Challenges for integrated permeability modeling incorporating conceptual fracture model in the Jurassic carbonate reservoir in a mature oil field, offshore Abu Dhabi

2008 ◽  
Author(s):  
Haruo Kojima ◽  
Yoshihiko Umezawa Tamura ◽  
Salman Mohamed Salman ◽  
Khalid Eissa Al-Hosani ◽  
Tsutomu Masuzawa
Keyword(s):  
Carbonate Reservoir ◽  
Oil Field ◽  
Fracture Model ◽  
Abu Dhabi ◽  
Permeability Modeling

Hard Backreaming Due to Hole Shrinkage Through Carbonate Reservoir in Offshore Abu Dhabi

2021 ◽  
Author(s):  
Kimikazu Tsusaka ◽  
Tatsuya Fuji ◽  
Motohiro Toma ◽  
Kengo Fukuda ◽  
Michael Alexander Shaver ◽  
...  
Keyword(s):  
Drill Pipe ◽  
Poor Performance ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
Borehole Wall ◽  
Abu Dhabi ◽  
Root Cause ◽  
Pull Out ◽  
Time Domain Data ◽  
Operational Time

Abstract The 3,000 ft long lateral holes drilled through water-injected area in the carbonate reservoir in the offshore Abu Dhabi have been forced to implement hard backreaming. The abnormal extra operational time has been taken due to poor performance in the operation to pull out a bottomhole assembly after drilling to the total depth. The study aims to analyze root-causes of the hard backreaming through the carbonate reservoir in the studied field. The speed of tripping-out was analyzed every stand of drill pipe by using time domain data of movement of traveling block. The correlations between the speed of tripping-out and rock characteristics such as porosity and constituent minerals in rocks were investigated. Hole shape was analyzed in the representative intervals of low trip-out speed using 16-sector caliper derived from azimuthal density logging. Stress concentration around the borehole wall was also analyzed using geomechanical model. The investigation revealed that hole shrinkage due to plastic deformation of the borehole wall was the most possible root-cause of the hard backreaming in the carbonate reservoir. Namely, BHA had to ream up deformed borehole wall in tripping-out. From the viewpoint of rock characteristics, the speed of tripping-out was found to be lower in the specific geologic layers with higher content of dolomite. This is because dolomite rocks cause larger resistance in reaming it in tripping-out since the strength of dolomite rocks is larger than that of limestone. Based on our findings, use of reamers on bit is found to be the better solution to improve the tripping-out performance in the problematic geologic layers instead of conventional operational attempts such as spotting of acid and use of high viscous fluids in hole cleaning. In addition, optimization of the design and position of reamers and stabilizers is essential to succeed in the future 10,000 ft long extended-reach wells in the studied oil field.

Immiscible WAG Injection Pilots Performance and Lessons Learnt in Carbonate Reservoir. Onshore Abu Dhabi Oil Field, United Arab Emirates

2012 ◽  
Author(s):  
Hamad Abdalla Al Shamsi ◽  
Abdulla B. Al-Katheeri ◽  
Ammar Faqqas Al Ameri ◽  
Abdul Samad Abdulrahman ◽  
Kashif Sajeel ◽  
...  
Keyword(s):  
United Arab Emirates ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
Abu Dhabi ◽  
Lessons Learnt ◽  
Wag Injection

Challenges of Optimizing Oil Recovery of "Tight Carbonate" Reservoir, Onshore Abu Dhabi Oil Field, United Arab Emirates

2008 ◽  
Author(s):  
Mohamed Benlacheheb ◽  
Adib Edris ◽  
Omar Sultan Al Jeelani ◽  
Salman Hassan Al Marzouqi ◽  
Maryam Al Sheehi ◽  
...  
Keyword(s):  
United Arab Emirates ◽  
Oil Recovery ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
Abu Dhabi ◽  
Tight Carbonate

Successful Implementation of Underbalanced Drilling to Maximize Recovery from a Tight Carbonate Reservoir in an Onshore Oil Field, Abu Dhabi, UAE

2010 ◽  
Author(s):  
Tayba Abdulrahim Al-Hashemi ◽  
Adel Mohammed Al-Hammadi ◽  
Hassan Sohdy ◽  
Mostafa Haggag ◽  
Omar Sultan Al Jeelani ◽  
...  
Keyword(s):  
Carbonate Reservoir ◽  
Oil Field ◽  
Abu Dhabi ◽  
Successful Implementation ◽  
Underbalanced Drilling ◽  
Tight Carbonate

Integrated 1-D and 3-D Basin Modelling to Characterize the Deposition and Distribution of Asphaltenes Within Tar Zones from an Oil Field Offshore Abu Dhabi, UAE and Qatar

2021 ◽  
Author(s):  
Daniel Holloway ◽  
Ranald Kelly ◽  
Daniel Kay ◽  
Claire Gill ◽  
Masatoshi Ishibashi ◽  
...  
Keyword(s):  
Source Rock ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
Source Rocks ◽  
Abu Dhabi ◽  
Hydrocarbon Generation ◽  
Peak Oil ◽  
Water Contact ◽  
Bulk Fluid ◽  
Basin Modelling

Abstract Increasing the recoverable reserves from oil fields by extracting from tar zones is becoming more desirable in the Middle East. One approach for improved definition of tar zones is to understand the factors which affected the deposition and distribution of asphaltenes within the target interval. In this paper we outline how integrated 1-D and 3-D basin modelling was used to identify the timing of hydrocarbon generation and expulsion from the Jurassic source rock to charge a prolific Jurassic carbonate reservoir formation of an oil field, offshore Abu Dhabi, UAE and Qatar. The source rock is modelled to be in the peak oil mature window today, with the onset of oil generation from the Cenomanian to the Turonian, depending on modelled and assumed source rock kinetics. The onset of oil expulsion was from the earliest Paleocene. Measured bulk fluid parameters in the reservoir formation have a significantly higher Gas-Oil Ratio (GOR) and elevated API gravity values when compared with predicted values. A possible mechanism to explain this discrepancy would be to invoke the contribution of higher GOR fluids from more mature source rocks within the fetch area of the field. Thermochemical sulphate reduction of anhydrite layers in the reservoir is predicted to have begun during the Eocene. Major uplift and erosion in the Oligocene and Mio-Pliocene significantly reduced reservoir pressure and temperature. This reduction in pressure and temperature is modelled to have caused precipitation of solids, gravity segregation and flocculation at the then oil-water contact, depositing the main tar zone and patchy tar in the reservoir beneath this zone as charge continued through time. We present a detailed review, interpretation and 3-D basin model; the first study of its kind conducted on this oil field. The 3-D basin model predicts the timing of the deposition and distribution of asphaltenes in the carbonate reservoirs of the studied field and demonstrate that local problems need to be understood in their regional context.

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