Experiment Protocol Petroleum Engineer in Pakistan Karachi –Free Word Template Download with AI

Prepared for: Senior Petroleum Engineer, Operations Division, Karachi.
Subject: Laboratory simulation of Enhanced Oil Recovery (EOR) techniques tailored for the specific geological conditions of the Indus Basin.

The primary objective of this Experiment Protocol is to evaluate the rheological stability and displacement efficiency of partially hydrolyzed polyacrylamide (HPAM) polymers when exposed to the high-salinity, high-temperature brine conditions characteristic of mature oil fields in the Sindh province, specifically around the Karachi and Badin districts.

As a Petroleum Engineer operating in Pakistan Karachi, it is critical to address the challenge of declining production rates in carbonate reservoirs. This protocol outlines the rigorous testing required to determine if chemical EOR methods are viable for local reservoirs, which often exhibit high divalent ion concentrations (Calcium and Magnesium) that typically degrade standard polymers.

• All personnel must wear appropriate Personal Protective Equipment (PPE), including chemical-resistant gloves, safety goggles, and lab coats.
• Work must be conducted within a certified fume hood to prevent inhalation of volatile organic compounds (VOCs).
• Spill kits specific to hydrocarbon and chemical leaks must be readily available in the laboratory.
• Waste disposal must follow the Sindh Environmental Protection Agency (SEPA) guidelines for industrial effluent.

To ensure the results are applicable to the local geology, the following materials are required:

• Core Samples: Plug samples (2.5 cm diameter, 5 cm length) extracted from active carbonate reservoirs in the Thar or Keti Bandar fields near Karachi.
• Brine Solution: Synthetic brine formulated to match the specific salinity (Total Dissolved Solids > 150,000 ppm) and ion composition of the target reservoir.
• Polymer: HPAM samples with varying molecular weights.
• Core Flood Apparatus: High-pressure, high-temperature (HPHT) core holder capable of withstanding 3000 psi and 120°C.
• Rheometer: For measuring viscosity changes under shear stress.
• Dead Oil: Crude oil sourced from the same field as the core samples to ensure wettability accuracy.

4.1. Sample Preparation

First, the core samples must be cleaned using toluene and methanol to remove existing hydrocarbons. The samples are then dried in an oven at 60°C for 24 hours. Following drying, the porosity and permeability of each core plug must be measured using a helium porosimeter. This baseline data is essential for the Petroleum Engineer to calculate recovery factors accurately.

4.2. Brine Saturation

The cleaned cores are saturated with the synthetic high-salinity brine under vacuum for 48 hours to ensure complete pore filling. This step simulates the natural water saturation found in the reservoirs of the Indus Basin. The connate water saturation (Swi) is recorded.

4.3. Primary and Secondary Recovery Simulation

Inject dead oil into the core until breakthrough occurs to establish initial oil saturation. Subsequently, perform a water flood using the synthetic brine at a constant flow rate of 1 cc/min. Continue injection until the water cut reaches 98%. This simulates the current water flooding operations common in Karachi's oil fields.

4.4. Polymer Injection (Tertiary Recovery)

Prepare the polymer solution by dissolving the HPAM in the synthetic brine. Allow the solution to hydrate for 24 hours. Inject the polymer slug (equivalent to 0.2 pore volumes) into the core at reservoir temperature (110°C) and pressure (2500 psi). Monitor the pressure drop across the core to detect any plugging or viscosity issues.

4.5. Post-Flood Analysis

After polymer injection, resume brine injection to push the polymer bank. Collect effluent samples at regular intervals to analyze oil concentration and polymer retention. Finally, extract the core and analyze the remaining oil saturation using Dean-Stark extraction.

The Petroleum Engineer must calculate the Incremental Oil Recovery (IOR) by comparing the oil produced during the polymer flood against the water flood baseline. Key metrics include:

1. Viscosity ratio of polymer solution to brine.
2. Pressure differential trends indicating mobility control.
3. Chemical compatibility results (precipitation or degradation).

The final report must assess the economic feasibility of implementing this EOR technique in the specific fields of Pakistan Karachi, considering the cost of chemicals versus the value of incremental oil production.

This Experiment Protocol provides a standardized framework for testing Enhanced Oil Recovery methods suitable for the challenging reservoir conditions found in the Karachi region. By strictly adhering to these steps, the engineering team can generate reliable data to support strategic decisions for extending the life of mature oil fields in Pakistan.