Samarang EOR

Samarang EOR Oil and Gas Field Profile

Location and Geology

• The Samarang EOR Oil and Gas Field is located offshore in Malaysia, specifically in the block known as Samarang Asam Paya. The field is situated in shallow water with a water depth of approximately 3,247 feet.
• The exact coordinates of the field are 5.618, 114.89 (WGS 84).

Operator and Ownership

• The field is operated by Petronas Carigali, a subsidiary of Petroliam Nasional Bhd (Petronas), which is the sole owner of the field.

History and Production

• The Samarang field was discovered in 1972 and production began in 1975. It has been a significant contributor to Malaysia's oil production, with peak production achieved in 1979.
• As of the current data, the field has recovered 95.21% of its total recoverable reserves. Production is expected to continue until the field reaches its economic limit in 2031, currently accounting for about 1% of Malaysia's daily oil output.

Enhanced Oil Recovery (EOR) Project

• The Samarang EOR project involves the implementation of Enhanced Oil Recovery techniques to extend the field's productive life. The project includes the alternate injection of water and miscible gas into the formation to recover more oil from the reservoir.
• Key components of the EOR project include:
  • Additional processing capacity for water pumping and gas compression.
  • Installation of new drilling centers and the drilling of new wells (22 producers, 5 water injection, and 6 gas injection wells).
  • Construction of new platforms, platform deck extensions, and new facilities such as a wellhead/drilling platform, a processing platform with gas compression and power generation, and new pipelines for water, gas, and LP gas.

Project Management and Organization

• The project follows the PCSB Project Management System (PPMS) and has passed the conceptual stage gate (MR4) in 2010. The project involves several stages including Full Field Review, subsurface model development, reservoir simulation, EOR screening, conceptual engineering, economic evaluation, detailed design, and execution.
• Schlumberger is responsible for the technical management of the subsurface, while PCSB manages the technical aspects of the facilities. Schlumberger also oversees the interface between subsurface and facilities. The operation interface is managed by a dedicated team under the alliance responsibility.

Infrastructure and Facilities

• The current field facilities include 3 processing platforms (A, B, C), 13 platforms, 39 pipelines, and an oil export system with a capacity of 150,000 bbl/day. There are also significant pipeline networks, including a 20” x 47.7 km pipeline to LCOT and a 14” x 52 km pipeline to LGAST.

Redevelopment Scope

• The redevelopment work involves the drilling of 33 new wells and the installation of new facilities, including:
  • 1 Wellhead/drilling platform combined with water processing.
  • 1 Processing Platform with gas compression and power generation.
  • New pipelines for water, gas, and LP gas.
  • Submarine infield electrical cables.

Organizational Assessment

• The project organizational assessment recommends different management scenarios, including breakdown by greenfield and brownfield work, project phases (concurrent engineering, installation, commissioning, and startup), and cluster-based approaches. Each scenario aims to optimize the project management team setup and ensure effective interface management between subsurface, facilities, and operations.