I-2-2 Accurate Measurement Section I Chapter 2 Guidelines Revision: 1 Chart Recorders and Charts When using a chart recorder, the Red pin should read between 20 inches and 80 inches of differential. (Maintain beta ratio of .20 to .60 β) The following pertinent data must be on each chart: • Location (Vessel ID) • Tube ID • Plate Size • Average Temperature (if applicable) • Date and Time Chart Installed • Initialed or Signed by Person Changing Chart Charts must be zeroed as follows: • 24 Hour Charts = Zeroed Every Chart Change • 7 Day Charts = Zero Verified Daily Note any unusual conditions on the chart and store charts properly until they are mailed. Chart Measurement Differential Minimum 20% of operating range 20% of 100 Inches = 20 Inches (20% of 250 Inches - 45 Inches) See Percent (5) of Error in Calibrations Chart below: Example Error: A 1/2” (4.5) error in 5” = 11.11% At 5,000 MCF/day 11.11%= 555.5 MCF/day X 365 X $ 4.30 MCF = $ 871,857/year Chart recorders may be used as custody/royalty meters with a departure from the regulations and/or agreement. The charts are to be integrated and volume statements generated as an audit trail with these statements to be sent to BSEE for royalty purposes. Safe Work Practices Page I-2-3 Accurate Measurement Section I Chapter 2 Guidelines Revision: 1 Typical EGM Installation Pictured is a typical EGM installation: These are the minimum parameters that should be programmed into an EGM meter: • Plate Size • Temperature • Pressure • Meter Run ID • Calculation Methods • Analytical Data (i.e. CO2, Nitrogen, Specific Gravity) Sediment & Water S & W tubes need to be certified/verified. Order certified tubes with certifications attached and keep certifications on file on the platform. Some S&W tubes have been found to be as much as 5 to 7 % out of calibration. Example an Error Could Cost: 0.50% - 0.025 = 0.475% 60,000/day x 0.50% = 300 barrels 60,000/day x 0.475% = 285 barrels 300 minus 285 = 15 bbls/day x 365 days/year x $100.00/bbl.= $ 547,500 Centrifugal Recommendations: Read tubes to the nearest 1/10 of 1 % Each sample should shakeout (ground-out) for a period of 5 minutes at 1500 rpm Misreading a centrifugal test by 1/10 of 1% from a full 1,000 barrel tank is equal to 1,000 x .001 (1 barrel) Safe Work Practices Page I-2-4 Accurate Measurement Section I Chapter 2 Guidelines Revision: 1 Gravity Oil Surface must be within ½ inch of the top of the thief before taking reading for gravity. This rise of liquid along the stem above the level surface is called the “MENISCUS” and the reading should be taken at its top. Subtract from this reading 0.1 to obtain the “Indicated Gravity” reading. In determining the “Gravity Temperature” with draw the hydrometer from the liquid only high enough to expose the thermometer scale at the bottom. Temperature Temperature is very important, for example: 1 degree Fahrenheit for a typical crude = 0.05% (1.0005) CTL correction factor. Note: CTL is: Correction for the effect of temperature on a liquid Impact to Fieldwood Income Example: 60,000 bbls/day = 10,950/ bbls/year 10,950 X $ 100/bbl = $ 1,095,000 Orifice Plate Holder Assembly There are three types of orifice plate holder assemblies in general use. Each of these assemblies is used for a specific purpose, however, they all provide the same basic features: • To hold the plate centered in the line of flow. • To seal around the plate so that all the gas flow passes through the plate opening. • To provide taps for the upstream and downstream pressure sensing lines. • To provide for the removal, reinstallation or replacement of the orifice plate. Inspection Frequency: Senior Orifice Fitting = Every Meter Calibration Orifice Junior & Simplex Fitting = Every Meter Calibration (If Possible) Flange Type Fitting = Annually (If Possible) Orifice Plates The Orifice Plate is the most important part of the primary element. This is the heart of the orifice measurement system and there are two types of orifice plates: 1. The Universal Type plate is used in the junior and senior type orifice assemblies. 2. The Paddle Type is used in the orifice flange type assemblies. Safe Work Practices Page I-2-5 Accurate Measurement Section I Chapter 2 Guidelines Revision: 1 REMEMBER, the sharp edge of the orifice must always be facing upstream and the beveled edge must always be facing downstream. NEVER, hang the orifice on metal pegs, nails or other devices as this will destroy the edge of the orifice. Plates should be sized to maintain differential readings between 10 - 100 % where EGM devices are used. Orifice Plate Inspection and Storage Plates should be taken out of the fitting and visual inspected as often as possible. Inspection: • Inspect for dirty, bowed, bent, nicked,eroded or backward installation which may produce large metering errors. • Plate seal rings should be part of every inspection. • Anytime it is suspected that a plate has been damaged, it should be inspected immediately. • Damaged plates should be discarded. Storage: • Plates should be stored in such a manner to protect the surface and edge of the plate from damage. • Plates should be stored in an orifice plate box and out of the weather. Orifice Beta Ratios As mentioned earlier Beta Ratio = d / D d = Orifice Plate Diameter in Inches (ID) D = Meter Tube Diameter in Inches (ID of meter tube) Maintain beta ratios from .20 to .60 Report all plate sizes to 3 Decimal places (Example .875) Orifice Meter Calibration Orifice meter measuring elements include; differential pressure transmitters, temperature transmitters, static pressure units and thermal systems electronic (EGM) chart recorders pneumatic. Safe Work Practices Page I-2-6 Accurate Measurement Section I Chapter 2 Guidelines Revision: 1 Prior to testing differential pressure units or transmitters... all leaks on tubing fittings, valves, etc. should be repaired. Orifice meter measuring elements should be verified at flowing conditions. Differential and Pressure elements should be verified at specified test points (i.e. 6 up 5 down) Calibration should occur if element is not within Company or contract tolerances Example: Differential .25 Inches Temperature .5 Degrees) On EGM’s, markers (platesize, temperature, differential, static and analysis data) should be logged into the EGM as found and as left: Example: Found 20 Inch Differential Left 22 Inches Example: Pressure found 750 psi Left 775 psi Plate changes should be logged into EGM’s using the manufacturer’s specified procedure. NOTE: Fieldwood personnel are "NOT" allowed to change an orifice plate in a Pipeline Gas Sales Meter Run. Checking Temperature Transmitters When checking a temperature transmitter, the calibration report will show the Temperature of the Standard used to test the online temperature device, the as found temperature and the as left temperature.
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