bluuebunny/crossref_metadata_2025_split huggingface dataset:
How To Find Low-resistivity Pay In A Mature Oil Field - K Field Case Study
Authors: Poerboyo Savitri Mutiah , Suharya Kelik Rudi 
Published: May 2016

Abstract
Prior to 2010, all oil from the K field was produced from the Lower Sihapas Formation, where oil could easily be identified from electrical logs in these thick, high-quality sands. Then, in 2010, something unusual happened. When drilling an infill well, we noticed good oil indications from mud logs in sands above the Lower Sihapas Formation, despite the low resistivity less than 4 ohm-m. We completed the sand and it flowed 146 BOPD with zero water. This unexpected result prompted us to conduct a short two-week study to identify other candidate wells. The study consisted of: collection of mud and wireline log data in all K wells; re-running petrophysical analysis using new a, m and n values for low resistivity sands; and ranking candidate wells based on sand quality, gas readings, oil shows, initial oil rate prediction, well cost and the chance of making money.
The study identified 17 candidate wells to re-complete in the Upper Sihapas. To date, we have worked over seven wells with an oil gain of 700 BOPD and estimated incremental oil recovery of 175 million stock tank barrels. One of the worked-over wells, the one with the lowest EMV, flowed water. This paper describes the study, the resultant workover campaign and lessons learned.

Introduction
The mature K oil field is located on the western side of Padang Island in the Malacca Straits PSC, Sumatra, Indonesia as seen in Figure 1. The field has produced oil for 23 years. Current production is around 1,800 BOPD and cumulative oil production is around 64 MMSTB.
Oil is produced from the Sihapas Formation, which consists of the Lower and Upper Sihapas as seen in Figure 2. These two sandstone reservoirs have different characteristics, and are separated by thick shale. Oil production has predominantly been from the Lower Sihapas sands, which are thicker, areally extensive and have higher permeability. Oil-bearing intervals in the Upper Sihapas are generally thin, shaly, lenticular and discontinuous, with lower permeability.
This Upper Sihapas study was initiated to assess oil production potential in existing wells. This study was timely, given the oil rate decline and water cut increase in Lower Sihapas sands.
Geological Aspects of the Upper Sihapas
The Upper Sihapas formation is a massive (200–300 ft thick) body of non-calcareous, silty shale with numerous fine-grain sandstone streaks and inter-bedded sand lenses as seen in Figure 3.
Sediments within the Upper Sihapas formation were deposited in a shallow marine environment. This led to a formation water salinity of about 16000 ppm, much higher than the salinity of the Lower Sihapas formation of about 2500 ppm where the depositional environment was mainly deltaic.
The sands are mostly discontinuous, low resistivity with thicknesses less than 10 feet; though some thicker sands (10 - 15 feet) can be correlated across several K wells.
Advanced Reservoir Characterization for CO2 Storage
Authors: Al-Menhali Ali , Reynolds Catriona , Lai Peter , Niu Ben , Nicholls Norman , Crawshaw John Peter , Krevor Sam 
Published: May 2016

Abstract
Injection of CO2 into the subsurface is of interest for CO2 storage and enhanced oil recovery (EOR). There are, however, major unresolved questions around the multiphase flow physics and reactive processes that will take place after CO2 is injected, particularly in carbonate rock reservoirs. For example, the wetting properties of CO2-brine-rock systems will impact the efficiency of EOR operations and CO2 storage but reported contact angles range widely from strongly water-wet to intermediate wet. Similar uncertainties exist for properties including the relative permeability and the impact of chemical reaction on flow. In this presentation we present initial results from laboratory studies investigating the physics of multiphase flow and reactive transport for CO2-brine systems. We use traditional and novel core flooding techniques and x-ray imaging to resolve uncertainties around the CO2-brine contact angle, relative permeability, residual trapping, and feedbacks between chemical reaction and flow in carbonate rocks.

Introduction
Uncertainty around CO2 storage and EOR may be significantly reduced from a greater understanding of the fundamental physics of fluid flow and reactive transport that control rock-brine-CO2 interaction in the subsurface. The combination of unique multiphase flow properties and significant reactivity in the CO2-brine-carbonate rock system has major impacts on the injection, flow and immobilization of CO2 in the subsurface. These unique properties must be accurately characterized to reduce major uncertainties for CO2 storage and EOR in carbonate rocks. Observations of reservoir condition multiphase flow and reactive transport properties for the CO2-brine-carbonate rock system are provided including wetting properties, capillary pressure, relative permeability and residual trapping. A methodology is presented for utilizing a combination of novel and traditional core-flooding and imaging techniques for a comprehensive characterization of carbonate reservoir rock.
Uncertainty of Porosity Measurement Correlations using NMR and Conventional Logging in Carbonate Reservoirs
Authors: Al-Kharaa Hamad S. , Al-Amri Meshal A. , Naser M. , Okasha T.  M. 
Published: May 2016

Abstract
Porosity is a dimensionless parameter, defined as the ratio of pore volume filled with fluid to the bulk volume. Porosity is a critical volumetric parameter used to estimate the reserve for a given reservoir and it can be used as an input for reservoir simulation as well. In addition, porosity can be classified into two types, effective porosity (interconnected pores) and total porosity (connected and isolated pores). Total porosity is defined as the sum of effective porosity and clay bound water (CBW). In other words, total porosity obtained from conventional logging tools will be equal to effective porosity in the absence of clay and while it is not the case when clay is present.
There are several methods used to estimate porosity of the formation. These include: measuring actual porosity in the core laboratory, computerized tomography (CT) scan, neutron-density logging, sonic tools, and NMR logging tools. All conventional logging tools (neutron-density and sonic logging tools) are strongly dependent on lithology, whereas NMR logging tool is independent of lithology.
The NMR logging the most accurate compared to all other methods since it is independent of the reservoir lithology. It can be used to estimate the reservoir porosity directly without the knowledge of matrix lithology. On the other hand, conventional logging such as neutron-density and acoustic depend strongly on lithology which might yield incorrect porosity measurement. Several studies have been conducted to estimate porosity for both sandstone and carbonate reservoirs using different logging tools, however, determining porosity is a challenge in complex and unconventional lithologies. In sandstone, the presence of shale and clay minerals will affect the response of all porosity tools. Carbonate is even more complicated than sandstone due to its heterogeneity and triple porosity system (pores, vugs, and fractures). In addition, the assessment of porosity measurements accuracy using NMR logging will be considered in this study. An attempt will be made to develop an empirical correlation from NMR data to obtain reliable porosity estimation.
Thinly Bedded Reservoir Characterization, From Qualitative to Quantitative Approach, Case Studies in a Cenozoic Basin of Malaysia
Authors: Nurhono Achmad A. , Kantaatmadja Budi P. , Sing Thu Goh , Masoudi Rahim , Othman Mohamad B. , Rahman Nasir B A 
Published: May 2016

Abstract
The limit of resolution of seismic data is a complex issue that involves not only wavelet frequency, phase characters, data quality (S/N), interference, tuning, but also criteria on how to measure resolvability, which can hamper confident lithology, porosity and fluid prediction of thinly bedded reservoirs.
Widess's classic paper (1973) concluded that for thin beds (below ?/8 wavelength), the seismic character, peak/trough time and frequency do not change appreciably with thickness, and also amplitude varies almost linearly with thickness, which goes to zero at zero thickness. Thus, ?/8 of wavelength is considered to be the fundamental limit of vertical seismic resolution which depends on velocity and mainly frequency. Tirado's work (2004) revised Widess's model, which is not applicable to the real reflection, and concluded that as the bed thickness decreases, there is a gradual increase in the peak frequency, but below a certain thickness (at some fraction of tuning thickness), the peak frequency rolls off and return to the peak frequency of the wavelet at zero thickness. Thus, the key factor in determining seismic resolution is by enhancing the frequency spectral bandwidth which, nowadays, can be effectively achieved either by acquiring Broadband Acquisition or conducting Broadband Seismic Re-Processing.
We demonstrated various case studies on thinly bedded reservoirs using qualitative and qualitative techniques in a Cenozoic basin in Malaysia. The qualitative techniques involve the -90° Phase wavelets with Relative Colored Inversion, Spectral Decomposition, and ThinMAN broadband spectral inversion. The quantitative approach includes an integrated multi-disciplinary technique combining with Cascading AVO Simultaneous inversion and Stochastic Inversion calibrated with conventional and SHARP-OBMI logs, which together, significantly enhance imaging of the thinly bedded reservoirs. This unique integrated workflow has been applied in the field study, resulting in an increase of about 30% of hydrocarbon in-place volume, and has been successfully validated with available production/well data as well as newly drilled wells.
A new mapping method to assess aquifers vulnerability based on hydrogeological and seismic data - Case Study: Mio-Pliocene Aquifer in Hassi Messaoud - Algeria
Authors: Bensenane Fadia K. , Dhina Okba 
Published: May 2016

Abstract
Non renewable groundwater resources in some arid regions are the unique source of water and constitute strategic reserves for more than ever with the expected water shortage in the near future. Thus, contamination due to the infiltration of pollutants coming from oil and gas industries is one of the major risks that are jeopardizing these valuable resources.
The main purpose of this paper is to present the widespread aquifers vulnerability evaluation methods prior to introduce and discuss the new mapping method we propose for oil and gas upstream activities.
The rationale for this mapping method is linked to time of travel and the quantity of contaminants that move from the surface to the aquifer. Three key parameters are considered:Consolidation of the upper geologic layers in the unsaturated zone (C);Depth to water table (D);Aquifer Media (A).
On one hand, seismic data have been used to estimate the consolidation of the unsaturated (vadose) zone. On the other hand, hydrogeological data from almost a hundred water wells in Hassi Messaoud field in Algeria have been used to determine the hydraulic head, the static level and the local underground flow of the mio-pliocene water table.
Therefore, processed data were used for the purpose of drawing the vulnerability maps allowing a better understanding and assessment of the aquifer sensitivity to potential pollution.
This simple yet useful method is developed to be used as a decision making tool when dealing with groundwater protection in oil and gas activities.
Permeability Multiplier Prediction using 3D OBC Seismic Data
Authors: Matarid T. M. , Ibrahim K. , Ibrahem M. S. 
Published: May 2016

Abstract
This work describes an approach in characterizing fractured reservoir of upper Jurassic Carbonate using seismic azimuthal anisotropy. The ultimate objective of this study was to attempt to map permeability multiplier inter-well for the contribution to the simulation model and the subsequent development plan of an oil field offshore Abu Dhabi.
The azimuthal seismic anisotropy for fracture prediction method showed fractures that are similar to those indicated by well methods and therefore seismic can be used to detect natural fractures between wells. The confidence in the seismic fracture prediction method's ability to capture information about fracture in Carbonate reservoir has increased if the well data are accurately integrated.
The study interval exists in the dense zone of the Upper Jurassic reservoir with total thickness of 120'. The fractures evidence have been compiled from well data, such as Core, FMI, orthogonal shear sonic, production test, multi-arm caliber….etc. Present day stress is captured from induced fractures direction, borehole breakout, offset field stress map, Eocene structure map and world stress map. All compiled information's indicated maximum horizontal stress of N10°-30°E direction.
The four sectored wide azimuth seismic data set have been fitted to an ellipse to find out the fast and slow velocity direction and the difference between those velocities. The Interval Velocity is sensitive to Lithology, porosity, pore fill; the Vint-Slow is sensitive to the minimum horizontal stress. The lower the VINTslow, the less the minimum horizontal stress, which allows the fracture apertures to be more open.
It is observed that the seismic anisotropy map for fractures showed a dominated direction (NNE-SSW) that match with present day stress field. The azimuthal Vint records current day stress field, not paleo-stress field. Good correlation between well permeability multiplier and the fractures map, particularly at the two reference wells.
Following the analysis of the azimuthal seismic anisotropy maps such as azimuthal amplitude and interval velocity, a good correlation has been observed between the seismic anisotropy components and the production well test. The two seismic anisotropy components that showed a great deal of link with the computed well permeability multiplier are the computed slow interval velocity and the anisotropy azimuth deviation from the known present day stress.
Therefore, the following equation has been written to invert those azimuthal seismic components into permeability multiplier. The resulted map showed match at both input wells and one blind well.
Empowering Women in the Workforce: Leadership Roles
Authors: Yousuf Muna 
Published: May 2016

Abstract

Global general perception of leadership roles
Worldwide leadership roles are traditionally held by men. While the share of women in the workforce is increasing, it remains difficult for them to reach senior positions, which are mostly held by men. The Qatar National Development Strategy 2011–2016 seeks to increase the number of women in leadership roles by 30 per cent.

Perceptions in the GCC that have traditionally limited career advancements for women
A number of cultural, organisational and personal challenges hamper women from reaching senior positions. Women are perceived to work responsibilities. In addition, traditional views on what constitutes appropriate spheres for women's employment influence education choices for education and promote occupational discrimination.

How to promote women to leadership positions
Research and evidence indicate that the appointment of women as top managers can positively improve the performance of a company. Global corporations, conscious of the value of gender balance at all levels, are more eager to hire and promote women. Developing professional women's skills in decision-making and leadership help them realise their full potential. Examples of development opportunities include providing training, instituting career development initiatives and mentoring programs, and ensuring networking opportunities.

Sustaining continuous growth for women in leadership roles
Today, some professional women in Qatar are already in challenging leadership roles. We need to ensure that we sustain these current positions while encouraging continuous growth. [Actual paper will review statistics and demographics for GCC, and in particular State of Qatar, and how they align with the Qatar National Vision 2030 for Qatarization].
Barzan Gas Project: Clean Source of Energy Supporting Qatar
Authors: Bacon William (Bill) , Al-Kuwari Essa  Matar M. R. 
Published: May 2016

Abstract
RasGas Company Limited (RasGas), on behalf of Qatar Petroleum and ExxonMobil Barzan Limited, is in the execution phase of the Barzan Gas Project, constructing two of the largest natural gas processing trains in the world to provide the State of Qatar with natural gas and associated liquids to fuel its growing economy. At peak, more than 30,000 people from over 40 nations will work together to execute this project in a safe and environmentally responsible manner.
Natural gas -associated gas field, will be produced at a rate of 1,900 million standard cubic feet per day (mmscfd) by Barzan Gas Project offshore facilities, comprising three unmanned wellhead platforms, two subsea pipelines, and two onshore gas processing trains, all of which will be operated by RasGas Company Limited on behalf of Barzan Gas Company Limited. In addition to producing natural gas, ethane and field condensate for the domestic market, Barzan Gas Company Limited will export liquefied petroleum gas (LPG), sulphur, and plant condensate to the international market.
Against the backgrorapid rise to prominence on the world stage, broad development of its economy, industry, commercial and social systems, and the hosting of high profile international events, including the 2022 World Cup, ambitious and impressive expansion programmes are being undertaken, including a new airport, new seaport, metro and rail networks, doubling the number of hotel rooms, new schools, universities, hospitals, sports stadiums, conference and exhibition centres. Natural gas supplied from the completed Barzan facilities, a landmark development, will play a key role in supporting n and reliable source of energy from world class production facilities, and in doing so, support the four pillars of the Qatar National Vision 2030: human development, social development, economic development, and environmental development.
The Barzan Gas Project takes its name from a fortified tower built in the early 20th century located north of

Introduction
The State of Qatarexceptional economic progress is evident in the increasing standard of living of its people, sustained by major advances in economic, human and social development. From modest beginnings, Qatar is undergoing a transformation to become dynamic and vibrant economies, setting an outstanding example of how wise leadership and prudent development of its diverse rich hydrocarbon resources can successfully lead a nation on a pathway to long-term prosperity, building a dynamic 21st century economy, while maintaining its cultural and traditional values as an Arab and Islamic nation that places the family as the central pillar of society.
Development of an Online, Non-Intrusive Means for Detecting Onset of Formation Water Production in Gas Flow Lines
Authors: Mohammed Sabry A. , Aggour M. , Fraim M. , Aboegila A. , Farooqui M. , Al-Kharaz H. , Ashkanani M. , Marmoush M. 
Published: May 2016

Abstract
Production of high salinity formation water with gas presents major operational and reservoir management challenges in gas reservoirs. Early detection of unexpected water production is critical for ensuring prompt action to prevent accelerated corrosion damage in surface pipelines and facilities if they are not designed to handle the produced brine. Several methods exist for detecting water in pipelines which are based on electrical, electromagnetic, and acoustic measurements. While most of the existing methods are intrusive requiring direct contact between the measurement probe and the flow stream, all such methods suffer from low accuracy of measurements and dependence on water composition and salinity.
This paper reviews the various technologies that are in use to detect and measure water production. It also describes the theoretical background and the laboratory testing of a new means for detecting presence of formation water in gas flow lines.1–10 This work is part of a joint collaboration between RasGas Company Limited and Texas A&M University at Qatar (TAMUQ) aimed at developing a device which is: non-intrusive, clamp-on externally on the flow-line, accurate, and independent of saline water composition. This technology is based on neutron elastic-scattering and activation interactions. The laboratory testing is performed using simulated field conditions to determine the feasibility and accuracy of the measurement technique. Based on the laboratory results, a prototype device is planned to be constructed for field testing. Safety aspects of the process application both in the lab and in the field have been thoroughly examined and comprehensive safety measures have been developed and implemented per the health and safety regulatory requirements.
The paper also presents the findings from a simulation study using the Monte Carlo N-Particle (MCNP5) neutron flux simulator11 to examine the feasibility of the proposed method and to properly design and optimize the experimental setup and procedure.

Introduction
Produced fluid in gas fields consists, generally, of gas, condensate, and condensed (zero salinity) water. As production progresses, formation saline water (brine) can be produced with the condensed water. This can affect the operation and safety of the production system by accelerating corrosion and scaling potential, especially in the presence of acidic gases such as CO2 and H2S and the inorganic salts dissolved in the brine. Brine can also lead to emulsion and bacteria related problems. Therefore, it is very important to detect the presence of formation brine in the system as soon as it starts to be produced.