Presentation Transcript

1. API Liquid Hydrocarbon Measurement Standards Update David Johnson, Senior Business Analyst - Enterprise Upstream Volumes November 2, 2010
2. Disclaimer The following is intended to outline our general product direction. It is intended for information purposes only, and may not be incorporated into any contract. It is not a commitment to deliver any material, code, or functionality, and should not be relied upon in making purchasing decisions.  The development, release, and timing of any features or functionality described for P2 Energy Solutions’ products remain at the sole discretion of P2 Energy Solutions.
3. API Liquid Hydrocarbon Measurement Standards Update API 11.1 and 11.2 - Liquid Hydrocarbon Volume Correction Factors
4. Learning Objectives Review the physical principles underlying EU liquid hydrocarbon volume correction factor computations API gravity correction for temperature CTL - volume correction for temperature CPL - volume correction for pressure CTPL - combined correction for temperature and pressure Understand API 11.1 / 11.2 volume correction factor terminology Review API 11.1 - 2004 changes vs. API 11.1 - 1980 Perform Enterprise Upstream (EU) form operations and computations - tank inventories, run tickets, oil meter readings
5. Liquid Hydrocarbon Volume Correction Factors Observed (sample) conditions Standard conditions (60°F, 1 atm) Liquid (stock tank) conditions EU first corrects API gravity from observed (sample) conditions to standard conditions Volume correction factor is then computed based on liquid (stock tank) conditions
6. Liquid Hydrocarbon Volume Correction Factors
7. API 11.1 - 2004 summary of changes Increased supported range of API gravity and liquid temperature API gravity range -10 to 100°API (was 0 to 100°API) Temperature range -58 to 302°F (was 0 to 300°F) Pressure range unchanged at 0 to 1500 psi Standard density of water 999.016 kg/m3 (was 999.012 kg/m3) ITS-90 temperature scale (was ITS-68 temp scale) VCF rounding is now 5 digits globally Floating point mathematics instead of integer (fixed-point) mathematics
8. API Liquid Hydrocarbon Measurement Standards Update API 12.1.1 - CTSh correction / FRA adjustment
9. Learning Objectives Review the underlying physical principles of the CTSh correction and the FRA adjustment Learn how to perform EU tank details setup necessary for EU to apply the CTSh correction and the FRA adjustment Demonstrate how EU tank inventories and run tickets forms use CTSh and FRA within liquid hydrocarbon volume computations
10. Physical Principles and Nomenclature NSV = {[(TOV – FW) * CTSh] + FRA} * CTL * BSW NSV - net standard liquid volume (60 degF, 1 atm) TOV - total observed volume (tank top gauge) FW - free water (tank bottoms) CTSh - tank steel shell temperature correction factor FRA - floating roof displacement adjustment CTL - volume correction factor due to temperature BSW - basic sediment and water (%)
11. CTSh correction factor CTSh is the correction factor for the effect of the temperature, both ambient and liquid, on the shell of the tank CTSh = 1 + 2aΔT + a2ΔT2 a - coefficient of thermal expansion per steel type ΔT = Tsh - Tb Tsh - temperature of tank shell Tb - base temperature (60 degF) Tsh = (7*Tl + Ta) / 8 (non-insulated tanks) Tl - tank liquid temperature Ta - ambient temperature
12. CTSh - tank details setup
13. FRA adjustment NSV = {[(TOV – FW) * CTSh] + FRA} * CTL * BSW FRA is a positive or negative volume adjustment to account for displacement of the floating roof FRA units are barrels FRA adjustment is not a ‘correction factor FRA = weight (apparent mass of roof)/(density*CTL) Two distinct FRA computation methods Method A - tank strapping includes FRA Method B - tank strapping does not include FRA
14. FRA - tank details setup / method A
15. FRA - tank details setup / method B
16. FRA - EU form examples
17. API Liquid Hydrocarbon Measurement Standards Update David Johnson, Senior Business Analyst - Enterprise Upstream Volumes November 2, 2010