bluuebunny/crossref_metadata_2025_split huggingface dataset:
Horizontal Well Correlation Using Real Time Data and Log Prediction in Geosteering Complex Reservoirs of Saudi Arabia
Authors: Al-Maskeen Abdul Mohsen A. , Sung Roger R. , Ali Sadaqat S. 
Published: December 2013

Abstract
Real time geosteering requires a continuously updated geological model made using real time log data. Although technologies in horizontal drilling, real time monitoring, and geological interpretation have advanced significantly during the last few years, occasional conceptual gaps may occur in well plans proposed by geoscientists and engineers.
This paper presents a case study of a new workflow technology that uses real time Logging-While-Drilling (LWD) data and a new horizontal well correlation technique, to dynamically update a structural framework that can be used to geosteer an actively drilling well. Historically, well correlation approaches have been limited by the vertical well trajectory assumption even when large sections of the well were horizontal. Correlations were also typically based on 2D cross sections which did not account for apparent dip, which is an important requirement for accurate reservoir thickness calculations.
The workflow presented in this paper begins with the creation of predicted logs using an initial structural framework and well plan. The predicted logs are then correlated to the LWD logs using anchor points and an interactive stretching and squeezing technique that honors the true stratigraphic thickness. Each anchor point results in the creation of an additional pseudo-well point and inter-well control that is used to create a more precise structural framework surface.
The benefits of this new approach include faster well log interpretation, and the ability to dynamically and more accurately update the subsurface model during drilling to more efficiently steer the wellbore into the most productive parts of conventional and unconventional reservoirs. In this case study we demonstrate how wells with over 10,000 feet of horizontal reservoir contact are correlated in a real time geosteering environment to enhance the accuracy and reduce the turn-around time of updates to a structural model. A major stride in the process of understanding and modeling the heterogeneity of complex reservoirs has been achieved.
Custody Measurement Best Practices
Authors: Suwaidan Khalid 
Published: December 2013

Abstract
Custody transfer in dynamic fluid measurement is defined as a metering point location, where the fluid is being measured for sale from one party to another. During custody transfer; accuracy and precision are very important and vital to both the company delivering the material and the eventual receiver. Best practices should be made for volume calculation to get near as much as possible to the true value.
To achieve the custody transfer accuracy requirements, Kuwait Oil Company (KOC) uses turbine and PD flow meters at locations designated as custody transfer type to measure the volume of crude oil transferred from one owner to the other. There are several factors that affect the operation of these flow meters, such as the liquid temperature, the pressure in the system, density of the product dispatched, water content….etc These variables are taken into account in order to calculate the "corrected" volume dispatched which is equivalent to the raw volume reported by the flow meters affected by correction factors obtained from established formulas based on the process variables. Established procedures for calibrating and testing the equipment’s required to measure process variables with the aim of obtaining accurate and representative values, are included in various International Standards such as the API, ASTM, ISO, IP Publications.
In KOC, Export Operations (EO) Lab, which holds International accreditation (ISO) IEC 17025 and is the only accredited lab in the country, is responsible to run the analysis required to obtain the required quality values needed to obtain the Gross Standard Volume (GSV) and Net Standard Volume (NSV) of the quantities dispatched to Refineries and Export.
Salt Water Disposal System Modification During Low Water Flow Rates from Khurais Fields
Authors: Al-Juaid Mazen , Al-Muaibed Mohammad , Randall Franklin , Khan Ashiff , Al-Jubran Mustafa , Al-Doosary Awwad , Al-Shammary Sabhan 
Published: December 2013

Abstract
The Khurais Central Processing Facility (KhCPF) includes four salt water disposal (SWD) systems distributed among four oil trains. Each SWD system is comprised of one water-oil separator (WOSEP), three 33% salt water disposal pumps, and necessary piping from pump discharge, which are terminated at the water injection header. The SWD system has been designed to accommodate ultimate produced formation water (30% water cut from Khurais fields); however, due to the unexpected very low water flow rate from the fields since the commissioning period of the facility, SWD systems are encountering inconvenient operation and frequent equipment failure.
To eliminate the operational difficulties and protect the major pieces of equipment, various options were evaluated. The most optimum solution found was to divert salt water from three WOSEPs to a depressurizing vessel by pressure transfer and then recycling it back to a single train. The benefits from modification included — energy conservation by minimizing the running of salt water disposal pumps, reducing the environmental impact and huge operational flexibility for the facility — even if the water cut increases in the future. This modification is expected to be one of the best solutions for the gas-oil separation plants (GOSPs) that that are facing operational difficulties due to low water flow rates from an oil field.
This paper describes the modifications in a salt water disposal system, hydraulic assessments, HAZOP study and the field modification that are planned in the KhCPF for the recycling of salt water from the WOSEP to the depressurizing vessel.
Diagenetic Events as The Key Omprovement of Carbonate Reservoir Quality in The Senoro Field, Central Sulawesi, Indonesia
Authors: Hasanusi Deddy , Wijaya Rahmat , Priyantoro Agus , Herawati Neni , Shahab Indra 
Published: December 2013

Abstract
The Mentawa Reefal Build-up member and Minahaki carbonate sequences are the main hydrocarbon bearing reservoir of the Senoro field, in the Block Senoro-Toili, Central Sulawesi of the eastern Indonesia, especially in the Banggai- Sula basin. Carbonate reservoir of Mentawa member of Minahaki Formation commonly recognized as pinnacle reef build up type which were growth in the structural high areas and having orientations relatively northeast to southwest direction, following the tectonic setting in the areas. On the other hand, the platform carbonate which is most identified as globigerinids wackstone and globigerinids packstone facies spread out dominantly in the deeper areas enveloping the higher areas as the places of carbonate build-up (in back reef and open marine area). Combination of diagenetic events especially on the vadose zone (above water table) which are controlled by relative sea level drop and rock composition as indication of main control in improvement of the carbonate reservoir quality (both carbonate re-build-up and platform types) that initially by two events. First, presence of aggrading neomorphism / re-crystallization of the carbonate mud matrix to micro crystalline calcite (micrite) and - micro sparite that having crystal size range from 3 – 20 μ with average around 12 μ (for carbonate build-up) and 6 μ (for carbonate platform). Second, presence of intensive dissolution of both selective bioclast grains and carbonate mud matrix contents created secondary moldic, micro-macro vuggy and honeycomb porosities and it has maximum size reach-up 3.2 cm (measure from conventional core). Both re-crystallization and dissolution process was intensively well developed in the Mentawa reef build-up member of Minahaki Formation that resulted fantastically in increasing porosity and permeability value. The data measurement of routine core analysis of the carbonate reef build-up having porosity and permeability values ranges from good to excellent classes. Whereas, in the carbonate platform type, the porosity indicated good to very good classes, nevertheless the permeability value turn out to be commonly low and having a very contrast value. This condition was controlled by dominantly micro-intercrystalline and intraparticle porosity types. This phenomenon probably having relationship with composition and main diagenetic event that undergone of the both carbonate build-up and carbonate platform.
Overcoming Unconventional Gas Challenges by Creating Synthetic Sweetspot and Increasing Drainage Area
Authors: Al-Nakhli Ayman R. , Abass Hazim , KwaK Hyung T. , Al-Badairy Hameed , Al-Ajwad Hassan A. , Al-Harith Abdullah , Al-Otibi Ahmad 
Published: December 2013

Abstract
The huge resources of unconventional gas worldwide along with the increasing oil demand make the contribution of unconventional gas to be critical to the world economy. However, major challenges that operators face to produce from unconventional resources are due to the need for identifying a sweetspot, commercial stimulation technique that creates sufficient stimulated reservoir volume, very low permeability and different damage mechanisms such as water blocking, filtrate invasion during drilling, completion, stimulation or production.
This paper describes a new stimulation technique that creates synthetic sweetspot by thermal and mechanical energies. An energized fluid was used to generate localized heat and pressure in tight core samples and therefore create microfracturing. Created microfractures significantly increased permeability, porosity, and stimulated reservoir volume. A synthetic sweetspot nearby a wellbore or fracture area can be created by the new treatment mechanism. Permeability of tested cores was measured by Coreflood system and showed significant increase with new treatment technique. Communication between micro and macro pores was also found as a result of the treatment.
The treatment doesn’t utilize any hydrocarbons and have no lift overs or potential damage. The generated high temperature and pressure can remove any damaging material or condensate banking near wellbore or fracture area. The new treatment technique was evaluated using Coreflood system with actual tight core samples collected from tight reservoirs in Saudi Arabia. ESEM, NMR and CT-Scan analysis were used to show creation of microfracturing and permeability porosity changes.
The Evolution of Expandables: A New Era of Monobore Expandable Well-Construction Systems
Authors: Stringer J. A. , Farley D. B. 
Published: December 2013

Abstract
The common limitation with a casing string is its inability to maintain hole inside diameter (ID) when run through an existing casing string already installed within the wellbore. This instigated development of expandable metal tubulars to maximize the open interval below existing casing, ensuring conventional wellbore designs can be maintained as well as managing unexpected drilling hazards. With the introduction of expandable tubulars, existing wells could now be completed through the ability to include an additional casing without increasing top-hole design or compromising on the planned completion size.
Today’s industry demands further development in technology, with an ability to set a casing and run another casing string without the additional hole-size reduction experienced with conventional casing or standard expandables. A monobore solution is key to allowing operators increased control of the wellbore by isolating intervals, ensuring an efficient fluid-management system, and continuing with the existing tool assemblies. This requirement has led to the development of monobore expandable systems for intervals of the wellbore with common hole sizes of 12-1/4 in., 8-1/2 in., and 6-1/8 in.
Whether in their liner or clad form, isolating the respective interval without a loss in hole diameter provides new economies to operators when accessing deep and more complex reservoirs. Wellbores can now be engineered with contingency solutions without compromising on well objectives. Their ability to isolate intervals while not compromising on post-expansion hole size is providing operators the ability to mitigate drilling hazards, slim tophole casing designs, or increase completion diameters with minimal operational impact on their existing well plans. To date, operators have actively incorporated monobore expandable solutions to mitigate drilling hazards in Norway, Oman, Turkey, Australia, Saudi Arabia, and Azerbaijan, allowing for hazards to be overcome and well objectives achieved. This paper details design and implementation of such monobore expandable systems while providing real results on a global scale of their implementation, advantages, and operational efficiencies.
Drilling and Completion Fluids Design for Horizontal Well Drilling - Case History from Raudatain Field
Authors: Al-Ajmi Hadi Saad , Al-Ajmi Abdullah , Al-Ajmi Khalid , Al-Rushoud Abdul Aziz , Khan Yousef , Barazi Nasser Al , Merza Abdullah , Sotomayor Ghery , Jadhav Prakash 
Published: December 2013

Abstract
This paper presents drilling and completion fluids design for drilling long lateral / horizontal wells in a North Kuwait field and its field application on well RA-492, RA-493 and RA-499. The offset wells were reviewed to identify the issues from drilling a challenging trajectory through troublesome reactive formations that showed serious wellbore stability issues and stuck pipe incidents.
The customized drilling and completions fluids system was designed for different intervals, taking the following objectives in consideration: Improved hole stability through stressed and reactive formationsEnhanced hole-cleaning efficiency at critical anglesMinimized risk of stuck pipe across depleted formations with high porosity and permeabilityMinimized / no induced losses to formation by utilizing unique wellbore-strengthening techniqueMinimal damage to reservoir section during drilling phaseNear-wellbore damage remediation during completion phase
This paper describes the customized drilling and completions fluids performance as compared to offset wells. A comprehensive engineered approach addressed the challenges of drilling horizontal wells by using a revolutionary bridging technology to strengthen the wellbore and improve wellbore stability to reduce nonproductive time (NPT) related to losses, stuck pipe, etc. This paper also describes the completions fluids design to minimize reservoir damage and utilize Mesophase technology to remediate near-wellbore damage and improve reservoir producibility. The lessons learned on these wells were incorporated in drilling subsequent wells to continue improve on performance.
Confirmation of Water Saturation and Rock Fluid Properties Across the Transition Zone for a Major Carbonate Reservoir
Authors: Serry Amr Mohamed , Budebes Sultan , Al-Marzouqi Mariam , Hashimura Tadashi , Tan Willy , Ramamoorthy Raghu , Desport Olivier 
Published: December 2013

Abstract
Proper petrophysical evaluation of carbonate formations, offshore Abu Dhabi is a difficult process considering the number of challenges to resolve. Lithology mainly consists of a combination of dolomite and calcite but also contains anhydrite which must be accounted for to get an accurate porosity. Resistivity measurements are affected by invasion and by the very high shoulder bed resistivity so computing formation resistivity can only be done through resistivity modeling and inversion, and once formation porosity and resistivity are properly computed, it is possible to compute an accurate formation saturation only if the Archie parameters cementation and saturation exponents m and n are properly defined. We will show how to resolve these challenges by acquiring and integrating in an advanced workflow a modern suite of logs including density-neutron-resistivity-gamma ray along with a multi-frequency dielectric measurement. We will also show how to confirm the formation saturation in selected zone in an Archie independent manner by combining the dielectric log and pump-out formation tester. The integration of the log data with core analysis results in a very comprehensive petrophysical evaluation of the formations encountered.
Creating a Culture of Safety and Reliability in the Offshore World
Authors: Matthews Teg 
Published: December 2013

Abstract
Most organizations in the offshore oil industry have squeezed all of the performance they can get from traditional approaches to procedures, rules, and other administrative controls. Adding more programs to an already overtaxed workforce is not only undesirable and costly but can actually be detrimental to safety, environmental, and cost performance. Operators don’t need more things to do but a way to get more out of what they are already doing. Operational reliability and execution are the keys to effective performance. And this means developing a safety culture that engages people at all levels to fully commit to doing the right thing at the right time in the right way. This paper will discuss research findings that demonstrate how a strong safety culture leads to operational reliability and is the leading factor that sets the very best performers in offshore drilling apart from their counterparts.
Numerical Modeling of Polymer-augmented Waterflooding in Heterogeneous Reservoirs
Authors: Teklu Tadesse Weldu , Alameri Waleed , Akinboyewa John , Kazemi Hossein , Graves Ramona M. , AlSumaiti Ali M. 
Published: December 2013

Abstract
Waterflooding is by far the most widely used method to increase oil recovery. All petroleum reservoirs are heterogeneous with varying degree of heterogeneity. Waterflooding could be less effective in heterogonous, channeled reservoirs as injected water moves easily through the channels leaving most oil behind in unswept regions. The reservoir fractures and high permeability channels can create expeditious breakthrough pathways from injectors to producers. Polymer-augmented waterflooding can enhance oil recovery in channel-dominated reservoirs. Polymer helps to reduce high conductivity in the channels, thus diverting injection fluid to the unswept regions of the reservoir. Proper design of polymer flood should be inclusive of the entire drainage volume of the selected well clusters in order to enhance oil recovery while minimizing water cut at the producing wells.
In this study, a finite difference numerical model was formulated and implemented, using implicit pressure-explicit saturation (IMPES) and explicit calculations for polymer concentrations and adsorption effects. The implemented approach was used to study the performance of polymer-augmented waterflooding by varying relevant reservoir parameters. Both homogenous and heterogonous variations of reservoir permeability were considered with more emphasis on channeling. A Langmuir adsorption as a function of polymer concentration was used to account for the irreversible adsorption of polymer during flooding. The effect of polymer adsorption on mobility and permeability was accounted for by a viscosity adjustment and residual resistance factor formulae. With the model’s help, the proper time, to switch back from polymer injection to waterflooding, was determined by analyzing the water cut profile.
Field Specific KPI - An Innovative Approach to Drilling Performance Management
Authors: Weekse Alexander E. , Al-Mumen Adib A. , Hajji Ali A. , Muqeem Muhammad A. , Abouelnaaj Khaled K. 
Published: December 2013

Abstract
The importance of improving the efficiency of drilling operations in the E&P industry cannot be overemphasized, since it directly impacts the overall cost of constructing oil and gas wells. The key performance indicator (KPI) for measuring drilling efficiency is feet per day (ft/d).
In Saudi Aramco, a high level target KPI is normally generated separately for new development oil wells and gas wells, using a benchmark (BM) method based on actual and projected performance. The drilling teams found it difficult to relate individual well performance to the high level KPI target and were unable to properly strategize to improve performance. A new method, the field specific KPI, was developed to complement the BM method and provide a more user-friendly platform to manage performance.
Notable impacts of the new method include; improved planning, accurate monitoring of performance for prompt corrective action; and enhanced accountability and variance analysis from individual wells to fields, departments and the high level. These were demonstrated to be the prime drivers to improve performance.
This paper presents the process of generating the drilling performance efficiency KPIs using the existing BM method and the new field specific method. The scope, strengths, benefits and weaknesses of both methods are also addressed.
Profiling Pressure-Derivative Values - A New, Innovative Way to Estimate the Radii of Investigation in Heterogeneous Reservoir Systems
Authors: Rahman N. M. , Akresh Saud A. 
Published: December 2013

Abstract
The concept of radius of investigation (ROI) has been very useful in assessing the sampled volumes of reservoirs while running well tests. This is also helpful in assessing the (pressure) stabilization times of hydrocarbon units, determining draining areas, and estimating hydrocarbon reserves. Dozens of analytical formulas that are available in the literature have been dedicated to homogeneous reservoirs. However, not much has been reported on the efforts to understand how the ROI concept can be applied to heterogeneous reservoir systems. This study presents a new approach with profiling pressure-derivative values with time in heterogeneous systems to estimate the ROI.
The relationship between the reservoir permeability and the well-test derivative of the pressures measured at the wellbore has already been understood. We will introduce a similar concept to calculate the derivatives at different radial points inside the reservoir for a progressive sequence of elapsed times. By studying the profiles of the derivative values, it is possible to determine how deep the extent of the ROI is. We will also demonstrate that there exists a relationship at a given time between the derivative values at the wellbore and those inside the reservoir.
Characterisation of Hydrocarbon Fluids for Integrated Production Modelling
Authors: Kathrada Muhammad , Fuenmayor Aimara 
Published: December 2013

Abstract
Hydrocarbon fluid characterisation plays a central role in the modelling of oil and gas processes but is still an area that is not well understood. This issue becomes all the more complicated in integrated production system models as the handling of fluid characterisation differs between software packages that model different parts of the oilfield system. Ideally a characterisation methodology that respects the physical behaviour of the fluid while being versatile enough for use by all disciplines is desired. This paper examines some key fluid characterisation issues faced by Integrated Production System Modelling teams and explains how they can be addressed viz.:- modelling the C7+ (heavy) fractionchoice of matching parameters to be used in the regressionthe number of acceptable components that can be used in the compositional model