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ABOUT TAKREER » Takreer Refineries » AbuDhabi Refinery

Abu Dhabi Refinery


Following the discovery of oil in Abu Dhabi in 1958, and the first export shipments of Crude in 1962, plans were drawn up for a grass root Refinery with a capacity of 15,000 barrels per stream day (BPSD) to meet a growing local need for petroleum products. Construction work on the project began in 1973 and the Refinery, costing an initial $45 million, was inaugurated in April 1976.

So rapid was the growth in demand for oil products, however, that work began almost immediately on installing a new Refinery to process a further 60,000 BPSD and this was commissioned in 1983.

Requirements continued to grow in the fast-developing Emirate, and ADNOC decided to expand capacity yet again, with environmental considerations in mind, to include additional units for Gas Oil Desulphurization and Sulphur recovery. The expanded Refinery started up in December 1992 with a rated capacity of 85,000 BPSD.

A Salt and Chlorine Plant, commissioned at Umm Al Nar in 1981, was merged in 1990 with the Refinery to form the Abu Dhabi Refinery and Chlorine Division.

Subsequently it was permanently shutdown on 30th November, 2001. Two power plants, owned and operated by Umm Al Nar Power Company, and a Lube oil blending/filling plant, owned and operated by ADNOC Distribution, are located adjacent to the Refinery.

For more details please go through the below links

-Refinery Installations.

- Utilities.


- Marinal Terminal.

- ADR Technology.

Refinery Installations:

The Refinery is a Hydro Skimming Complex designed to process Bab Crude as well as a mixture of Asab-Sahil, Shah and Thammama Condensate.

Finished products from the Refinery are as follows :

  • Liquefied Petroleum Gases
  • Naphtha
  • Unleaded Gasoline
  • Aviation Turbine Kerosene
  • Domestic Kerosene
  • Gas Oil
  • Straight Run Residue
  • Liquid Sulphur.

Refinery units include:

Crude Distillation Unit (85,000 BPSD)
As a first step, prior to the actual distillation process, Crude Oil is passed through a Desalter Unit to remove the undesirable salts, water and sludge which are generally associated with any type of Crude. After final heating in a furnace, the Crude is then fractionated in the Atmospheric Distillation Column into the basic raw petroleum fractions of Naphtha, kerosene, Gas Oil and Straight Run Residue.

Naphtha Hydrodesulphuriser Unit (22,500 BPSD)
The Naphtha Hydrodesulphuriser sweetens the Straight Run Naphtha from Crude Unit. Three products are produced in this unit namely, Heavy Naphtha, Light Naphtha and Sour Liquefied Petroleum Gases.

Kerosene Merox Unit (21,250 BPSD)
The unit converts Mercaptans in straight run kerosene into disulphide to meet the final product quality for aviation kerosene.

Catalytic Reformer Unit (14,000 BPSD)
The Reformer processes the Heavy Naphtha cut to improve its anti-knock properties prior to using it as a Gasoline blending component. The Unit is a continuous regeneration type and does not need to be shut down periodically for regeneration of catalyst.

Gas Oil Hydrodesulphuriser Unit (22,500 BPSD)
The Gas Oil Hydrodesulphuriser Unit reduces Gas Oil sulphur content to 0.15 wt% to improve product quality.

LPG Treating and Recovery Unit (3,480 BPSD)
Raw LPG from Naphtha Hydrodesulphuriser and Catalytic Reformer Unit are processed in this unit. Butane produced is used as a blending component in Gasoline and also blended with Propane to form LPG for domestic use.

Naphtha Stabilizer Unit (3,630 BPSD)
Excess Naphtha from Crude Unit is stabilized prior to export to Ruwais Refinery.

Gas Sweetening Unit (40 tons/day H2S Removal)
Sour Gases produced in the Refinery facilities are sweetened using amine solution to remove hydrogen sulphide to minimize sulphur oxide emissions.

Sulphur Recovery Unit (40 tons/day)
The acid gases produced from Gas Sweetening Unit are converted to liquid Sulphur, which is then transported to Ruwais Sulphur Handling Terminal via Road tankers.

Jarn Yaphour Crude Oil Stabilization Plant (10,000 BPSD)

The Oil/Gas Separation Plant is designed to stabilize Crude from Jarn Yaphour Wells, located some 30 kilometers from Umm Al Nar. The separated gas is further treated to remove hydrogen sulphide, water and hydrocarbon condensate before it is injected into GASCO’s Main Gas Network. The Stabilized Crude is sent to the Refinery Crude Distillation Unit for further separation into petroleum fractions.

Additional Effluent Water Treatment facilities were installed to adhere to rigid oil in water specification of 10 ppm maximum.


The Refinery receives power and fresh water supplies from the Adjacent Plant of the Abu Dhabi Water and Electricity Authority. Steam, Air, Nitrogen and Sea Water for cooling are all provided by the Refinery's own facilities. The Refinery’s Fuel Gas supply is supplemented by Natural Gas from the GASCO Main Network.


Storage Capacity of Abu Dhabi Refinery Tank Farm is 500,000 cubic meters, which includes facilities for Crude Oil, Intermediate Streams, Semi-Finished Products, Finished Products and Utility Fuel Oil. Most of the Refined Products from Abu Dhabi Refinery are sold in the ever expanding domestic market, while the Residue and Naphtha are shipped to Ruwais Refinery.

Marine Terminal

The Refinery is served by a two-Berth Marine Terminal on the North Shore of the Island for loading and unloading of tankers. Maximum Draft is 9.5 meters; maximum Cargo is 30,000 tons.

ADR Technology

In 1994, Abu Dhabi Refinery completed the process of installing a fully integrated state-of-the-art Computerized System designed to Modernize Operations. The first level was achieved in January 1993 with the commissioning of a new Consolidated Control Room under the overall Refinery expansion project.

The Refinery is equipped with a Distributed Control System (DCS), which allowed for the introduction of an Advanced Process Control system as part of the Process Automation and Computerization project (PACS).

PACS has been designed to provide accurate and up-to-the-minute information on every aspect of the Operations in Support of Operational and Management Activities.

The second level of the project includes the implementation of Advanced Process Control (APC) strategies and off-site Automation and Computerization, while the third level involved the implementation of a plant-wide Data Base and Communications Network, leading to the use of a Computerized Decision Support System in laboratory management, Planning, Scheduling, Mass Balancing, Oil Accounting and Performance Monitoring.