bluuebunny/crossref_metadata_2025_split huggingface dataset:
Quantification of Reservoir Pressure in Multi-Zone Well under Flowing Conditions Using Spectral Noise Logging Technique, Zubair Reservoir, Raudhatain Field, North Kuwait
Authors: Eldaoushy Ahmed S. , Al-Ajmi Moudi , Al-Shammari Maali , Aslanyan A. , Aslanyan I. , Prosvirkin S. , Farakhova R. 
Published: November 2015

Abstract
Monitoring the reservoir pressures throughout the production life of the field is considered as a cornerstone for reservoir management and optimization of the development plans. There are many challenges to have routine and proper pressure records. Multi-zone single completion wells are one of these challenges, where it is difficult to acquire the reservoir pressure for each zone through the conventional pressure gauges. In addition to that, deferring the production or injection of high rate wells for quite time to acquire downhole static pressure data is adding more to these challenges.
Raudhatain Zubair Reservoir is a layered reservoir with difference in reservoir pressure from layer to the other. Spectral Noise Logging technique has been utilized to estimate the average reservoir pressure for each perforated layer in a Multi-zone single completion oil producer. The noise logging survey has been carried out under flowing conditions and on different rates. The process of estimation the average reservoir pressure from Noise logging is based on quantification of the noise power under different rates. The signal recorded by SNL has two main parameters: amplitude and frequency. The frequency ranges widely from 8 Hz to 60 kHz, while the amplitude increases with differential pressure. The power of the acoustic noise signal generated by a reservoir fluid flowing from a particular unit is directly proportional to the product of differential pressure and flow rate. Nonlinear relationship between the noise power and bottom-hole flowing pressure has been utilized to estimate the average reservoir pressure which stays valid under monophasic flow conditions for the hydrocarbon to the wellbore.
The estimated pressures for each layer from this technique matched the RFT pressure data that have been recorded in the nearby wells and in also RFT data recorded in same well considering the production history. The noise profile has also indicated the effective sand thickness for each layer and investigated flow behind the casing from non-perforated reservoir to the existing perforations.
Utilization of the SNL logging to estimate the reservoir pressure is adding more to reservoir surveillance applicable tools that could mitigate some of the existing challenges and aiming to improve the surveillance process under certain circumstances.
This paper presents a case of applying the noise logging in an oil producer with the detailed job procedures, measured data, interpretation process, and the final results
Redevelopment of Brownfield in Malaysian Offshore Industry: A Cost-Optimized and Mitigated-Risk Approach
Authors: Lim Jit Sen , Muda Ahmad Ramudzan , Razali Wasli , Sidek M Saleh , Hashim Abdul Fattah 
Published: November 2015

Abstract
Brownfield redevelopment carries an amount of risk and cost (capital expenditure and operating expenditure). There will always be uncertainties on the remaining hydrocarbon in the reservoirs, and the estimated ultimate recovery. These uncertainties of production gain may undermine the economic feasibility, and restrict additional financial investment to redevelop the brownfield. This paper is a case-study of a 30-year-old brownfield redevelopment in Malaysia. The risks of redeveloping this brownfield were mitigated through subsurface studies, phased-development strategy, staged reviews, and risk sharing through alliance partnering. The costs were optimized by minimizing facilities modification, emphasizing on fit-for-purpose concept, applying low-cost alternatives, continuous improvement from lessons learnt, and having long-term plans to reduce the operating expenditure. A sustainable brownfield is defined by its ability to continue producing at an economical Unit Production Cost (UPC).
LWD Fluid Sampling, Tool Allows for Innovative Applications in Middle East Carbonate Reservoirs: A Case Study from a Gas Re-Injection Project
Authors: Al-Shehhi Noora , El-Hamawi Mohamed , Ateeq Budour , Smith Steve 
Published: November 2015

Abstract
The traditional way of acquiring reservoir fluid samples (prior to production) has usually involved running a wireline formation tester for several days or even weeks after drilling the well. This time delay between drilling and sampling has an adverse effect on obtaining high quality fluid samples because of long-term exposure to invasion. This effect becomes worse in low permeability formations where effective mud-cake build-up is poor, resulting in deeply invaded formations. In turn, this requires large volumes of filtrate to be pumped back out of the formation in order to collect low contamination reservoir fluid samples.
The ability to sample while drilling using LWD technology solves part of this problem by allowing the pump-out to start much earlier in the invasion process, thereby reducing the volume of filtrate required to pump out of the formation. In addition to cost-savings from reduced sampling time, there are other benefits to LWD sampling such as continuous circulation. This can be critical when multiple reservoirs are exposed, some of which may be depleted and pose differential sticking risks, which is often the case in the Middle East.
However, current LWD sampling technology is done with a probe which limits the inflow area thereby complicating the sampling process in low permeability formations. Many of the giant carbonate reservoirs in the Middle East are highly heterogeneous and have low average permeabilities (&lt;1-5mD) making it difficult to sample with a standard probe in many situations (LWD technology cannot overcome all the challenges just yet). But viscosity is also critical and the overall mobility of gas reservoirs can be relatively high due to the low gas viscosity, thereby making gas samples a potential application for this new LWD technology in Middle East carbonate reservoirs.
Formation pressures and fluid samples were taken from such a reservoir. In this field there is known condensate banking and the project involves re-injecting the produced dry gas into the reservoir to help maximize the condensate recovery. Seven (7) samples were collected using an LWD sampling tool, and subsequent lab analysis on the samples confirmed condensate in the reservoir. This new technology is seen as a way to help maximize recovery and minimize costs.
Efficient Systems Completion Execution; The PNG LNG Experience
Authors: Richards D.J. , Perez V. , Lee Y. 
Published: November 2015

Abstract
The positive impact of a well planned, efficient and integrated Systems Completion program has a significant focus within ExxonMobil’s project portfolio. The recent publication of API 1FSC recommended practice for Facilities Systems Completion Planning and Execution which aims to standardize terminology across the industry is an initial step towards more consistently applied and accepted processes by contractors & clients alike. This paper discusses the continuous improvement measures of a successful Systems Completion implementation process and highlights the importance of the fundamental precursors for a successful project systems completion campaign. Through proper planning and alignment with all stakeholders, a project’s overall schedule to first production can be shortened and delays and downtime due to poor quality mitigated.
The Papua New Guinea LNG Project, LNG Facility located near Port Moreseby and operated by ExxonMobil was successful in its execution. One of the major factors was the proper planning and alignment across Company Project & Operations and Contractor organizations. The Project Team and EPC Contractor leveraged & improved upon jointly established processes from previous projects to capture further efficiencies. The turnover of the PNG LNG Plant Train 1 and Train 2 facilities were achieved ahead of schedule, with minimal punchlist and full alignment with the Operations Organization.
A Case Study of Integrated Seismic and Well Statistics in Modeling of Deep Reservoirs, Abu Dhabi, UAE
Authors: Hu Jialiang , Obaid Khalid , Witte Johan , Mahgoub Mohamed , Neves Fernando 
Published: November 2015

Abstract
Previously, the deep reservoirs of Middle Jurassic (Araej Formation), Upper Permian (Khuff Formation) and pre-Khuff (Berwath Formation) age in a salt-related field offshore Abu Dhabi were interpreted to be uneconomical due to their small GIIP volume which was based on limited data from only one exploration well. However, new geological studies including basin modeling suggest a much higher potential for deep gas in this particular field. In view of the increasing demand for gas in Abu Dhabi, ADNOC has initiated the re-evaluation of a number of deep gas reservoirs using updated geological models, integrating reprocessed 3D OBC seismic and all available well data.
The major challenge in modeling these deep reservoirs is lack of well control. It is challenging to calculate statistically meaningful averages for the lateral variations in reservoir characteristics with high confidence, only based on a few wells. On the contrary, reservoir property-related seismic attributes such as RMS amplitude and acoustic impedance from post-stack inversion of the 3D OBC seismic are laterally continuous datasets, providing the database for lateral statistics. In this study, geostatistics are combined with horizontal variogram modeling based on seismic and vertical variogram modeling based on wells, which bridges the vertical-lateral gap of resolution and continuity between wells and seismic. Variogram maps rather than a single variogram model are calculated from the average seismic attribute maps, which extend statistic control of lateral continuity to 360 degrees. In addition, variograms are mapped for each fault segment separately, which honors the reservoir behavior to the maximum. Statistically, seismic attributes show a similar trend in their probability curves and vertical distribution as reservoir properties calculated from well logs. Therefore the final reservoir property models are built using co-krigging sequential Gaussian simulation with seismic-well combined variograms.
As a result, the new geological model enlarges the area of deep-gas prospectivity and locates the primary deep gas target in the Upper Khuff and pre-Khuff around the crest of this field. The re-calculated GIIP with low, average and high cases now shows an economical gas volume in these deep reservoirs.
This integrated statistics and modeling approach, combining seismic and well data reduces uncertainty in reservoir characterization with limited well data. Considering the good coverage of seismic in Abu Dhabi, this approach can be applied to the other fields with lack of deep well penetrations.
In-Situ Tectonic Stress Measurement from Wireline Straddle Packer MicroFrac Testing: A Case Study in a Carbonate Reservoir (U.A.E.)
Authors: Al Shehhi Noora Saeed , El-Hamawi Mohamed , Moronkeji Dee , Franquet Javier , Smith Steve 
Published: November 2015

Abstract
Geomechanical modeling is important to understand in-situ stresses, reservoir stress path, stress contrast, wellbore stability, solid production, integrity of cap-rock and drilling vertical and horizontal wells. The knowledge of the in-situ stresses is critical for pre-drill and post-drill well planning as well as wellbore stability prediction and is needed throughout the life of a well. The uncertainty associated with this geomechanical modeling can be critical and costly if these uncertainties are not mitigated and, to reduce this uncertainty, it is important to have a calibrated geomechanical model. One important technology that can help with reducing the uncertainty is the wireline straddle-packer microfrac tests for in-situ stress characterization. It is an important technology that helps in the measurement of in-situ formation breakdown pressure, fracture propagation pressure and fracture closure pressure. It also helps with other important hydraulic fracturing design such as fracture containment assessment, horizontal stress profile and stress contrast to stimulate tight formation shale gas or oil, water disposal wells and for OBM cutting reinjection wells.
The microfrac testing procedure uses the pressure response measured during formation breakdown, fracture propagation, fracture reopening cycles and pressure fall-off cycles for overall stress measurement and fracture closure identification. The objective of this microfrac testing was to validate and calibrate the horizontal stress profile in various intervals of the target formations. This paper focuses on the microfrac testing methodology, the geomechanical principles governing the testing, the resulting interpretation and the geomechanical modeling for horizontal stress calibration in a vertical borehole onshore Abu Dhabi.
New Insights on the Mechanical Characterization of Kerogen-Rich Shale, KRS
Authors: Hull Katherine L. , Abousleiman Younane N. , Han Yanhui , Al-Muntasheri Ghaithan A. , Hosemann Peter , Parker S. Scott , Howard Cameron B. 
Published: November 2015

Abstract
In the past decade, chemical, physical and mechanical characterization of source rock reservoirs has moved towards micro- and nano-scale analyses, primarily driven by the fact that the representative elementary volume (REV) for characterizing shales is at the nanometer scale. Nanoindentation is now widely used in many industrial and university laboratories to measure both stiffness and strength and other mechanical properties of shales, such as anisotropic Young's Moduli and plastic yielding parameters. However, to date, tensile failures of shales have not been studied at the micro- or nanoscale.
In this work, a nanoindenter is used to bring organic-rich shale (preserved Woodford shale from a well site in Ada, Oklahoma) to failure in tension. Micro-cantilever beam geometries (~25 microns in length and ~5 microns in width) were milled and loaded to failure while monitoring in-situ via scanning electron microscopy (SEM). The force-displacement curves were analyzed in light of the high resolution images collected during fracture initiation, propagation, and ultimate failure. Complementary studies of the mineralogical composition, particularly at the failure faces, as well as the organic content were also performed. Failure planes and tensile fracture initiation in the micro-beam were associated with the various phases of the mineral and organic cluster components.
The micro-beam tests of this composite natural material demonstrate linear elastic behavior followed by plastic yielding before complete failure. This behavior was clearly observed to correlate with the amount of organic matter at the fractured surface. Energy dispersive X-ray spectroscopy (EDS) analyses were conducted at the post-failure stage on the resulting fracture faces and the relationship between mechanical behavior and composition was established. It was observed that when high mineral content was found at the faces, a brittle failure took place, while when the fixed support had high kerogen content the micro-beam failed in a ductile mode.
These results reinforce our growing understanding of the heterogeneous nature of shale and the importance of nano- and micro-scale analyses to understand our reservoir source rocks.
Mapping Geomechanical State of Unconventional Shale - A More Robust, Faster Lab Characterization Method
Authors: Pérez Héctor González , Ali Syed Shujath , Jin Guodong , Dhamen Ali Abdullah 
Published: November 2015

Abstract
Unconventional shale mechanical parameters are important for many applications such as reservoir stress-state determination, horizontal drilling and hydraulic fracturing design among other engineering design parameters. These parameters include Young's modulus, Poisson's ratio, cohesion, angle of internal friction, and unconfined compressive strength. Their determination is commonly performed on single-stage triaxial (SST) compression tests using three or more core samples at various confining pressures. For unconventional shale, this has been a practical bottleneck - it is very difficult to drill multiple plugs with good quality from a whole core because of its brittleness and complexity. An alternative procedure is the multi-stage triaxial (MST) compression test, which requires only one plug to be tested. However, its main problem lies in the practical difficulty in determining the failure envelope of the sample. Judgment must be made regarding the stress-strain state "immediately prior to failure". It is not uncommon that a wrong estimation of the failure state occurs when interpreting these stress-strain curves. The MST test uses one plug, which in itself could be a significant advantage.
This paper presents a robust modified method of the MST compression test that accurately determines the imminent rock failure through continuously monitoring the radial deformation. To test and validate the method, Berea sandstone and Mancos shale plugs are selected to perform a series of the SST and MST tests. For each rock type, at least four plugs are used, which are cut from the same whole core or have similar lithofacies. Experimental results show that the Mohr-Coulomb failure envelope can be generated perfectly from both the SST and MST tests. However, the failure parameters derived from the MST tests are lower than those from the SST tests. The difference may be attributed to the intrinsic heterogeneity of rock samples or the damage accumulated from the early stages in a MST test. The proposed MST method is an efficient alternative to generate the Mohr-Coulomb failure envelope when the availability of core samples with good quality is limited, especially in the exploration and development of unconventional reservoirs.
Mentor Book Based on Infographics Demonstration for Oil and Gas Companies
Authors: Ghazo S. 
Published: November 2015

Abstract

Description
One needs the proper guidance to develop his/her potential into tangible value and a role of a competent mentor is therefore crucial in that regard. Working in an organization, like ADCO, with 8037 employees (60.4% -4855 employees- of which are UAE nationals) and targeting 75% emiratization by 2017, the need for the right mentors becomes essential.
The main goals of publishing this paper are the following:

Application

Results and conclusion

Technical contribution
Architecture, Facies Distribution and Reservoir Properties of the Mishrif Formation (Zubair Field, Southern Iraq): An Example of Integration of Seismic Interpretation with Well Data
Authors: Miraglia Salvatore , Borromeo Ornella , Maragliulo Chiara , Rodrigues Juan , Sartorio Dario 
Published: November 2015

Abstract
With the aim of building environments of deposition (EOD) maps supporting the prediction of the reservoir quality in the Mishrif Formation investigated in the subsurface of the Zubair field, sedimentary facies distribution and reservoir internal architecture were defined through integration of 3D seismic interpretation with well data (core facies, biostratigraphy, petrophysical parameters and log-derived facies obtained extending the log character of the different core facies to the non-cored wells).
The workflow comprised the sedimentological core study, the seismo-stratigraphic interpretation tied to the well stacking pattern and the environment of deposition mapping including the interpretation of attribute volumes derived from seismic inversion (porosity and frame flexibility facies volume based on the internal Eni approach CaSRC -Seismic Reservoir Characterization for Carbonates- which put into relationship the rock physic parameters to the pore structure).
Mishrif Formation consists of shallow water, bioclastic carbonates deposited in a well-developed carbonate ramp system. Geometrical evidences observed on seismic allowed to depict the evolution of the ramp passing through a main phase of aggradation, a subsequent step of progradation and, finally, a stage of aggradation-progradation. For each identified system tract, thickness maps were computed and depositional settings distributed as inner, middle and outer ramp domains. Each domain is represented by a group of facies characterized by its own configuration of porosity and pore types. Porosity is excellent in rudist bearing shoal facies deposited in the middle ramp setting and poor in mudstone and wackestones of the outer ramp. The inner ramp domain is characterized by packstone with poor to moderate porosity, improved at the very top of the Formation by diagenetic alteration associated with subaerial exposure.
Once established the relationships between facies types, environments of deposition and porosity, the EOD maps were utilized to estimate the porosity distribution within each system tract. In this view, the interpretation of the volumes derived from the seismic inversion were included in the mapping process to refine the outlining of the boundaries between depositional domains characterized by different porosity configurations.
The approach proved to be very useful in predicting the distribution of facies and related reservoir properties in areas of the field poorly controlled by well-data.
Reservoir Facies Development and Depositional Models of the Mixed Carbonate/ Clastic Asmari Formation in the Northern Margin of Dezful Embayment
Authors: Afshin S. , Lotfpour M. , Chegini A. 
Published: November 2015

ABSTRACT
The Oligo-Miocene Asmari Formation in the North Dezful Embayment of SW Iran is comprised of mixed carbonate/ clastic facies associations. The lower part of Asmari Formation is characterized by a variation of clastic facies and the upper part is dominated by carbonate shallow marine facies types. The main purpose is to investigate a regional reservoir facies changes (lateral and vertical facies variations) and also to define a relationship between sequence stratigraphy and reservoir facies quality among the three selected wells, which are located in the North magin of Dezful Embayment. During this case study, at least ten reservoir facies types were identified and classified in the study area using all available geological subsurface data. As well as, the six third-order depositional sequences (carbonate and clastic dominated cycles) have also been distinguished and correlated in the study area, representing particular sedimentary regime and relevant reservoir characteristics, which are controlled by local tectonic events and eustatic sea level fluctuations. Theses facies types directly make the significant aggraded to prograded systems tracts that can be separated by correlable surface boundaries, influenced by local disconformity events. The reservoir facies quality of these depositional sequences is drastically controlled by sedimentary regime, facies types and different diagenetic impacts on the reservoir. Local collisional tectonic events and relevant erosional features had a big role to influx the clastic sediments in the study area. The early and late diagenetic events generated the reservoir carbonate facies. The novelty of facies this case study is to define a new reservoir facies classification of the mixed Asmari reservoir stacks in the northern part of Dezful Embayment, which is affected by several influxes of the clastic sediments, multiple diagenetic events on the upper carbonate and tectonic events.