Experiment Protocol Petroleum Engineer in New Zealand Auckland –Free Word Template Download with AI

This Experiment Protocol outlines the procedures for a controlled laboratory simulation designed to evaluate the efficiency of CO2-enhanced oil recovery (EOR) techniques in sandstone reservoirs. This protocol is specifically tailored for the Petroleum Engineer operating within the research facilities in New Zealand Auckland. The primary objective is to quantify the incremental oil recovery factor when utilizing supercritical CO2 injection under varying pressure and temperature conditions that mimic the geological formations found in the Taranaki Basin, which is the primary hydrocarbon-producing region of New Zealand.

The Petroleum Engineer must adhere strictly to this protocol to ensure data integrity, safety compliance with New Zealand regulations, and reproducibility of results. The experiment aims to contribute to the broader understanding of sustainable extraction methods relevant to the energy landscape of New Zealand.

This protocol applies to all experimental activities conducted by the Petroleum Engineer at the designated laboratory in New Zealand Auckland. It covers the preparation of core samples, the setup of the high-pressure flow loop, the execution of the injection process, and the post-experiment analysis. The scope is limited to core flooding experiments using synthetic brine and crude oil analogs representative of New Zealand reservoir fluids.

Safety is paramount. The Petroleum Engineer must comply with the Health and Safety at Work Act 2015 of New Zealand. Specific safety measures for this experiment include:

• Personal Protective Equipment (PPE): Safety glasses, lab coat, chemical-resistant gloves, and closed-toe shoes are mandatory.
• CO2 Handling: As CO2 is an asphyxiant, the laboratory in New Zealand Auckland must be equipped with CO2 detectors and adequate ventilation. The Petroleum Engineer must be trained in emergency procedures for gas leaks.
• High-Pressure Systems: All high-pressure vessels and lines must be inspected before use. Pressure relief valves must be functional.
• Chemical Safety: Safety Data Sheets (SDS) for all chemicals used must be accessible. Spill kits must be available.

The Petroleum Engineer shall prepare the following materials and ensure the equipment is calibrated:

• Core Samples: Sandstone cores (5 cm diameter, 10 cm length) sourced from New Zealand geological formations or equivalent analogs.
• Fluids: Synthetic crude oil, synthetic brine (matching reservoir salinity), and high-purity CO2.
• Equipment:
  • High-pressure core holder with heating jacket.
  • Positive displacement pumps for fluid injection.
  • Back-pressure regulator.
  • Differential pressure transducers.
  • Flow meters.
  • Data acquisition system.

The Petroleum Engineer shall execute the following steps in sequence:

5.1. Core Sample Preparation

1. Clean the sandstone core samples using toluene and methanol to remove any existing hydrocarbons.
2. Dry the cores in an oven at 60°C for 24 hours.
3. Saturate the cores with synthetic brine under vacuum to ensure 100% water saturation.
4. Measure the initial porosity and permeability of each core sample.

5.2. System Setup

1. Install the saturated core sample into the high-pressure core holder.
2. Connect the core holder to the fluid injection pumps and the back-pressure regulator.
3. Set the heating jacket to the target reservoir temperature (e.g., 60°C).
4. Pressurize the system with brine to the target confining pressure (e.g., 15 MPa) and pore pressure (e.g., 10 MPa).

5.3. Oil Saturation

1. Inject synthetic crude oil into the core at a constant flow rate until water breakthrough is observed.
2. Continue injection until the produced water cut stabilizes at less than 1%.
3. Record the volume of oil injected and water produced to calculate the initial oil saturation.

5.4. Water Flooding

1. Switch the injection fluid to synthetic brine.
2. Inject brine at a constant flow rate until the produced oil rate drops below a predefined threshold (e.g., 0.01 mL/min).
3. Record the cumulative oil production to determine the recovery factor from water flooding.

5.5. CO2 Injection (EOR Phase)

1. Switch the injection fluid to supercritical CO2.
2. Inject CO2 at a constant flow rate, maintaining the system pressure above the minimum miscibility pressure.
3. Monitor the differential pressure across the core and the composition of the produced fluids.
4. Continue injection until the produced oil rate drops below the predefined threshold.
5. Record the cumulative oil production to determine the incremental recovery factor from CO2 injection.

5.6. System Shutdown

1. Gradually reduce the system pressure to atmospheric pressure.
2. Turn off the heating jacket and allow the system to cool.
3. Remove the core sample and store it for further analysis if required.
4. Clean all equipment and dispose of waste fluids according to New Zealand Auckland environmental regulations.

The Petroleum Engineer shall analyze the collected data to calculate:

• Initial oil saturation.
• Recovery factor from water flooding.
• Incremental recovery factor from CO2 injection.
• Total recovery factor.

A comprehensive report must be prepared, detailing the experimental conditions, results, and conclusions. The report should highlight the implications of the findings for potential EOR applications in New Zealand reservoirs. All data must be stored securely in the laboratory's database in New Zealand Auckland.

This Experiment Protocol provides a structured approach for the Petroleum Engineer to conduct CO2-enhanced oil recovery simulations in New Zealand Auckland. By following this protocol, the Petroleum Engineer can generate reliable data that contributes to the advancement of petroleum engineering practices and supports the energy sector in New Zealand.