bluuebunny/crossref_metadata_2025_split huggingface dataset:
Simulation Study on Surfactant-Polymer Flood Performance in Fractured Carbonate Reservoir
Authors: SayedAkram Nawaf I. , Mamora Daulat 
Published: May 2011

Abstract
This paper presents a comprehensive simulation study on the impact of natural fractures on the performance of surfactant polymer flood in a field wide scale. The simulation model utilized for the study is a dual porosity dual permeability model representing 1/8 of a 20-acre 5-spot pattern. The model parameters studied include wettability alteration, interfacial-tension changes and mobility reduction effect. The results of this study clearly indicate the importance of reservoir description and fracture modeling for a successful surfactant-polymer flood. This may lead in huge difference in reserves booking from such EOR method.
Naturally fractured carbonate reservoirs are usually characterized by mixed wettablility and low matrix permeability which leads to low oil recovery and high remaining oil saturation. Enhanced oil recovery methods such as surfactant-polymer flood (SPF) enhance the recovery by increasing the spontaneous imbibitions either by lowering the interfacial tension or altering the wettability in the matrix. However, one of the main reasons for failed surfactant-polymer floods is under-estimating the importance of the reservoir and fluid characteristics especially the description of natural fractures and their effect on recovery.
Sensitivity runs were made in field size scale in order to compare oil recovery by capillary force, buoyancy force and viscous force. The simulation study indicates a relationship between water saturation and the start of altering wettability and/or interfacial tension to maximize oil recovery. Also, when a surfactant alters the rock wettability, an optimum IFT should be identified for faster and higher imbibitions. In addition, the study shows effect on recovery by permeability contrast between that of the fracture and that of the matrix as well as fracture orientation with respect to injector-producer direction.
Automated Technology Improved the Efficiency of Directional Drilling in Extended Reach Wells in Saudi Arabia
Authors: Kragjcek Roberto H. , Al-Dossary Abdullah , Kotb Waleed , Al Gamal Abdelsattar 
Published: May 2011

Abstract
With the focus on continuous drilling optimization, a collaborative effort was implemented to analyze and assess drilling challenges encountered while drilling extended horizontal wells in the Khurais field in Saudi Arabia. The primary requirement was to enhance the efficiency of conventional downhole motor directional drilling systems in the challenging horizontal reservoir section.
The Khurais field is located in a remote area in the central part of Saudi Arabia approximately 200 km from the Saudi capital Riyadh, and 300 km from the Eastern port city of Dammam. The producer wells are drilled in the middle of the field and the water injector wells are drilled close to the field boundaries.
An average of 12 rigs worked simultaneously throughout the duration of the project to drill and complete the required increment wells. The horizontal wells are comprised of the producers, trilateral producers and power water injectors. The wells were drilled to an averaged measured depth of 14,000 ft, with an average of 6,500 ft of open hole section across the reservoir. The 6⅛" horizontal hole section is particularly challenging and is drilled with steerable mud motors with the assistance of real time geosteering and logging while drilling (LWD) tools to maintain the horizontal open hole section of the well close to the top of the reservoir within a window of 3 ft.
The fracture intervals coupled with high permeability makes the drilling of this section particularly challenging, as mud losses are frequently encountered in this section. The main difficulties to improve the efficiency of the directional drilling process were high drag and differential sticking.
To overcome the challenges mentioned above, the drilling team utilized a new sliding technology that interacts with the drilling rig top drive to break the static friction improving the weight transfer to the bit, and thereby increase the rate of penetration (ROP). Through the virtual elimination of differential sticking and reduction of buckling problems, this system smoothly helps to deliver weight down to the bit. Additional benefits of this innovative technology are the prevention of stalling of the mud-motor, steady orientation of tool face and easier steering.
The authors will describe the innovative system utilized to improve the ROP during the sliding process by almost 50% and will present real cases supported by field data. They will also illustrate the importance of post-actions review and rig crew training in the achievement of record ROP in sliding mode. Historical cases will be presented and the benefits of the application of this technology in these wells will be explained.
Surface Tension of Spent Acids at High Temperature and Pressure
Authors: Saneifar M. , Nasralla R. A. , Nasr-El-Din H. A. , Fahes M. , Hill A. D. 
Published: May 2011

Abstract
Spent acid accumulation in the wellbore area after acidizing causes severe formation damage resulting in loss of productivity. This would cause reduction of relative permeability to gas, especially in tight gas wells. Capillary forces are the key parameters that affect the trapping of spent acid in the formation. This work provides a comprehensive study of the effect of acid additives in spent acid on surface tension in tight gas carbonates. All experiments were conducted using Drop Shape Analysis (DSA) at high temperature and pressure.
Different types of commonly used acid additives including corrosion inhibitors, iron control agents, mutual solvents, methanol, acetic acid and formic acids were tested at different concentrations. Experiments were conducted at 1000 psi and temperature ranging from 25 to 150 °C.
Acid additives such as methanol and corrosion inhibitors reduced surface tension. However iron control agents, formic and acetic acids had no impact on surface tension. In addition, increasing temperature resulted in reduction of surface tension.
A unique feature of this work is that measurements were conducted at high temperature and pressure. This work contributes to the knowledge of surface tension behavior of different acid additives. Consequently, that would help in better designing the acid formulae used to enhance well productivity by minimizing capillary forces.
Drilling Solutions to Improve Performance in Deep Gas Drilling in Saudi Arabia
Authors: Nawaz Khalid , Kubaisi Abdallah A. , AbdRabAlreda Saeed H. , Verma Jaywant , Ganda Sukesh 
Published: May 2011

Abstract
Directional drilling in the deep gas fields of Saudi Arabia is very challenging because of the hard formations and harsh drilling conditions. The formations encountered are primarily hard limestone and dolomites interbedded with anhydrite. This paper describes various drilling solutions implemented in deep gas drilling. These solutions include: Successful introduction of open hole sidetrack (OHSDTR) technique to drill multilateral horizontal wells.Implementation of Powered Rotary Steerable System (PRSS) in Khuff and Pre-Khuff formations.Drilling Optimization to enhance drilling performance.
Conventionally, whipstock technique was employed for drilling dual laterals. Saudi Aramco and Schlumberger D&M jointly came up with the idea of drilling dual laterals using an OHSDTR technique to avoid complication due to whipstock failure. First successful dual lateral horizontal Khuff-C gas producer drilled with the open hole sidetrack technique, saved $975,000 and two weeks of rig time. It also helped in getting rid of time consuming whip stock operation which sometimes even resulted in loosing entire lateral due to unsuccessful whip stock retrieval.
With PRSS, the company was able to drill both vertical and curve sections in one run, maximize rate of penetration (ROP), and increase footage per bit run while meeting directional requirements. Successful development of the PDC bit in conjunction with the PRSS system led to record runs in all deep gas fields. Casing-to-casing sections were drilled with an improved ROP of approximately 97%, compared to that of a conventional motor. The integrated power section played a key role in improving penetration rate. In addition to tangible time savings, it offered benefits such as reduced tortuosity and better hole cleaning.
This paper reviews the design and optimization processes that when developed resulted in improved drilling performance, significantly reduced rig days and enabled early delivery of the wells in challenging deep gas drilling in Saudi Arabia.
A Novel 4-D Reservoir Simulation Workflow for Optimizing Inflow Control Device Design in a Giant Carbonate Reservoir
Authors: Ogunsanwo Oloruntoba , Lee Byung , Wahyu Hidayat , Leung Edmund , Gottumukkala Varma , Ruan Feng 
Published: May 2011

Abstract
The newly developed workflow is based on a 4-D sector modeling study on a west flank of Field A, offshore Saudi Arabia. The approach involves the use of time-lapse monitoring of reservoir saturation profile for injectors and producers as well as 4-D water flood front movement in the reservoir to understand dynamic reservoir challenges. These challenges are zones with future water breakthrough, dynamic injection/production interaction, impact of reservoir drive mechanism on well injectivity or productivity, initial and future reservoir conditions.
With this understanding, rate optimization process is performed on the open hole injectors and producers. Thereafter, completion is optimized to achieve uniform influx profile, flow restriction and zonal isolation where required along the horizontal section. Four different completion strategies were evaluated by alternating between Inflow Control Devices (Nozzle based) completion and open hole in injectors and producers.
Even though the sector model used in this study is subject to further calibrations as more geological, petrophysical and production data become available; the study outcome based on the novel workflow demonstrated the challenges involved in making a completion strategy with ICD's in injectors and producers. The results showed an incremental cumulative oil gain of (5%) with a one year delay in water breakthrough over a period of 20 years. It also indicated that further improvement in oil recovery can be achieved by ICD completion above that achieved in the rates optimization process of injectors and producers. The study showed a positive indication that ICD completion is beneficial in challenging reservoirs with mobility ratios considerably greater than one. The industry should consider a novel 4-D well – reservoir integrated modeling approach to making completion strategy and evaluating ICD completion design prior to deploying them in a field wide campaign.
A New Approach to Classify Microporosity in Miocene Carbonate Reservoirs of Offshore Sarawak, Malaysia
Authors: Rahman Md. Habibur , Pierson Bernard J. , Yusoff Wan Ismail 
Published: May 2011

Abstract
Microporosity can occur in grain, cement or matrix and it is related to the depositional and diagenetic history of the carbonate reservoir. Depending on the crystallometry and morphometry of micrite particles, microporosity can vary both in amount and in nature. Different kinds of micrite microtextures may produce different kinds of microporosity. This study proposes a classification of micropores and micrite microtextures. We propose a classification that includes four micrite microtextures in Miocene Carbonate reservoirs, offshore Sarawak, Malaysia. Rounded, subrounded, microrhombic and polyhedral, and compact anhedral micrites have their distinct crystal morphology and crystal contacts. This microtexture classification of micrite particles can explain the occurrence, distribution and abundance of microporosity in Miocene carbonates. Based on the crystallometry, morphometry and textural arrangements of micrites a classification scheme is proposed that includes four different classes of micropores such as very fine, fine, medium and coarse micropores with a maximum pore diameter of 0.1 to 2 micrometer, 2 to 4 micrometer, 4 to 6 micrometer and 6 to 10 micrometer respectively. Microporosity affects the empirical porosity-permeability relationship in carbonate reservoirs and influences the assessment of ultimate recovery of hydrocarbon. The application of microtextural classification of microporosity can explain the scattering of data points in porosity-permeability crossplot.
Methods of Drilling Rate Increase, Near Bit Ejector Application
Authors: Evstifeev S. , Evenko V. , Shakirov A. 
Published: May 2011

Abstract
Desired drilling depths are rapidly increasing i.e. extended reach and ultra deep drilling, thus sharply decreasing the performance of drill bits. The reason for this is the presence of porous, reservoir, and the variable total differential hydrostatic and hydrodynamic pressures that affect the conditions of rock destruction.
In Near Bit Ejector Pump (NBEP), we developed a new and innovative design based on the principle of using the kinetic energy of the liquid jet. This system reduces the differential pressure in the bit's work zone, thus result in mechanical drilling rate increase of up to 20% and more, mudding the borehole wall and preventing bit balling.
NBEP technology works in the partial loss of washing fluid zones, therefore preventing the phenomenon, moreover retaining the diameter of the hole close to desired nominal diameter. The technology is applicable to all rotary drilling, and in conjunction with hydraulic downhole motors, as well as with both tricone bits and PDC bits. This technology has been used and is still applied successfully in drilling operation of Russian and Libyan oil fields, allowing significant gains to the operating oil companies.
Step Change Technology for Running Tubulars
Authors: Davis Lance , Al-Othman Abdulaziz 
Published: May 2011

Abstract
Oil and gas well construction requires the installation of tubulars at a specific depth, prescribed for reasons of mechanics, formation pressure and wellbore integrity or accessing reserves. Deepwater construction has an additional need to also land all strings in the subsea wellhead with precision. The industry has recognized this significant problem for some time. There have many instances of failed well programs where critical depths have not been secured. A step change technology solution has been created to reduce well construction risk, applicable to all casing strings, liners and completion strings.
An elegant solution has been created with a new family of tools based upon a unique mud motor. Exceptionally, the motor can be drilled up using a normal polycrystalline diamond cutter (PDC) bit in minutes, and for any intermediate string, the cemented shoe track and motor are drilled with the next bottom hole assembly (BHA). The result is a time saving, practical, cost-effective solution which can be systematically applied to ensure all tubulars are placed on depth.
Similarly, with the advent of complex, expensive completion systems, there is an absolute necessity to land on target. An ideal solution also eliminates the need to rotate the completion string. One of the new technologies does this, and provides a gun barrel borehole right in front of the completion. Results of applying this technology are presented in this paper.
To date the technology has provided a new approach to running tubulars, and mitigating operating risk. It provides a significant boost to ensure well integrity and has clearly demonstrated the ability to recover collapsed hole and land completions across the entire reserves section, delivering an outstanding return on the technical investment.
The Technologist Development Program: Saudi Aramco's Strategy to Prepare Today's Professionals for Tomorrow's Challenges
Authors: Al-Ali Hussein , Kersey David G. 
Published: May 2011

Abstract
One of Saudi Aramco's strategic objectives is to prepare the work force to meet evolving technical challenges in Petroleum Engineering (PE). To address this important objective, the Petroleum Engineering Technologist Development Program (TDP) was established to provide the opportunity for young engineers to become recognized experts in critical technical disciplines. The TDP provides organizational support for the participants to progress in professional and managerial careers to ultimately fulfill Saudi Aramco's business needs.
The program is overseen by management and technical advisory committees. New candidates are selected based on competency, years of experience, outstanding performance and strong personal skills. In addition, they must have demonstrated technical ability, resourcefulness, and dedication to address emerging technical and operational challenges. The technical advisory committee will assist in selecting an area of specialty based on Company requirements, candidates' interests and expertise. Also, they will nominate a mentor (subject matter expert) to guide and manage development of technical and soft skills.
Each participant has a competency development road map based on a plan to develop required technical and soft skills. The participants must complete all required tasks and develop expertise in his area of specialty. In addition, the candidates are trained during rotational development assignments and, in many cases, they enroll in an advanced degree program. They need to meet specific TDP graduation requirements including publication in technical journals and active participation in international technical meetings and forums. In addition, to graduate from the TDP, a candidate is must demonstrate to the technical review committee that he has achieved technical expertise in his chosen specialty.
Saudi Aramco designed the TDP to ensure young engineers have the opportunity to become technical experts in critical specialties. The program has successfully met its goals as evidenced by the number of successful graduates.
New Approach of Water Shut off Techniques in Open Holes – and World First Applications of Using Fiber Optic Services with Tension-Compression Sub
Authors: Olarte Jorge Duarte , Haldar Surajit , Said Rifat , Ahmed Mahsoon , Burov Anton , Stuker John , Kharrat Wassim , Wortmann Henry 
Published: May 2011

Abstract
Te oil producer wells, in the southern are of Saudi Arabia, are mostly completed as horizontal open hole (OH). Some of these wells are dead or on itermittent production due to high water cut, which is caused mainly by water influx through carbonate fissures or fractures. Multiple water shut off (WSO) jobs using inflatable packers, were performed between 2005 and 2010 but failed during execution because of the packers setting failure in OH.
The WSO candidate selection process starts with reservoir and production data evaluation, then requires a coiled tubing logging run to identify the water source and adjust the required isolating fluids formulation and volume. For the execution, there is a need to control the placement, inflation, injection and disconnect of the inflatable packers in order to ensure successful WSO treatment.
This paper describes how the fiber optic enabled coiled tubing (FOECT) system, enabling realtime downhole data measurement, can optimize the WSO treatments design, execution and evaluation, and increase their success rate.
For the job design, production logging tools were run with FOECT string to detect the water source, measure the BHT required for the formulation of WSO fluids, obtain a GR log, and get an X-Y OH caliper critical to decide the best setting depth for the inflatable packer and to confirm the required WSO fluids volume.
For the job execution, the depth correlation for the packer setting was performed with the fiber optic bottom hole assembly FOBHA-GR. The inflation of the packer and the injection through it were monitored and adjusted realtime with the FOBHA-PTC measurement inside and outside the FOCT string. The confirmation of the packer setting and the release from it were confirmed with the world's first applications of FOBHA-Tension/Compression sub.
Recent production results showed previously dead well flowed at significant oil rate with 10% water cut after performing a WSO with FOECT innovative solution.
The integrated FOECT solution, eliminating engineering assumptions during the full cycle of design-execution-evaluation, is a proven WSO technique in OH, which can bring many wells back to economical production.
Enhancing Well Testing Performance by Installing a Reliable Water Cut Meter Along with Coriolis Flowmeter
Authors: Al-Mutairi Ahmed R. , Khuzzan Syed Haizir , Helal R. , Raman B. 
Published: May 2011

Abstract
This article shows the impact of installing Weatherford's online Red Eye water cut meter to work with the Micromotion Coriolis meter on the monthly well testing validity. This was applied on HwGOSP-2 test trap which is used to test the GOSP's wells on a monthly basis.
The wells' testing validity has been an issue since the installation of the new Coriolis flow meter. After several comparisons between the Coriolis flowmeter, multiphase flowmeter and the lab sampling results for more than a month, it was concluded that the coriolis was not giving accurate water cut readings, due to the variation in the well's liquids specific gravity.
This analysis revealed that specific gravity independent water cut meter is needed to be installed to work with the existing Coriolis mass flow meter. The water cut reading will be fed into the Distributed Control System (DCS) to report accurate net volumes of oil and water.
It was an opportunity to trial test the Red Eye 2G water cut meter which is using Near Infra Red (NIR) technology for real-time water cut measurement, the technology is based on NIR absorption spectroscopy, and independent of density changes. Red Eye water cut meter has been installed in the liquid leg of the test trap, to accurately measure and evaluate its capabilities of measuring the full range of water cut (0 to 100%) in a commingled oil and water stream.
The success criterion for this meter was defined as having the Red Eye data matching the lab data to a 90% confidence level. These success criteria have been met and the trial test was successfully concluded. The meter is presently operational at HwGOSP-2 since installation in April, 2010; performing to the desired results.
A New Approach to Drill Highly Depleted and Fractured Limestone Reservoir in Pakistan
Authors: Asrar Muhammad , Sabir Shahid Majeed 
Published: May 2011

Abstract
This paper presents the planning phase, operational results and future recommendations of first well drilled with Gasified Fluid Drilling technique in Pakistan.
The project's goal was to minimize non productive time associated with drilling operations and reach the target depth safely. Total loss circulation events were observed while drilling highly depleted and fractured Limestone Reservoir in Balochistan area with conventional drilling techniques in offset wells. This led to adopt technology of Gasified Fluid Drilling for very first time in Pakistan.
A multidisciplinary team planned and executed operation. Objectives were met with no downhole fire, minimal lost circulation and no formation influx. Results from this well showed significant increase in penetration rates and hole cleaning in comparison to offset wells.
This application opened new ventures and recommendations for further mature field development in Pakistan.