As per the PFDs, a mixture of sour water and 50% hydrocarbons enters a three-phase separator operating at 185 psig and 120°F. The separator is provided with an LCV to control the liquid level. This LCV also reduces the pressure of the sour water from 185 psig to atmospheric pressure.

After separation, the sour water, containing 0.12 mol% H₂S, is routed to an atmospheric storage tank (internal floating roof tank) through an 8-inch line. The tank is provided with an 8-inch water inlet nozzle, which is submerged below the liquid level. The minimum tank liquid level is 4 meters, while the tank is 18 meters high and 15 meters in diameter.

The tank is equipped with a PVRV designed for thermal breathing. An H₂S adsorbent bed is installed on the tank vent line to treat the vented vapor before discharge to the atmosphere. The tank is also provided with nitrogen blanketing to maintain the required tank pressure.

The tank is an internal floating roof tank. The design sour water flow rate is 6,000 bbl/day, while the actual operating flow rate is approximately 2,000 bbl/day.

Appreciate any major concerns with this design. The project is about to start based on the provided design by the engineering contractor.

The curve may still be perfectly useful, but you're left with a scanned or paper Q-H curve rather than a digital dataset.

Curious how others here deal with this:

• Do you digitize the curve manually and recreate the Q-H data in Excel or another tool?

• How do you handle interpolation between the published points?

• When the operating conditions change, how do you generate a revised curve using speed or impeller diameter changes?

• For old curves, how do you handle efficiency and NPSHr data when only the original plotted curves are available?

• For pumps in series or parallel, do you digitize and combine the curves yourself?

I've ended up building an Excel workbook for my own work that takes a pump performance curve from a paper/PDF/image source, converts it into a usable digital curve, and then allows the curve to be evaluated under changed operating conditions using the relevant scaling relationships. It also allows the resulting performance data to be generated in a usable engineering format.

The reason I built it was mainly to make older or otherwise inaccessible pump curves usable again — particularly where the original OEM digital selection software or product database is no longer available.

Happy to share what I developed if anyone is interested. I'm mainly interested in how others here approach this problem and whether there are established methods or tools that you use.

 Hydrate_Prediction_Calculator_Wayne Gajadhar.xlsx   128.5KB   11 downloads

I am calculating the actual temperature of the flaring gas from our Vacuum Distillation Tower where a stream of gas (C11H24) at a temperature of 400 C, a pressure of 4.5 barg, enters a flare header with a diameter of 32 inches and a length of 600 meters. Given that the ambient temperature is 48 C, according to heat transfer calculations, on average, the gas temperature drops to 340 degrees at the end of pipe. But this temperature for stress analysis calculations has led to the addition of several loops in the design. Does anyone have any experience in this regard? Isn't the temperature of the pipe wall much lower in practice due to the actual heat transfer with the environment as well as radiation, for example, below 200 degrees? If the temperature drops more in practice , the number of loops caused by the stress analysis calculations will really decrease. I would like to thank you for helping me.

Araboni

SO BASICLY WE WANT TO SIZE A PRESURE EQUALIZATION LINE FOR A 10" PIPELINE VALVE (KIND OF BY-PASS) TO EQUALIZE THE DOWNSTREAM OF THE 10" VALVE DE TO A VERY HIGH DP BETWEEN UPSTREAM AND DOWNSREAM OF THE VALVE.

THE PIPELINE CARRY A 85 BAR LPG.