Pressure

• 1 bar = 14.5 psi =》1bf (bound per force) /inch^2
• 1atm= 14.7 psi
• 100 kpa(killo pascal) = 14.5 psi
• 1 psi = 6.4 kpa

Temperature:

• Temp(F°) = 32 + ( 1.8 * T(C°) )
• Temp(R°) = Temp (F°) + 460

Length:

• 1feet = 30.5cm = 0.305m = 12inch
• 1inch = 2.54cm = 25.4mm
• 1yard = 3feet = 0.9144m

Volume:

• 1barrel= 42USgal= 35 imperial gallon= 159 liters
• (FOR NYTROGYN) 1Gallon = 92SCF {standard cubic feet} = 0.159m^2

Density:

• 1ppg = 119.83 kh/m^2
• 1SG = 0.12 * 1ppg
• 1ppg of water = 8.33

Hydrostatic pressure:

• = 0.052 * 1ppg(p) * TVD[total vertical depth] (rt)
• Bottom hole pressure (shut-in case) = shut-in pressure [ pressure in the surface] + Hydrostatic[pressure of the liquid in the tubing]

Volume in barrels:

• V= ID^2 [internal diameter] * L(feet) / 1029.4
• V= ID^2 casing - ED^2 tubing

Retention Time =》 the time it takes one liquid moleculer to enter the Separator and exit. Retention time= 0.5 * Separator volume / liquid flow rate (bbl/day)

Factors affecting gas rate:

Temperature in Rankine= Temperature in Fahernheit+460
Temperature in Fahrenheit= 32+ (1.8*Temperature in Celsius)

Using a gravitometer (ranarex). .............................................

• 300
• 600
• 900

• 1502 pipe
• 602 pipe

Do not panic, hold your breath, wear breathing apparatus, use ESD to secure the well, raise the alarm or inform the supervisor and finally proceed to muster station.

At least 600 feet. .......................

Using a gravitometer (ranarex). .............................................

The relation between temperature and gas rate is inversely proportional.
Also the relation between gas specific gravity and gas rate is inversely proportional.

As the h2s percentage increases the specific gravity increase.

Critical flow for oil is when the downstream pressure is 60% of the upstream pressure.

while for gas it is that the downstream pressure is 50% of the upstream pressure.

Transparent, refractive and magnetic.

1. A. Work authorization
2. B. Bypass safety controls
3. C. Confined space
4. D. Driving
5. E. Energy isolation
6. F. Line of fire
7. G. Working at height
8. H. Hot work
9. I. Toxic gas
10. J. Safe Mechanical lifting

Pressure instrument where pressure is applied to a hydraulic fluid to lift a small piston connected to a plate on which weight are added as necessary to balance pressure applied. Dead weight tester is a source of very accurate pressure and are used for calibration of other less accurate types of pressure measuring devices, such as Bourdon Tube Pressure Gauges.

Condensate gas ratio

Lower explosive limit (L.E.L)= 4.3% and Higher explosive limit (H.E.L)= 46%

The ratio between the tank volume/reading divided by the meter reading.

• For 2 inch 170-1700 bbl/day
• For 3 inch 1300-13000 bbly/day

National association of corrosion engineers.

They are a number of tubes placed in the gas line to streamline the flow before it enters the Daniel box in order to obtain laminar flow to be able to measure the gas rate.

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• Natural-gas hydrates are ice-like solids that form when free water and natural gas combine at high pressure and low temperature. This can occur in gas and gas/condensate wells, as well as in oil wells. Location and intensity of hydrate accumulations in a well vary and depend on:
  1. Operating regime
  2. Design
  3. Geothermal gradient in the well
  4. Fluid composition
  5. Other factors

• In the oil and gas industry, the term "hydration" is often used in the context of gas hydrates, which are ice-like crystalline solids composed of water and natural gas molecules, typically methane. Gas hydrates can form in certain conditions of pressure and temperature, and they pose challenges in oilfield operations. Here's how hydration is relevant in the oilfield:

  1. Gas Hydrate Formation:
     Formation Conditions: Gas hydrates form when water and natural gas combine under specific conditions of high pressure and low temperature, commonly found in deep-sea environments or in subsea pipelines.
  2. Flow Assurance:
     Pipeline Blockages: The formation of gas hydrates in pipelines can lead to blockages, restricting the flow of hydrocarbons. This phenomenon is a concern in flow assurance, and measures are taken to prevent or mitigate hydrate formation.
  3. Hydrate Inhibitors:
     Chemical Additives: Hydrate inhibitors are chemicals injected into the production stream to prevent the formation of gas hydrates. These inhibitors can modify the conditions under which hydrates form or destabilize existing hydrates.
  4. Subsea Operations:
     Subsea Equipment: In subsea operations, where pipelines transport hydrocarbons from offshore wells to onshore facilities, the risk of hydrate formation is significant. Subsea equipment may include systems for injecting inhibitors or other measures to manage hydrate risks.
  5. Well Testing:
     Hydrate Formation in Well Testing: In well testing operations, especially in deepwater or subsea wells, there may be a risk of hydrate formation due to the low temperatures and high pressures. Managing hydrate risks is crucial to ensure the safety and efficiency of testing operations.
  6. Production Chemistry:
     Chemical Management: Hydration considerations are part of production chemistry, where engineers and chemists work to optimize the chemical composition of fluids to prevent issues such as scale formation, corrosion, and hydrate formation.
  7. Safety Concerns:
     Safety Protocols: Hydrate formation can pose safety concerns, as it may lead to blockages in equipment or pipelines. Safety protocols and engineering controls are implemented to mitigate these risks.

  Preventing hydrate formation and managing the risks associated with it are essential aspects of oilfield operations. Engineers and chemists use a combination of temperature and pressure management, chemical inhibitors, and other technologies to ensure the safe and efficient production, transport, and processing of hydrocarbons in the presence of water.

In the oil and gas industry, "PVT" stands for Pressure-Volume-Temperature, and PVT samples refer to samples of reservoir fluids (crude oil and natural gas) that are collected and analyzed to understand their behavior under different pressure, volume, and temperature conditions. The analysis of PVT samples is crucial for reservoir engineering, well testing, and facility design. Here's a breakdown:

1. Pressure (P):

   • Definition: Pressure refers to the force exerted on a unit area. In the context of PVT analysis, it relates to the pressure conditions that fluids experience in the reservoir and during production.
   • Sample Collection: PVT samples are collected at various pressure levels representative of the reservoir conditions.

2. Volume (V):

   • Definition: Volume refers to the space occupied by a substance. In PVT analysis, it involves studying how the volume of hydrocarbons changes under different conditions of pressure and temperature.
   • Sample Collection: Samples are taken at different volumes to observe changes in fluid behavior.

3. Temperature (T):

   • Definition: Temperature is the measure of the average kinetic energy of particles in a substance. In PVT analysis, it's critical to understand how temperature influences the phase behavior of reservoir fluids.
   • Sample Collection: PVT samples are collected at various temperatures to study fluid behavior under different thermal conditions.

Why PVT Analysis is Important:

• Reservoir Characterization: PVT analysis helps in characterizing the fluids present in the reservoir, including their composition, phase behavior, and physical properties.
• Reservoir Simulation: PVT data is used in reservoir simulation models to predict the performance of the reservoir over time and optimize recovery strategies.
• Well Testing: PVT analysis is essential for interpreting well test data and understanding how reservoir fluids respond to changes in pressure and temperature during production.

PVT Sample Collection:

PVT samples are typically collected during well testing or through the use of wireline tools that can sample fluids downhole. The collected samples are then transported to a laboratory for detailed analysis. The analysis includes measuring properties such as density, viscosity, compressibility, and the phase envelope (the conditions under which different phases of hydrocarbons exist).

Accurate PVT analysis is crucial for making informed decisions in reservoir management, field development, and facility design in the oil and gas industry.

There are four colors for every three months; they are red , blue , white , yellow or orange
It paints on the slings after doing inspection if the equipments need maintenance or no

Meter factor and k-factor affect on the flow rate and it read like 94% of the real flow rate. Also temperature affect on the flow rate so if it actually 1000psi it read on the data 850psi

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