In the realm of oil and gas production, maximizing resource extraction is a constant pursuit. One technique employed to achieve this is Intermittent Lift, also known as Intermittent Gas Lift. This method involves injecting gas into the wellbore in periodic intervals, rather than continuously, to lift fluids to the surface. This strategy offers several advantages over continuous gas lift, making it a valuable tool for optimizing production.
Intermittent lift operates by injecting a defined volume of gas into the wellbore at regular intervals. This gas displaces the oil or gas in the wellbore, creating a pressure differential that forces the fluid upwards. The injection cycles are typically controlled by a surface-mounted system that monitors wellbore pressure and adjusts the timing and volume of gas injection accordingly.
Intermittent lift is widely used in various applications, including:
Intermittent lift is a proven technique for optimizing oil and gas production. By injecting gas periodically, it offers a more efficient and environmentally friendly alternative to continuous gas lift. Its versatility and adaptability make it a valuable tool for maximizing production from a wide range of well types and reservoir conditions. As the industry continues to focus on improving operational efficiency and reducing environmental impact, intermittent lift is poised to play an increasingly important role in the future of oil and gas production.
Instructions: Choose the best answer for each question.
1. What is the primary advantage of intermittent lift over continuous gas lift?
a) Higher initial production rates b) Reduced gas consumption c) Increased wellbore pressure d) Lower risk of wellbore collapse
b) Reduced gas consumption
2. How does intermittent lift work to lift fluids to the surface?
a) By injecting a continuous stream of gas into the wellbore. b) By injecting gas periodically, creating pressure differentials. c) By using a pump to draw fluids upwards. d) By relying solely on natural reservoir pressure.
b) By injecting gas periodically, creating pressure differentials.
3. Which of the following is NOT a benefit of intermittent lift?
a) Improved wellbore stability b) Increased production rates c) Reduced environmental impact d) Increased risk of wellbore collapse
d) Increased risk of wellbore collapse
4. Intermittent lift is particularly beneficial for which type of wells?
a) Newly drilled wells with high production rates b) Mature wells with declining reservoir pressure c) Wells with a high concentration of dissolved gas d) Wells with a high concentration of hydrogen sulfide
b) Mature wells with declining reservoir pressure
5. How is the timing and volume of gas injection typically controlled in intermittent lift systems?
a) By manually adjusting valves at the wellhead b) By a surface-mounted system that monitors wellbore pressure c) By using a timer to control injection cycles d) By the rate of natural gas production from the well
b) By a surface-mounted system that monitors wellbore pressure
Scenario: A mature oil well is experiencing declining production due to reduced reservoir pressure. The well has a high water cut and low natural gas production. You are considering implementing an intermittent lift system to enhance production.
Task:
1. **Intermittent lift could help improve production in this specific scenario by:** * **Increasing wellbore pressure:** Periodic gas injection will create pressure differentials, pushing more oil and water to the surface. * **Managing water cut:** Intermittent lift can be adjusted to optimize water production and maintain stable oil flow. * **Improving efficiency:** Reduced gas consumption compared to continuous lift will lower operating costs. 2. **Key factors to consider when designing the intermittent lift system:** * **Wellbore pressure:** Carefully monitor pressure to determine the optimal frequency and volume of gas injection. * **Water cut:** Adjust the system to minimize water production while maximizing oil output. 3. **Potential challenge and solution:** * **Challenge:** Increased risk of gas channeling or bypassing if the wellbore has significant permeability variations. * **Solution:** Use a multi-point injection system to distribute gas evenly throughout the wellbore, minimizing channeling.
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