bluuebunny/crossref_metadata_2025_split huggingface dataset:
Plunger Lift Applications: Challenges and Economics
Authors: Hassouna Mohamed 
Published: April 2013

Abstract
A plunger lift system is an artificial lift system that provides an economical solution for producing marginalized wells. Widely used in the United States, this artificial lift method has not gained much momentum in the rest of the world. This was mainly due to difficulty in Plunger Lift operation optimization resulting from lack of automatic optimization tools. Plunger-lift has become more popular in recent years due to better mechanical reliability and flexibility of equipment, improved electronic controllers and a better understanding of the operating system.
Now a day with reliability and flexibility of equipment improvement and due to low capital & operational costs, plunger lift became the most economical artificial lift system for dewatering gas wells, stabilize the production of oil wells with liquid loading problems, reduce gas injection on intermittent gas lift wells, and prevent paraffin and scale build up.
A plunger lift system utilizes a free flowing plunger in the tubing to lift accumulated fluids. Using the wells own energy the well is intermitted allowing for pressure to build up in the tubing while the well is shut in, and once the well is turned on the plunger acts as a mechanical seal between liquid accumulated above it in the tubing and gas below it, thus preventing liquid fall back and increasing the lift efficiency.
The scope of this paper will be to discuss the different applications, and operations of today's plunger-lift systems criteria and limitations, while presenting relevant case studies.
Parallel Estimation of Surface Subsidence and Updated Reservoir Characteristics by Coupling of Geomechanical & Fluid Flow Modeling
Authors: Al-Mudhafer Wathiq J. 
Published: April 2013

Abstract
Determining of reservoir surface subsidence is a crucial problem especially for soft and unconsolidated formations. For long time production with water injection and/or water influx, the pore pressure decreases with increasing in effective stress leading to reservoir compaction and vertical surface subsidence. In this paper, a Tank Capacitance-Resistive Model (TCRM) has been done to estimate the history of vertical subsidence in the upper sandstone member/main pay of South Rumaila oil field in Iraq. It is a mature oil field with around 58 years of production with 40 producing wells and it has also 20 injection wells located only at the east flank. The average surface area for this reservoir is 142 km2. The reservoir is modeled considering an infinite acting aquifer at the east and west flanks. A commercial reservoir simulator has been adopted parallel with the Tank Capacitance-Resistive Model to estimate the subsidence in very active aquifer. The Carter-Tracy water influx model has been adopted to calculate the water influx rate. The TCRM depends on the concept of continuity equation that considers the difference between the water injection and oil production as reservoir input and output, respectively. So, the simulator calculates the total water injection rate and water influx to be treated as water injection in the continuity equation.
The results demonstrated that reservoir formation has plastic deformation because it has recurrence subsidence in the reservoir thickness. The current subsidence for this reservoir in the current time after 58 years of predict is 1.5 ft at the crest of the reservoir and it is approximately close to the local subsidence at each grid in the reservoir crest.
Developing Realistic Depletion Plan of Senoro Field using Coupled Reservoir - Surface Network Simulation
Authors: Suwono Sugiyanto Bin , Wijaya Rahmat , Masbudi Herryadi , Muttaqin Muttaqin , Prasetyo Hadi 
Published: April 2013

Abstract
Based on current approved development plan of Senoro gas field, the field will be produced at rate 300 MMSCFD (net) to fulfill the gas demand. Existing study based on black oil reservoir simulation conducted on developing depletion plan of Senoro Field give an unexpected result of plateau time which is only 11.7 years while the field has gas delivery contract for 13 years. This possibility of shortfall gas tends to risk the company to get a penalty as termed in the contract.
Further analysis of the existing development plan also shows that the gas depletion plan is not yet optimal. It is indicated by the unbalance recovery factor between southern and northern reservoir area as it is shown by a significant difference of its reservoir pressure at the end of contract year. Furthermore, the design of production network planned for Senoro Field also indicating huge pressure losses will be encountered by the southern area wells.
To solve the problem, a new study has been conducted to optimize the development plan. The method used in this study is dynamic coupling simulation by connecting reservoir simulation and surface network system into a single package of simulation run. This study has successfully optimized the Senoro field depletion plan to achieve the target 13 years of plateau time. Strategies used to achieve the target are by rescheduling well, utilizing pressure booster in southern area, installing gas compressor after 9th years of production, introducing horizontal well S-22hw to substitute well S-22, and reducing the number of well to 19 from the original plan of 21 wells.
Introducing a Producible Oil Water Contact (POWC) for Better Assessment of Moveable Oil in the Transition Zone
Authors: Doerband Robert 
Published: April 2013

Abstract
An exploration campaign of RWE Dea AG has discovered several oil fields in carbonate reservoir layers. Log analysis shows that most of the wells have a very long transition zone above Oil Water Contact (OWC). The lower part of the oil column above OWC contains significant amounts of non-producible oil. The length of this zone may falsify the economic significance of the oil column, which appears as too large.
An additional hydrocarbon contact is defined and named „Producible Oil Water Contact - POWC". The differentiation between moveable and unmoveable oil in the transition zone helps to identify and assess the producible oil in a more appropriate way. This level may be determined by using fractional flow curves. In this case the contact level is a derived value for water saturation that relates to a specific water cut at surface conditions. If dynamic reservoir modeling is available the POWC can be also determined based on 3D-simulation results, at the lowest level where oil begins to flow.
In order to comply with the industry standards for definition of OWC the methods available will be discussed and it will be verified if the newly introduced POWC fulfills common best practice and can be used as supplement.
The effect of applying the POWC on oil-in-place calculations and recovery factor is shown with an example for application in reservoirs with long transition zones. It is aimed to concentrate resource calculations to the levels with economically producible oil, in order not to artificially inflate oil-in-place volumes and keep recovery factors reasonable. Furthermore, improved contour mapping based on new POWC can help to find locations for wells with better oil productivity.
Effect of Capillary Pressure on the Numerical Simulation of Conventional and Naturally Fractured Reservoirs
Authors: Shams M.. , El-Banbi A. H. , Khairy M.. 
Published: April 2013

Abstract
Engineers involved in numerical reservoir simulation studies typically use capillary pressure for model initialization. However, the effects of capillary pressure on reservoir performance may not be fully understood for different drive mechanisms.
The aim of this work is to show the effect of both oil-water and gas-oil capillary pressures on reservoir performance for reservoirs producing under natural depletion, water injection, and gas injection recovery processes over a wide range of reservoir and production parameters. Both conventional and naturally fractured reservoirs are studied.
For fractured reservoirs, both matrix and fracture capillary pressures effects were investigated when capillary pressure imbibition is the only drive mechanism and when both capillary pressure imbibition and gravity drainage recovery mechanisms are active together. To quantify this effect, simulation results of large and small transition zones were compared with models of zero transition zones and three difference indicators were calculated for each run. Hundreds of runs were made to quantify these effects in a variety of reservoir heterogeneity levels.
It was found that capillary pressure effects are different for different recovery processes. While capillary pressure is usually important for initialization, it may not be as important during flow calculations in every situation. Capillary pressure was more important in depletion runs than in most displacement runs. No clear correlation exists between capillary pressure effects and the level of reservoir heterogeneity. It was also found that fracture gas-oil capillary pressure effects increase in certain conditions for naturally fractured reservoirs. A real reservoir model was also used to confirm the results obtained from hypothetical models and validate the study conclusions. Finally, guidelines were developed to show when capillary pressure was important and when it can be ignored.
Overcoming the Typical Operational Problems & Cost of Water Injection Using Dumpflooding
Authors: Helaly Rami , Bekheit A.. , Farahaty M.. , Tawfik M.. 
Published: April 2013

Abstract
Meleiha North East oil Field is located in the Egyptian Western Desert. Its estimated value for the OIIP is 125.5 MMSTBO. The field started production in the year 1986 and was subjected to 4 years of natural depletion. The reservoir mainly consists of three producing layers; all are heterogeneous with local poor horizontal connectivity and low natural pressure support. Consequently, and during that period of natural depletion, the recovery of only 14.7 MMSTBO caused the reservoir pressure to decline from an initial value of 2300 Psi to 1000 Psi; a slope of approximately (-325 Psi/year). After applying water-injection in the year 1990, the pressure decline-slope got reduced to (-30 Psi/year). Currently the field contains 27 producers and 3 injectors. The distance to the nearest water-source well is approximately 10 Kilometers.
Maintaining continuous injection remained a challenge due to the typically associated operational problems; the long length of the injection lines increased the frequency of line leakage, corrosion, and blockage. Both water-source and injection wells require regular maintenance operations to handle problems such as casing leaks and ESP's maintenance. The necessity of flushing the injection lines after each operation results in additional time losses. Other problems maybe related to issues with the injection plant. All of these operational difficulties eventually affect the reservoir pressure performance and consequently decrease the production performance.
As an attempt to improve the performance of water injection, a dump-flood project was initiated. The idea is based on using the pressure differential between the perforated intervals within a single well to drive the water coming from a relatively high pressure water-bearing zone to a lower-pressure oil-bearing zone(s). Well NE-41 was initially drilled as water injector. The RFT measurements indicated that the pressure in three oil bearing zones (B-I, III & IV) averaged around 400 Psi, while the pressure in a water-bearing zone (B-VI) was found to be 2250 Psi. Hence, the well was selected to be a pilot for dumpflooding. After completing the well as planned, a PLT was performed and its results indicated that the water-bearing zone produced 1100 BWPD that were distributed among the three recipient zones. The project therefore was considered successful for the following reasons: Avoiding all the typical operational problems such as surface leakages, casing leakages, and ESP's maintenance,Providing a minimum cost for supplying the reservoir pressure by water injection.
Downhole Testing Tools in Extreme Hostile Environments: HP/HT Offshore Well - Northeast Brazil
Authors: Marcançola Fernando , Pontes Thiago , Adriano Marcio 
Published: April 2013

Abstract
Hydrocarbon production and exploration has ventured into deeper, more hostile environments, and this change has required continual operational change to enable operators to address the challenges presented by the more hostile environments into which exploration has now moved. Testing technology has had to redefine the operating envelopes for its scenario to meet the requirements presented by the more extreme conditions in the newer environments. Not only high-pressure and high-temperature tools have been needed, but tools that are more debris-tolerant have been needed as well.
This paper discusses the application of downhole testing tools in formation evaluation jobs in extremely hostile environments; these include testing in such conditions as: Ultra-deep waterExtreme high-pressureExtreme high-temperatureDebris presence.
Case history information will also be presented where a downhole testing operation was performed in a high pressure and high temperature offshore well northeast of Brazil.
The definition of ultra-deep water is when wells have at least 10,000 feet of water depth, and HP/HT well environments include those with bottomhole pressures above 10,000 psi and bottomhole temperatures above 300° F. When environments have bottomhole pressures above 15,000 psi and temperatures above 350° F, the wells are considered as extreme HP/HT.
Many testing operations have been severely challenged by these scenarios as downhole tools available for standard projects only could function efficiently to approximately 350° F and up to 10,000 psi of pressure. Now, special tools are available for conditions with temperatures of up to 450° F and 30,000 psi of hydrostatic pressure with maximum 15,000 psi of differential pressure. To function in higher pressures and temperatures, the drill-stem test (DST) string design should meet its capabilities and scenarios variation should be considered.
The addition of these tools has enabled high-quality well testing to be performed safely, and when the tools are used in wells where solids problems are not anticipated and unexpected debris does occur, they can avoid the unexpected rig time previously required to clean the well, further enhancing economic efficiency. Debris-tolerant tools also have allowed fracturing and acid operations to be performed with a test string, and with the same string, the well can be opened to a well-testing operation without compromising the functioning of the downhole tools. This capability saves time and adds economic value to the job.
This paper also discusses how formation evaluation jobs now can be performed satisfactorily in extremely hostile wells using the improved technology and the best practice information that has now been gained concerning testing in in this type of scenario.
Permanent Magnet Motor application for ESP Artificial Lift
Authors: Refai Ahmed , Abdou Hesham A.M. , Seleim Ahmed , Biasin Giovanni , Reda Walid , Letunov Dmitry 
Published: April 2013

Abstract
The majority of Western Desert wells (Agiba Petroleum Company) are completed with artificial lift systems and several kind of pump: ESP, Sucker Rod, PCP (about 40 ESP, 250 Sucker Rod and 10 PCP). A new technology - Permanent Magnet Motor (PMM) - has been developed for ESP motors as alternative to conventional asynchronous induction motor in the last years. PMM is synchronous motor in which the stator manufacturing technique is similar to that of conventional asynchronous motor, but rotor has permanent magnets (instead of copper winding). PMM has more benefit of conventional induction motor: high efficiency (90 94%) vs. induction motors up to 86%; smaller size and weight; wider ranges of rotation frequency regulation (100-1000, 1000-4200 and 3000-6000 r.p.m.); reduced energy consumption and rating of surface equipment (Power Saving); stable torque over wide operation range; Power factor is near to 1; lower specific heat release due to higher efficiency. Also indirect benefits are: a) low heat release (minimum cooling fluid velocity 0.05 ft/s); b) less size for cable and lower power rating for transformer and VSD; c) decreased reactive power; d) improved system Power factor. All Agiba ESP wells are equipped with conventional induction motor. In the middle of June of 2012 Agiba performed a trial installation of Novomet PMM replacing an ESP unit with induction motor on well North Nada 1 x (oil well - Qg =315 BFPD, Qn=173 BOPD) of North Nada field. The installation was successful achieving the expected results and benefits in term of low power consumption. Successful key point: keeping electrical system stability and minimize the number of shutdowns; minimum cost for power consumption and production.
Moving Towards Innovative Waste Water Treatment and Disposal Technologies: Field Study for In Situ Waste Water Treatment and Evaporation Technology
Authors: A. Moati Wael Hamed , Ibrahim Shaban 
Published: April 2013

Abstract
Produced waste water in oil and gas fields is a chronic headache from operational and HSE points of views. Many companies spend a lot of efforts and money to seek for the best produced water treatment and disposal. Whatever the technology applied; the main scope is to treat water and dispose it respecting the specifications imposed by the environmental affairs agency. However; this isn't the end of the story where the water disposal itself into water bodies or disposal wells can trigger in serious problems if water hasn't been treated well. Other companies -due to limitation of their existing waste water treatment plant capacities-are forced to trucking solution to transfer untreated water to other waste water plants operated by service companies.
In situ water treatment and evaporation of waste water is an innovative solution that allows to get rid of produced waste water in a safe and economical matter. The paper introduces a field study carried out in gas processing plant "El Gamil plant" located at Portsaid city on the Northern east coast of Egypt. The waste water production of the producing gas fields increased from 500 m3/d to about 3,000 m3/d. The existing waste water treatment plant capacity was limited to 500 m3/d, the matter that implies to seek for further solutions to avoid trucking option. In situ water treatment and evaporation was selected to apply in a pilot project with capacity of 500 m3/d to expand it in case of successful implementation.
The results show that technology is reliable but in certain applications and sites. In particular; if the oil content of the waste water is in the form of free phase where the water treatment will be based on physical separation in settling tanks and oily water separator to remove the oil phase and dispose water in to atmosphere using atomizers.
The paper will study with the parameters that can affect the success of this process highlighting the appropriate conditions for its applications.
Production Enhancement in the Egyptian Western Desert using the Channel Fracturing Technique – A Field Case Study
Authors: Samir M.. , Kamal M.. , Mathur A.. , Semary M.. , Yosry M.. , Bernechea J. M. , Kamar A.. , Mokhtar A.. 
Published: April 2013

Abstract
The Abrar field in the Egyptian Western Desert produces mainly from the Abu Roash formation that is characterized as a complex, thin-bedded sequence with heterogeneous laminated siltstones. Hydraulic fracturing has traditionally been employed to produce hydrocarbons from these marginal reservoirs. This paper describes the application for the first time of a novel channel fracturing technique combined with rod-shaped proppant in selected production targets in the Abrar field. The channel fracturing technique introduces channels within the proppant pack that increase conductivity and effective half-length leading to increased productivity. Rod-shaped proppant when used as tail-in in fracturing treatments increases near-wellbore fracture conductivity and prevents proppant flowback due to its particular geometry.
Many sedimentary features of hydrocarbons in the Western Desert in Egypt are characterized as multi-layered, deltaic, thinly and tight laminated sandstones and siltstones consisting of sands with limited lateral and vertical extension with an average permeability of 1-3 mD and Young's modulus in the order of 2.5 – 3.0 million psi.
The channel fracturing technique was first introduced in the Egyptian Western Desert in late 2011. Since then several wells have been fractured using this technique and the production evaluation of these wells has been compared to offset wells fractured with conventional hydraulic fracturing techniques. Further, the application of rod-shaped proppant has provided excellent proppant flowback control as demonstrated by zero proppant flowback. Initial and long-term normalized production of the wells fractured with this technique increased significantly over offsets fractured conventionally. The positive results from implementation of this combined stimulation technique have led to a vigorous expansion of its utilization throughout Egypt's Western Desert area.
Best Practice to Design and Interpret Interference Tests Based on Features of the Line-Source Solution: Theory and Application
Authors: Maizeret Pierre-David 
Published: April 2013

Abstract
Interference testing is the oldest, but still the most effective, way of establishing communication between wells and determining the interwell reservoir transmissibility. However, these tests are not frequently run because the results are commonly difficult to analyze due to unforeseen complications.
This paper presents several practical methods to design and interpret effective interference tests based on the properties of the line-source solution. In single-well transient tests, early-time features of the exponential integral function occur at times that are too early to be observed. However, the distinctive pressure transient derivative features appear at an observation well much later during an interference test, and can be used to estimate the storativity and transmissibility ratios of the reservoir. The pressure response and the log-derivative of the pressure intersect on the log-log diagnostic plot for the observation well and the pressure response itself exhibits an inflection point. Based on these characteristics, simple geometrical methods are proposed to estimate reservoir parameters. Moreover, we formulate a new expression for the "travel time", or delay in the response. The particular case of fall-off or buildup is studied in detail, as the time lag in reservoir response can bring extra information. A field example is included to demonstrate the application of these methods in a field case and their usefulness to a practicing well test engineer.
An Effective Knowledge Sharing Framework in Oil Sector: A Case Study from Sudapet
Authors: Ali Arif Abdelwhab , Wadidi Elfatih 
Published: April 2013

Abstract
Knowledge as ancient concept is used for leading decision making and projects set up. The possessed efforts in different projects conducted in oil sector resulted in a huge amount of data and knowledge within different types of handling media, where needs of knowledge sharing is raised and considered as one of the main objectives of the companies. The recognition of the Sudapet Company as a national company in this fields tends to set a framework for experience and knowledge sharing in a proper and scientific manner.
This paper explores the methods used in Sudapet Co. to frame the activities for knowledge sharing and setup the framework for the oil industry in Sudan. The key success factors are discussed such as top management support as well as the staff commitement. Several knowledge sharing techniques have been embedded into the framework to support ceating a learning organization. In addition, the challenges which have been facing the implementation of this framework have been highlighted.