The production process train for the oil spill response system is a modular high rate offshore production testing package (HRWTP). This production process train is a part of an offshore emergency response system (cap and flow) for offshore oil and gas wells.

This base process system has been engineered and designed for 55,000 barrels per day and 100 mmscfd of process capacity.

​The design and modularity of the system adds the ability to easily upgrade flow capacity to 130,000 bpd and 200 mmscfd. The system is designed for rapid deployment and start up.

Due to the limited space on the rigs, especially with simultaneous ongoing operations, the package was designed to minimize the footprint required.

Engineering, design, construction and operation of pigging vessels and filter separators. Importance: Tier 1, # 2 job failure would disrupt Prudhoe Bay production field wide. Scope: Client was pigging the field fuel gas lines and testing the ability to switch to reservoir gas for power generation. During pigging operations, particulates may be dislodged from the pipe wall and carried by the gas to various end-user facilities. PTS installed knock-out vessels and filters at three separate locations in the FFG system to capture the particulates and liquids during the pigging process. We were also able to prove the viability of reservoir gas as an alternate fuel gas for the electric generators.

Customer required frac flowback services to separate frac sand from produced fluids and return the oil and gas into the production pipe line. PTS provided a high flow rate sand separator and personnel.

The Osprey Exploration Program was a 7 well exploration program utilizing well testing and DST to evaluate the West Fordland oil prospect in the Cook Inlet. PTS provided surface well testing and flowback equipment, DST, and personnel to cleanup and test the wells. The program started in 2000 and finished in 2004.

Oil Based Mud (OBM) flowback facilities emitted too many VOCs (volatile organic compounds). The original OBM flowback system consisted of a flowback separator operating at line pressure (~200psig). This  allowed too much gas to remain in the flowback fluid. The gas vented to atmosphere from the storage tanks caused VOC emissions in excess of permitted amounts. This caused the field to be shut in for 5 months until a new annual permit was issued.

Nitrogen was used as the lift gas, but caused each well AFE to exceed budget by over $100,000. The VOC emissions were still too high, causing the field to be shut in for 2 months of the year.

After the VRU was  placed in services, well completion AFEs were within budget, and the field operated year round.

The client recognized PTS with an award for pioneering environmental solutions.

Client required post-frac flowback services on the Vestfonn offshore stimulation vessel to remove frac proppant during well clean up, and efficiently burn the oil, to avoid oil onboard storage. PTS provided our high rate flowback equipment and a high efficiency oil and gas burner. Approximately 400 wells have had frac intervention and flowbacks. All of them were successful.

Customer required flowback and well testing services to cleanup the wells post frac treatment to prepare the wells for production. Pre-frac and post-frac data was used to determine the effectiveness of the frac treatment, and to optimize subsequent frac jobs. PTS conducted the work, utilizing a separator, heater, choke manifold, and support equipment. Special attention was given to environmental and HSEQ considerations due to the arctic conditions and vicinity to a natural sanctuary.