SPWLA Kuwait 2011/2012

    June 2012

Back to the Future with LWD Technologies and Applications

 

Presenter: Mr. Ahmet Aki

Formation and Reservoir Solutions Manager, Halliburton


Abstract:

Significant advancements in LWD Technologies and Applications have been achieved within the past two decades. The industry's vision for the future of Directional Drilling and Formation Evaluation being tightly linked has called for the rapid transformation of Open Hole Wireline technologies into drill collars. We believe that these two processes will continue to be integrated, and Wireline Logging will be more focussed on Cased Hole Applications.

In light of the increased challenges associated with locating and developing new commercial hydrocarbon reserves, the value for this integration has been realized via better Drilling Optimization, Reservoir Characterization, and Well Placement in a Real-Time environment; ultimately leading to reduction in Field Development costs.

 

This presentation will give an overview of LWD Technologies from a historical perspective, and focus on recent developments including Formation Testing and Sampling, Nuclear Magnetic Resonance and High Resolution Imaging Applications.

 

Author’s Biography:

 

Ahmet Aki is a Formation and Reservoir Solutions Manager with Halliburton in the Southern Gulf.

 

Mr. Aki has obtained his B.Sc. and M.Sc. degrees from University of Birmingham in the UK in 1981. He has worked for Schlumberger and Halliburton in field operations and management positions in West and North Africa, North America, North Sea and the Middle East, prior to moving into log analysis in 1994.

 

Mr. Aki has worked in technical and petrophysical consulting positions for both LWD and Wireline in the Middle East since 1996 and has extensive experience on products, services and interpretation techniques in petrophysical and geosteering applications with various technical publications.

 

Mr. Aki has been a member of SPWLA and SPE since 1986, currently serving on the board of SPWLA Abu Dhabi Chapter


    May 2012

Quantitative petrophysical uncertainties modeling and its impact on reserves estimates

 

Presenter: Mr. Nicolas Poete
Business Development Manager, Paradigm


Abstract:

Quantitative petrophysical interpretation leads to the estimation of reservoir properties such as clay content, porosity, saturation, permeability and hydrocarbon volumes. These properties are generally passed onto reservoir engineers for input into their 3D reservoir models to ultimately evaluate recoverable reserves.
Reserves estimates being usually presented with different probability scenarios such as P10, P50 and P90 figures, it is crucial to accurately quantify the range of uncertainties associated with the petrophysical properties. An accurate approach to model uncertainty is the key to better evaluate risks and take appropriate decisions.


We present here a holistic approach to petrophysical uncertainty that considers the true range of all unknowns for the hydrocarbon-in-place computation.

 

Author's Biography:


Nicolas Poete graduated in 1995 from IFP School with an engineering degree in Petroleum Geology. He joined CGG software branch and then Paradigm as a software support Petrophysicist.
He has 15 years' experience in Petrophysics and currently works at Paradigm as a business development manager in formation evaluation. He is a member of EAGE.

 

Petrophysics and Shale Gas Development in the Middle East - Replicating the North American Experience


Presenter: Mr. Robert Kuchinski
Wireline Business Development Manager, Middle East - North Africa, Weatherford

 

Abstract:

 

The demand for clean burning natural gas to drive the growing economies of the Middle East countries has created enormous interest in the development of Shale Gas and other unconventional resources in the region. This interest is partly a result of the successful growth of Shale Gas development in North America over the past decade. The experiences and lessons learned from North America are now being shared in every region of the world as shale gas development expands. The role of petrophysics plays a key role in understanding these resources and is critical for the success of a shale gas development. This talk will provide some insight into the impact shale gas has made on the energy markets in North America and how petrophysics plays such a key role in understanding these resources. The key learning's from the North American experience will also be discussed as a reference for developments abroad.

 

Author's Biography:


Robert. Kuchinski is the Weatherford Wireline Business Development Manager for the Middle East - North Africa region. He has been involved in the acquisition of subsurface data since 1976. During this period he has worked as a geologist in both the mining and petroleum businesses in western Canada. In 1986 he joined Reeves Wireline where he worked in various roles including technical sales, sales management, and Senior Vice President. He played a key role in the development of the Compact technology which was acquired by Weatherford in 2005. Robert is a registered professional geologist in the province of Alberta, Canada where he has worked extensively in both unconventional heavy oil deposits and Coal Bed Methane. He has authored numerous technical papers including papers on unconventional resources. He has been located in Dubai for the past 5 years in his current role.

 

 


   April 2012

A New Multi Laterolog Tool For Improved Petrophysical Models – A Case History in the Phiops Field of Egypt

 

Presenter: Mr. Thomas Glowig
Geoscience Advisor, Baker Hughes


Abstract:

 

The Multi Laterolog is a newly developed array laterolog logging device based on the Dual Laterolog principle, consisting of four independent focused measurements of differing depths of investigation with high vertical resolution. A model-based adaptive borehole correction (ABC) technique corrects the Multi Laterolog measurements for borehole effect in very conductive muds and large boreholes by solving for tool position as an unknown. This approach guarantees that in non-invaded intervals, all four laterolog curves are properly "stacked", even in large washouts, while invaded intervals show a consistent resistivity profile. The correction algorithm is very fast and is applied in real time during data acquisition. It also provides an estimate of true formation resistivity (Rt) that can be significantly higher than the deepest laterolog measurement. This results in a more accurate estimation of hydrocarbon saturation. With the addition of a micro-resistivity device, it is also possible to estimate the length of mud filtrate invasion (Lxo). Advantages of the new Multi Laterolog logging tool and advanced processing principles in combination with other wireline logging tools like the Formation Resistivity Imager are illustrated by an example from the Phiops field in Egypt.

 

Author's Biography:


Thomas Glowig is a Geoscience Advisor at Baker Hughes Geoscience in Al-Khobar, Kingdom of Saudi Arabia. He has worked for over 20 years in the Oil Field Service business.


He graduated from the Technische Universitaet Karlsruhe, Germany as Diplom Geologe, with a major in Sedimentology and Geophysics.


Thomas started his career as a wireline engineer for Dresser Atlas and served in various positions in wireline operations, management and Geoscience for Western Atlas Inc. and Baker Hughes Inc. in the North Sea, Central Europe, Africa and the Middle East.
He is a member of the Society of Petroleum Engineers (SPE).

 

Influence of Petrophysical Calibrations on Geomechanics and Resultant effects on Hydraulic Fracturing: A Case Study

 

Presenter: Mr. Satya Perumalla
Geomechanics Team Leader (Middle East), GMI/Baker Hughes

 

Abstract:

 

Petroleum Development Oman is actively developing tight gas reservoirs which include the Paleozoic Amin Formation in Northern Oman.

Natural fractures in this reservoir can be critically stressed and permeable at in-situ stress conditions, however, production may not be sufficient for commerciality. Experience from tight gas reservoirs in Oman and around the world shows that production is often only commercially feasible when such formations are hydraulically fractured.

 

The low porosities (3-10%) and permeabilities (1-0.001 mD) of this Amin formation, are reflected in the mechanical properties of the formation, with high compressive strengths (100 – 250 MPa). These high strength values limit not only fracture initiation, but also the identification of suitable intervals favorable for fracturing, which has become a critical factor for a successful stimulation program.

 

High in-situ stresses and large variability in pore pressure and rock properties are also observed at the Amin level. The pressure distribution in this area is believed to be affected by compartmentalization and faulting, which is accompanied by a significant variation in stress orientation across the major fault systems of Northern Oman, which may influence well planning strategy.

 

Geomechanical characterization of Amin using open-hole logs and conventional petrophysical techniques are seen to be inadequate for characterising this reservoir for hydraulic fracturing zone selection and design. Understanding the uncertainties in the models resulting from data inputs is the key in identifying and justifying potential intervals for fracturing.

 

This presentation discusses how core based lab tests combined with petrophysical calibrations improved the geomechanical model to identify intervals favourable for fracturing, explaining fracturing successes and failures in offset wells.

 

Author's Biography:

 

Mr. Satya Perumalla, Geomechanics Team Leader (Middle East): Satya Perumalla is working in Oil & Gas Industry as a Drilling & Geology Consultant over 15 years at different levels, supporting Well-Engineering & Geoscience interests of various operators in the Middle East, Africa and India. He is associated with Baker Hughes / GMI in Dubai since 2007 and he worked on various consulting projects linking geomechanics to wellbore stability, pore-pressure, production related reservoir changes and unconventional reservoirs. He authored SPE technical papers and also delivered Geomechanics courses. He received M.Sc (Applied Geology) degree from Indian Institute of Technology- Roorkee, India in 1994 and General Management Diploma from Indian Institute of Mangement- Ahmedabad, India in 2010. Mr.Perumalla is a member of AAPG, SPE, SEG and local SPWLA chapters.


   March 2012

Evaluating Remaining Oil Saturation in Middle East Carbonates


Presenter: Mr. Raghu Ramamoorthy
Petrophysics Advisor for Wireline, Middle East Operation, Schlumberger

 

Abstract:


As many major Middle East reservoirs mature there is increased interest in improving recovery factors and in employing tertiary recovery techniques. Proper economic assessment of EOR methods requires a very good understanding of the remaining oil saturation of the reservoirs. Due to the nature of the formations and due to the secondary recovery methods applied, there exist challenges in the assessment of the remaining oil at the end of a water flood. Several new logging methods offer solutions to these challenges. Furthermore, new technologies permit the downhole assessment of the incremental recovery from various EOR agents. This talk will present the challenges and the applications of various logging technologies to address these.

 

Author's Biography:

 

Raghu Ramamoorthy has worked with Schlumberger since 1982 in various roles such as wireline field engineer, location manager, log analyst, research scientist and petrophysicist. He is currently Petrophysics Advisor for Wireline Middle East Operations based in Abu Dhabi. He has an MS in Petroleum Engineering from U. Texas at Austin. He holds several patents in petrophysical methods and has received the Henri Doll Award and Conrad Schlumberger Award for best interpretation papers inside Schlumberger. He recently received the SPE Regional Award for Formation Evaluation. He is widely published in the SPE, SPWLA and AAPG. His current interests are Carbonate Petrophysics and EOR.

   February 2012

Probabilistic Assessment Methodology of Stock Tank oil in place (STOOIP)


Presenter: Mr. William Taylor Bryant
Senior Consultant Petrophysicist, KOC


Abstract:
Components for a successful Probabilistic assessment of STOOIP are: representative sampling, range is more important than shape, and inputs must be random. Adhere to these principles with valid log processing, simulation is easy and accurate. Perform interval reservoir summaries on all the wells for the reservoir (gross thickness, average porosity, Swirr and shale volume). The average values will be the input for the probabilistic simulation along with the bulk rock volume distribution from the geologists and the formation volume factor distribution from the engineers.


The methodology determines each output parameter from the distribution of that parameter. There is no guessing or assuming. There is no deciding whether the distribution should be triangular, normal or log normal. There is no guessing what range should be input. The input to the Monte Carlo program is the exact distribution of that input parameter.


Since the inputs are the average properties from the well logs, the well log calculations have to accurately represent the oil in place. There are three critical areas where historically large oil volumes are overlooked and are not included as oil in place. These three areas are bed boundaries, using cut offs to determine net reservoir, and reducing porosity by the shale content. The methodology used in the STOOIP calculation insures no loss of oil volume.
The distribution from the representative zones of each parameter are plotted from smallest value to largest value. The data is curve fit with a polynomial solution. This polynomial covers the exact range of data and has the exact shape of the distribution. All data used in this analysis had a correlation R^2 of 0.96 or better, an extremely good fit.

 

Author's Biography:

 

William worked for Schlumberger for 10 years as a field engineer, computing center engineer, sales engineer and service manager. After Schlumberger he worked internationally for 20 years with Amoco and BP. Since then he has consulted with a variety of major national oil companies and is presently completing seven years of service with KOC. He has several published works with SPE and has presented work at several SPWLA Topical Conferences.

   January 2012

New Innovative Techniques in Gas Monitoring Minagish Oolite reservoir, West Kuwait


Presenter: Mr. Fawaz Al-Saqran
Senior Petrophysicist, KOC

 

Abstract:


Minagish field is located in Northeast of Arabian shelf with an area of about 90 sq. km. The main producing member is Minagish Oolite consisting mainly of Oolitic limestone & accounts for over 80% of oil production in West Kuwait Oil Fields. The Minagish reservoir is currently being produced under a peripheral water injection scheme. Continuous reservoir surveillance plan is implemented to monitor Gas Cap and water front. Periodic interactive water conformance studies are conducted to analyse the surveillance data and draw conclusions about the dynamic reservoir performance. Traditional and emulation methods showed Low Sensitivity, high ambiguity and no Quantification in GOC detection.


To overcome the above limitation we implemented a high-resolution gas saturation measurement that presents a remarkably clear picture of reservoir gas, using the mineralogy, completion type, fluid density, gas pressure and density. The result shows almost three times the ability to find gas compared with traditional pulsed neutron tool. We could accurately identify smaller volumes of formation gas than before. The result provided us with the information that current gas composition within gas cap in the northern and southern sectors are different. Both gases are not in communication which means that the East-West main fault is completely sealed from top of reservoir down to Gas oil contact. Both gases are not in equilibrium with oil, whereas the northern gas gradient increases with increasing pressure, while the southern gas gradient decreases with increasing pressure.

 

Author's Biography:

 

Mr. Fawaz Al-Saqran is working with KOC as a Senior Petrophysicist in the Field Development Group of West Kuwait directorate. He has has over 10 years of experience as a Petrophysicist. After his BS in Geology from Kuwait University in 2001 he joined KOC as a Field Geologist. Mr. Fawaz has been associated with many field development studies for the Minagish Field. His interest and areas of expertise are fracture carbonate reservoir characterization, Cased hold log analysis, Geomechanics and Core Analysis. He has published several papers and attended many conferences. He is an active member of SPWLA Kuwait Chapter.