bluuebunny/crossref_metadata_2025_split huggingface dataset:
Efficient Upgrading Philosophy to manage Future Effluent Water in the Kuwait Oil Company, Greater Burgan Field
Authors: Ali Farida Mohammed , Al Wazzan Roqaya , Robinson Mike , Thawer Roxy 
Published: December 2013

Abstract
Over the forseeable future in support of the KOC 2030 strategic objectives the Greater Burgan Field will maintain its current plateau production whilst the water cut is predicted to increase from 23% to more than 60%. The requirement in any giant field is the implementation of timely upgrades to manage the required incremental gross handling capacity, reduce infrastructure complexity that will result from increasing well count and to manage investment and activity in line with the development needs.
To meet these objectives it is required to reduce the normal capital project cycle of 8 years and wherever possible, procure standard equipment to reduce complexities in the new facility upgrades which will also provide flexibilities in installation and maintenance. To meet these challenges we required a common equipment philosophy and a faster procurement strategy.
A concept was developed to modularize the upgrades into common, standard sized, skid-mounted (where possible) units to meet the increasing production system throughput and infrastructure de-congestion and combine these with long term supply contracts to manage the logistics and efficiency of rapid turn around in upgrades. This concept is already being implemented in the design and installation of remote headers and will create a step change improvement in our upgrading process when applied to the rest of the facilities upgrades.
Successful Application of Metal-Crosslinked Fracturing Fluid with Low-Polymer Loading for High Temperature Proppant Fracturing Treatments in Saudi Arabian Gas Fields — Laboratory and Field Study
Authors: Malik Ataur R. , Bolarinwa Simeon , Leal Jairo A. , Duarte Jorge , Vielma Jose R. , Soriano Eduardo 
Published: December 2013

Abstract
For the past decade, Saudi Aramco has been successfully exploiting tight gas sandstone formations. These formations are routinely hydraulically fractured to enhance gas production, but as the development of the existing fields continues into deeper formations the exploration of new reservoirs emerges. New challenges are now being faced especially, considering that higher temperature is being encountered and the fracture fluids currently being used (based on borate crosslinker) are not stable enough to tackle the extreme conditions.
Metal-crosslinked fracture fluids have long been the most popular class of high viscosity fracturing fluids. Primary fluids that are widely used are titanate and zirconate complexes of guar, hydroxypropyl guar (HPG), carboxymethyl hydroxypropyl guar (CMHPG), or carboxymethyl hydroxyethyl cellulose (CMHEC). Zirconium-delayed CMHPG are typically used for high temperature applications. These types of fluids provide high temperature stability with low polymer loading with the added benefit of salt compatibility. The proppant transport capabilities of the metal-crosslinked fluids are excellent. Zirconium-delayed CMHPG fracture fluid is currently the preferred fluids due to its extraordinary stable characteristics for bottom-hole temperatures (BHTs) up to 375°F.
This paper addresses the research, lab testing and successful application of a metal-crosslinked fluid used for fracturing operations of a high temperature (312 ~330 °F) tight gas reservoir in Saudi Arabia, with its post-treatment evaluation to optimally develop these reservoirs in harsh bottom-hole conditions.
Rapid Application of New Solution Maintained Wellbore Integrity in Fractured Carbonate Formation
Authors: Szabo Joseph J. , Clapper Dennis K. , Lewis Tom G. 
Published: December 2013

Abstract
Wellbore integrity continues to be a primary concern in drilling operations due to AFE over-runs resulting from delays, and in extreme cases, re-drills when integrity is lost. In the case of tensile failure, it is vital to have a solution that is versatile, easily prepared and quickly placed to remediate a loss-of-integrity event. A one-sack, quick mix and pump fiber pill formulation has been developed that addresses these common operational concerns. Previous field trials have shown this one-sack, rapid mix and pump material to work quickly and effectively in shale- and sand-based formations.
Recently, this material has also been shown to work successfully in fractured chalk formations. Fractured-chalk formations show many similar physical characteristics to fractured carbonates, but many differences from shale and sand-based formations. This is a great leap forward in showing the versatility and applicability of this lost circulation solution because fractured carbonates are present in many of the world’s drilling areas. Through these new trials it is now evident the material is effective across most of the physical conditions encountered worldwide. These trials also contain a new and successful utilization of calcium carbonate as a weighting agent in the formulation of the one-sack rapid mix (OSRM) pill, opening a new area of utilization for this material at lower densities. The successful use of calcium carbonate, rather than barite, also enables the OSRM pill to be further customized through the use of different, and assorted, particle sizes available in calcium carbonate grinds. In addition, it is also important to note that this one-sack, lost-circulation product has been given a green environmental rating in Norway, demonstrating high environmental compliance for most markets worldwide.
Design and Analysis of Interference Tests – Application to a Seven-Spot Inverted-Pattern Waterflood Pilot in the Wara Formation of the Greater Burgan Field, Kuwait
Authors: Gazi Naz H. , Abdulla F. A. , Al-Naqi M. , Al-Kandari I. , Dashti L. , Al-Qattan A. , Al-Farhan F. A. , Maizeret P.-D. 
Published: December 2013

Abstract
Interference testing is the oldest but still the most effective way of establishing communication between wells and determining the reservoir transmissibility. However, data can be difficult to interpret and the results can be misleading. Fortunately, simple steps can be performed to validate the data and obtain first estimates of the formation parameters. We demonstrate this methodology for an interference test performed in the Greater Burgan field in Kuwait.
A pilot project was started to understand how to successfully inject water in the Wara reservoir. Seven wells were drilled in an area away from the existing wells: one injector at the center of a 250 m-radius hexagon formed by six producers. An interference test was performed between the injector and the producers. The main objective of the study was to evaluate the transmissibility between wells and the permeability anisotropy in the formation. In five of the producers, the target sands were oil bearing, whereas surprisingly, the same sands were water bearing in the sixth well. Consequently, a second objective was added to the study: to check whether the sixth well was in communication with the other wells and to determine the origin of the water.
The tests showed that all wells responded to the pressure pulse, including the sixth well, thus refuting the assumption that a fault was isolating it. The fall-off analysis of all the wells highlighted the presence of boundaries, a finding that was consistent with the fluvial depositional environment. Moreover, the analysis showed that the channel was narrowing near the sixth well. Therefore, we could hypothesize that the sixth well had been drilled in a zone with perched water trapped by the channel boundaries. A few weeks after the test, the oil cut started to increase in that well, confirming our hypothesis.
The findings from this pilot project proved the efficiency of waterflooding as secondary recovery method and were used to design the pressure maintenance program.
Foamer Application for Sajaa Asset gas Wells
Authors: Poulose Biji , Hamadi Masoud Al 
Published: December 2013

Abstract
Sajaa gas field is one of the oldest gas fields in the Northern Emirates and Petrofac currently holds accountability for the Sajaa asset wells. This mature asset suffered from declining reservoir pressure and increased problems with liquid loading where entrained liquid dropped out in the vertical well bore, thereby restricting the flow of gas and fluids to the topside processing facility. A detailed study was conducted to understand the different techniques available for overcoming this liquid loading problem which impeded gas production rates.
After studying several methods to overcome this liquid loading issue, foamer injection was suggested for the wells which had intermittent flow patterns. The foamer application was also chosen as one of the cheapest and easiest means for overcoming liquid loading issues. Foamer treatment for Sajaa fields was initiated two years ago and a substantial increase in gas production was recorded for most of the wells with this foamer application. The foamer product selection was carried out based on modeling and subsequent lab tests. Close monitoring of well behavior to the foamer application was conducted and detailed case histories were developed for some of the wells.
A tremendous improvement in gas production rate was noted for one of the wells in Sajaa field – ‘Sajaa S-36’ (9⅝" completion). Unlike most of the other Sajaa wells, S-36 was fitted with capillary injection tubing where the foamer chemical was injected downhole through the ¼" tubing. The well performance was monitored for a period of one year and sufficient data was collected highlighting the foamer performance.
This paper presents the results of the foamer downhole injection campaign and gives an overview of the treatment methodology. An insight into the factors influencing the foamer performance, selection methods and the optimization techniques employed during the foamer injection trial are also presented.
Carbonate Stimulation with Biodegradable Chelating Agent Having Broad Unique Spectrum (pH, Temperature, Concentration) Activity
Authors: Reyes Enrique Antonio , Smith Alyssa , Beuterbaugh Aaron 
Published: December 2013

Abstract
The use of chelating agents to stimulate carbonate reservoirs has continued to increase since their first inception. A distinct chelant is presented in this paper. The new chelant is fully biodegradable and can be used in fluid formulations that specifically target the formation characteristics.
The chelating agent can be used in concentrations from 0.2 to 0.6 M, with a pH of 1, 2, or 4, and is effective from 125 to 350°F. The specific fluid composition is a function of the mineralogy and rock lithology as well as temperature. Core flow testing at less than 200°F shows optimum dissolution with low-concentration, low-pH fluid; while, at temperatures &gt;200°F, higher concentrations of chelant is optimum. The representative pore volume (PV) breakthrough curves provide an indication of the distinct reactivity of this chelant to other known chelants. Analytical characterization of the spent fluid (elemental analysis, pH) and of the core (CT imaging) are used to show that the activity in which the fluid displays on select limestone (calcite or dolomite) cores can be exploited to enhance wormhole structure generation. Core permeabilities ranged from 0.4 to 10 md, and core dimensions (radius × length) corresponded to 1- × 4-in., 1.5- × 6-in, and 2- × 6- or 10-in., respectively. The chelating fluid maintains in solution dissolved calcium, a property that is magnified because of the ease with which the acidic fluid spends as it is transported through the limestone matrix.
The concentration of the chelant can be optimized to a specific pH to maximize its dissolution capacity. Overall, the new chelating agent affords superior complexation capacity from low pH to near neutral pH values while dissolving the minimum amount of mineral and effectively increasing porosity. The chelant expands the range of available options in the area of treating fluids for carbonate stimulation.
High Resolution ChemoSteering in Drilling Horizontal Wells, Kuwait
Authors: El Gezeery Taher , Al Anezi Khalaf , Ismael Abdul Aziz , Silambuchlvan Jeevan , Latif Ahmed A. , Prakash Das OM , Padhy G. S , Estarabadi J. , Marai N. , Shoeibi A. , Khan F. 
Published: December 2013

Abstract
Advanced multilateral well drilling & completion requires the application of innovative technologies while drilling to place the well in sweet spots by managing all the geological uncertainties. The smart level-4 multilateral well with dual stacked lateral was drilled by integrating advanced Real-Time geo-steering formation characterization along with geochemical, advanced gas analysis and seismic data interpretation.The Burgan reservoir consists of vertically stacked channelsands associated with geological heterogeneities along with series of fault networks connected to the aquifer at the bottom. The reservoir contains ultra-high water mobility with down hole oil viscosity of about 40cp enhances water breakthrough and requires customized ICD and ICV completions to enhance dry oil production and maximize oil recovery. Real-time geo-steering performed on Multi-lateral well by utilizing advanced technologies including High resolution Geochemical Analysis has been utilized in Real-Time to identify "geochemical proxies" and allow geochemical steering, distance to boundary tool using 4 resistivity curves with deep spacing Geosignal, At-bit measurements and density image to correct well positioning and locating faulted areas.
The pre job planning had two components such as: (i) building a geosteering model based on offset well logs, geological and geophysical information and (ii) preparation of geochemical model based on XRF analysis of core chips from offset wells. The later model was calibrated through logs and utilized further to predict key rock attributes such as: (a) detailed lithological variations generally beyond the resolution of LWD logs, (b) detailed mineralogy to determine the diagenetic overprint and (c) depositional environment of different Burgan sand facies. Continuous interpretation and integration of XRF and petrophysical analysis supported by LWD data was a key factor for real-time geosteering operation.
Such integrated approach also resulted in successful placing the wells with maximum reservoir contact and also was very instrumental for (i) isolation of potential trouble zones, (ii) segmentation of horizontal sections and (iii) optimization of nozzle sizes of the ICDs and hence planning of smart completion designs.
Application of Bacterial Mat for Optimized Gas Hydrate Recovery
Authors: Dubey A. , Saxena A. 
Published: December 2013

Abstract
With increasing energy demand, the oil and gas industry requires new technological developments in the field of unconventional resources along with sustainable development. In this paper we put forward the concept of Bacterial Mat for optimised recovery from marine gas hydrates. Gas hydrate is a solid compound in which methane is trapped within a crystal lattice of water under high pressure and low temperature condition.
The primary condition for the stability of gas hydrate is high pressure and low temperature i.e. a minimum depth of 300m and a temperature lesser than 2°C. Several technologies have been experimented for the extraction but the main problem faced was uncontrolled liberation of methane which is a powerful green house gas.
Our suggestion is to use Bacterial Mat for the optimised recovery of gas hydrates. This bacterial mat contains Archae bacteria. These bacteria can survive in extreme environment and can produce methane from CO2 & H2O. This process is exothermic and can raise the temperature to 140°C leading to escape of methane from gas hydrates. These bacteria will breed on an artificial animal intestine mat from which they will get nutrients for growth. The bacterial mat will be sent to the seabed and fixed to the bed with its arms on the edges where gas hydrates are deposited. After achieving the desired saturation of gas, it is produced from the sea surface installation.
The above suggested methodology is an optimised and economical way to recover gas hydrates. Firstly it will help to change the focus of extracting resources from conventional to unconventional resources. Secondly, it will lead to sustainable development and reduce the hazard of global warming to a large extent. Thirdly, this technology has huge potential in the petroleum industry.
Integrated Water Management and Surveillance Strategies in a Giant Carbonate Field from Saudi Arabia
Authors: Alghazal Mohammed A. , Razally Ali M. , Alhuthali Ahmed H. 
Published: December 2013

Abstract
Excessive water production and unbalanced sweep in a water flooded reservoir can significantly impact oil production and increase water handling expenses, jeopardizing the overall economic recovery of hydrocarbon within the field. The objective of this paper is to provide a review of various integrated water management techniques successfully implemented in a carbonate field in Saudi Arabia, balanced under the critical monitoring eye of a systematic strategic surveillance program deployed to assess sweep efficiency across the field.
Complex networks of super permeable streaks and sub vertical fractures highly influencing fluid transport media within the subsurface characterize this carbonate reservoir. Understanding fluid flow mechanism in this heterogeneous gravity dominated reservoir is a predominant factor influencing the various approaches designed to manage water production in the field. The key management strategies that have been introduced are horizontal sidetracking of existing vertical wells at the top of reservoir, rigless water shut-off jobs and employing cyclic production mode for wells with very high water cut. In addition, Inflow Control Device (ICD) completion technology is being deployed within lateral sections that have encountered flow dominating geological features, such as fractures or super-K, providing a practical, innovative solution for an effective homogenized flow distribution along the lateral intervals. Collectively, these employed practices have been found successful in substantially reducing water production and improving oil recovery as supported by field data.
Concurrent with these water management strategies, sweep conformance and flood front movement are regularly monitored by conducting a rigorous Strategic Surveillance Master (SSM) plan across the whole field. The results from saturation and production profile logs confirm efficient vertical and areal sweep conformance and ensure the effectiveness of the integrated water management strategies employed in the field.
Issues of a Combination of Ultrasonic Doppler Velocity Measurement with a Venturi for Multiphase Flow Metering
Authors: Huang S. , Xie C. , Lenn C. , Yang W. , Wu Z. 
Published: December 2013

Abstract
Multiphase flowmeters (MPFMs) available today are mostly based on a combination of differential pressure measurement, provided by at least one flow constriction, such as a Venturi device, with phase holdup measurement based on nuclear techniques, electromagnetic techniques, or both. This paper investigates the issues of combining the ultrasonic Doppler velocity measurement with the differential pressure measurement for multiphase flow metering. The intention is to measure at least one "useful" velocity of the flow, such as the bulk liquid velocity or the homogeneous mixture velocity, which can then be combined with a measured differential pressure across a "constriction" device, such as a Venturi, to derive parameters needed to calculate liquid and gas flow rates. An ultrasonic Doppler velocity sensor has been tested in combination with a Venturi under multiphase flow conditions. The results show that, due to the effect of gas bubbles in the liquid phase, the interrogation depth of the ultrasonic wave is often limited to a shallow liquid region near the pipe wall. As a result, the ultrasonic Doppler sensor can measure neither the bulk liquid velocity nor the homogeneous velocity reliably. It is generally difficult to interpret the measured Doppler velocity and to derive the flow rates of a multiphase flow without employing an elaborate flow model. This work was part of a project co-funded by the UK Technology Strategy Board1, with industry partners The University of Manchester, Schlumberger Gould Research, and TUV-NEL.
Improved Permeability Prediction from Seismic and Log Data using Artificial Intelligence Techniques
Authors: Anifowose Fatai A. , Abdulraheem Abdulazeez , Al-Shuhail Abdullatif , Schmitt Denis P. 
Published: December 2013

Abstract
Accurate prediction of permeability remains the key to the determination of oil and gas reservoir quality. A number of studies have been carried out to investigate the predictability of reservoir permeability from log measurements. More recent studies have attempted to predict permeability from seismic signals. Both log measurements and seismic signals have shown to provide rich information about the structure and texture of the subsurface and hence have jointly proven to be good predictors of permeability. However, previous studies on this subject were limited to the application of Artificial Neural Networks (ANN).
With the persistent quest for more accurate predictions for more successful exploration and improved production, this paper investigates the effect of combining both seismic and log datasets with the application of more advanced Artificial Intelligence techniques on the accuracy of reservoir permeability predictions.
Log measurements and seismic signals obtained from several wells in a giant oil and gas reservoir were used to train and evaluate the performance of Support Vector Machine (SVM) and Type-2 Fuzzy Logic (T2FL) models in the prediction of permeability. The log measurements were matched with the seismic signals of the exact corresponding wells taken from 10-, 20-, 30- and 40ms seismic zones.
When compared with the long-existing ANN model, the SVM model gave the most accurate permeability predictions, with the highest correlation coefficient and the least error measures. The results also showed that a combination of seismic and log data has the potential to give more accurate permeability predictions than using either of them separately. A wider field application of the proposed techniques will give more insight, and is expected to save more time, effort and improve hydrocarbon recovery.