Experiment Protocol Petroleum Engineer in Mexico Mexico City –Free Word Template Download with AI

This Experiment Protocol outlines the standardized procedures for conducting laboratory-scale simulations of Enhanced Oil Recovery (EOR) techniques, specifically focusing on Carbon Dioxide (CO2) injection. This protocol is designed for use by Petroleum Engineers operating within the geological context of the Mexico City Basin. The primary objective is to evaluate the efficiency of CO2 flooding in recovering residual hydrocarbons from tight carbonate and sandstone formations characteristic of the region surrounding Mexico City.

The petroleum industry in Mexico faces unique challenges due to the complex geology of the Basin of Mexico. As a Petroleum Engineer, understanding the interaction between injected fluids and native reservoir rock is critical. This protocol applies to experimental setups conducted in certified laboratories within Mexico City, adhering to local environmental regulations and safety standards set by the Secretariat of Energy (SENER) and the National Hydrocarbons Commission (CNH).

The scope includes:

• Core sample preparation from specific geological strata near Mexico City.
• Fluid property characterization (oil, water, and CO2).
• Core flooding experiments under reservoir conditions.
• Data analysis for recovery factor calculation.

The primary objectives of this experiment are:

1. To determine the residual oil saturation after primary and secondary recovery processes in Mexico City Basin rock samples.
2. To evaluate the miscibility conditions between CO2 and the crude oil found in the region.
3. To quantify the incremental oil recovery achieved through CO2 injection.
4. To assess the impact of injection rates on sweep efficiency and pressure drop across the core sample.

All equipment must be calibrated and certified prior to use. The following materials are required:

• Core Samples: Cylindrical rock cores (2.5 cm diameter, 10 cm length) extracted from wells in the Mexico City Basin, representing target reservoir zones.
• Core Holder: Stainless steel Hassler-type core holder capable of withstanding pressures up to 10,000 psi.
• Fluids: Live crude oil from the basin, formation brine, and high-purity CO2 (99.9%+).
• Pumps: High-pressure syringe pumps for precise fluid injection.
• Pressure Transducers: For monitoring inlet and outlet pressures.
• Temperature Control System: To maintain reservoir temperature (approx. 60°C - 80°C depending on depth).
• Flow Meter: For accurate measurement of effluent volume.

All Petroleum Engineers involved must:

• Wear appropriate PPE, including safety glasses, gloves, and lab coats.
• Ensure the laboratory is equipped with CO2 detectors and emergency shutdown systems.
• Follow waste disposal regulations for hydrocarbons and brine as per Mexican environmental law.
• Conduct a risk assessment before starting the experiment.

5.1. Core Sample Preparation

Begin by cleaning the core samples to remove any drilling mud or contaminants. This is typically done using toluene and methanol in a Soxhlet extractor. After cleaning, dry the cores in an oven at 60°C for 24 hours. Measure the dry weight and dimensions to calculate porosity and permeability using helium porosimetry and gas permeametry.

5.2. Saturation with Brine

Place the core sample in the core holder and apply confining pressure. Saturate the core with formation brine by injecting it at a low rate until no gas bubbles are observed in the effluent. This simulates the initial water saturation of the reservoir.

5.3. Oil Saturation

Inject live crude oil into the core sample at a controlled rate to displace the brine. Continue until the effluent is 100% oil. This step establishes the initial oil saturation (Soi) of the core, mimicking the reservoir's state before production.

5.4. Primary and Secondary Recovery Simulation

Simulate primary recovery by producing oil under reservoir pressure. Follow this with secondary recovery by injecting brine (water flooding) until the water cut reaches 98%. Record the volume of oil recovered during these stages.

5.5. CO2 Injection (Tertiary Recovery)

Begin the CO2 injection phase. Inject CO2 at a constant rate, monitoring pressure and effluent composition. Adjust the injection rate based on the pressure drop across the core to avoid fracturing. Continue until the breakthrough of CO2 is observed at the outlet. Maintain injection until no more oil is produced.

Throughout the experiment, record the following data at regular intervals:

• Inlet and outlet pressures.
• Volume of injected fluids (brine, CO2).
• Volume of produced fluids (oil, water, gas).
• Temperature of the core holder.

After the experiment, calculate the recovery factors for each stage:

• Primary Recovery Factor: (Volume of oil produced / Initial oil in place) × 100
• Secondary Recovery Factor: (Volume of oil produced by water flood / Initial oil in place) × 100
• Tertiary Recovery Factor: (Volume of oil produced by CO2 injection / Initial oil in place) × 100

Compare the results with historical data from Mexico City Basin wells to validate the applicability of CO2 EOR in the region.

All Petroleum Engineers must compile a detailed report including:

• Experimental setup and conditions.
• Raw data and calculations.
• Graphs of pressure vs. time and recovery factor vs. pore volumes injected.
• Conclusions and recommendations for field application.

The report should be submitted to the project manager and archived according to company policy. This documentation is crucial for future reference and for regulatory compliance in Mexico.

This Experiment Protocol provides a comprehensive framework for evaluating CO2-based Enhanced Oil Recovery techniques in the context of the Mexico City Basin. By following these procedures, Petroleum Engineers can generate reliable data to support decision-making for oil field development and optimization in Mexico. The insights gained from this experiment will contribute to maximizing hydrocarbon recovery while minimizing environmental impact.