bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Case Study of Evaluating Reservoirs in the Malay Basin
Authors: Zulkipli Siti Najmi , Kyi Ko Ko , Haddad Sammy , Johan Zailily , Wa Wee Wei , Sinnappu Suresh , Lim Lee Chin 
Published: April 2013

AbstractFormation fluid type and composition are important and integral parameters in reservoir characterization and evaluation. Fluid type and composition can be obtained by capturing samples from limited depth across the producing zone. However, recent advances in downhole fluid analysis (DFA) enable the downhole fluid identification and composition measurement from depth where the fluid samples are either not collected or when PVT results are not readily available. A new wireline technology in insitu fluid analysis (IFA) was used to achieve this objective.This work is based on field data from a newly drilled well in Malay Basin where the targeted reservoirs are comprised of clastic formation on the upper section of tested interval and of Central Luconia carbonate in the bottom section. The insitu fluid analysis technology has successfully guided the identification of oil and water in the clastic formation and gas in the carbonate. The detailed information on oil and gas composition, CO2 content, and fluid density was obtained in real time.The presence of water in clastic formation identified by wireline formation tester triggered interest in more investigation. The water producing interval is located at about 100 m down dip from a nearby development well that is producing gas. Instead of initially planned full DST, decision was made to run the wireline formation testing dual packer module to perform interval pressure transient testing (IPTT) after the well had been cased. The IPTT and DFA confirmed the water section and saved significant cost on running unnecessary testing. The methodology, applications and suggested best practices are presented in this work.
Revitalizing Mature Gas Field Using Energized Fracturing Technology In South Italy
Authors: Granado Luis E. , Garritano Roberta , Perfetto Raffaele , Lorefice Roberto , Ceccarelli Roberto L. 
Published: April 2013

AbstractThis paper reviews the fracture stimulation improvement achieved over the well stimulation experience to attempt a field redevelopment through a well revitalization after workover and recompletion with a multistage hydraulic fracturing string using energized fluids, notwithstanding the limited background of fracture technology applications in Italy. The objectives were concentrated on the reserves final recovery of the principal layers and assessment of potential thin layers that has never produce before, which entail the use of technologies state-of-the-art for drilling, completions, stimulation and development plans.The hydraulic fracturing stimulation technique pumping energized fluids introduced in the Roseto-Montestillo field has proved to be very successful recovering well productivity, however some associated problems have required a process optimization during the intervention. The problems ranged from in situ stress variation, that lead to very high pumping pressure (even in presence of very depleted reservoir), plastic or soft formation with potential proppant embedment issues, effective vertical coverage of the target pays intervals and gel residue with the consequent damage to fracture conductivity.Here significant gains in production have been observed following the successful fracture treatment optimization moving from conventional borate crosslinked guar polymer to an optimized zirconate fracturing fluid energized with CO2. The use of energized fracturing fluids, expedite the fracture clean up process and dramatically reduce the amount of fluids to be recovered, while aid the lifting process on the other layers where conventional treatments were pumped. All this lead to a higher well productivity sustained along the time while minimize post fracturing problems compare to the jobs with conventional fracture treatment.This paper summarize the fracture stimulation treatment best practices and review the design along with the operational considerations for the area, including treatment volumes, pump rates, surface equipment, completion selection and fluid chemistry.
Enhancing Oil Recovery in Gulf of Suez by Deep Conformance Control using a Thermally Activated Particle System
Authors: Towns Martin , Lara Angarita Monica , Thrasher David , Denyer Paul , Nabil Mohamed M. , Bayoumi Radi S. , Kinawy Mahmoud M. 
Published: April 2013

Abstract
This paper describes the use of Bright Water™1, a thermally activated particle (TAP), to enhance oil recovery from the giant Morgan field in the Gulf of Suez. The main reservoir of the Morgan field, the Kareem sandstone, has a high well density and has produced under water flood for over 35 years. Despite this, lower permeability zones remain poorly swept while average production water cut exceeds 85%. Deep conformance control is required to improve sweep efficiency.
The authors describe the area selection criteria, the treatment design method and deployment operations. Although Bright Water particles have been deployed in many fields globally, this treatment, completed in September 2012, is particularly noteworthy in that it is the first application of this chemical system via an onshore injection system to simultaneously treat multiple offshore wells. At the time of writing, this is also the largest treatment of its kind performed in a single operation.
This application sets a precedent for future treatments in terms of technique and scale. Treating multiple wells simultaneously from an onshore facility greatly reduced the cost of execution operations and minimised operational risk. The treatment's impact on production will be determined from a rigorous programme of well testing and wellhead sampling.
Advances on Partial Coupling in Reservoir Simulation: A New Scheme of Hydromechanical Coupling
Authors: Lautenschläger Carlos Emmanuel , Righetto Guilherme Lima , Inoue Nelson , da Fontoura Sergio Augusto 
Published: April 2013

Abstract
This paper deals with the implementation and validation of a new hydromechanical partial coupling methodology conducted between two commercial simulators of flow and stress. Such configuration is based on a coupling methodology developed by the Computational Geomechanics Group – ATHENA/GTEP - PUC-Rio, based on the consistent inclusion of terms in flow equation in order to approach the results of fully-coupled simulations. The IMEX® flow simulator was included in the workflow of the coupling code in order to widen the application scope of the methodology developed. To include the new option of flow simulator was required some implementation effort together with validation through simplified models. The algorithms developed to guide the programming were defined after detailed study of numerical and computational functioning of the flow software. The results obtained with the new simulator were compared with the pre-existing configuration (ECLIPSE flow simulator), considering one and two way partial coupling and fully coupled models. In the comparison scenarios set out to validate the implementation, it was evaluated changes of average pore pressure in the reservoir, compaction and subsidence, as well pore pressure variations. Comparisons with the results of pre-existing configuration and the full-coupling scheme demonstrated the success of the developed algorithm. The exchange of coupling parameters between simulators, in the new configuration, has been implemented effectively. Parametric studies of the variables also demonstrated the quality of the new configuration coupling. The rigorous choice of exchange parameters between flow and stress simulators is crucial for obtaining reliable results.
Green Gas field Development with Zero Flaring in Egypt
Authors: Abou El Azm Adel 
Published: April 2013

Abstract
In the frame work of global gas flaring reduction, RWE Dea Egypt (RWE Dea) as the development operator for the green gas fields in Disouq Concession, Nile Delta has recognized that the International Finance Corporation (IFC) Social, Environmental, Health and Safety Guidelines and Egyptian environmental Laws emphasize reuction of gas flaring as much as is practicable.
Over the last few years, most international operating companies have worked hard to progress towards "Zero Flaring". In today's technology there are complete flare systems available that provide zero flaring solutions. These systems cannot remove the basic need for flaring in emergency situations as a final safety device, but can and do offer real cost and environmental benefits by extinguishing or managing the flare in daily operations.
This paper provides an overview for the gas development of seven gas fields discovered in the Disouq concession onshore in the Nile Delta region of Egypt and it features a set of measures and techniques that were considered in the design concept to achieve zero flaring. RWE Dea project team decision was made after several technical and commercial discussions in order to find the best feasible scenario and incorporated also the previous experience of zero flaring made in other operating fields in Norway and UK.
RWE Dea adopting zero flaring facilities as an improvement over continuous flaring systems to avoid any flaring during normal operation and minimize the off gases from the process equipment. Off gases which are produced will be collected by a recovery gas compressor and used as fuel.
There are several measures reflected in the design to achieve the zero flaring in Disouq project, which are as follows: Minimizing off gases.Recovery of flash gas by installing a recovery gas compressor.Considering noncontinuous pilot gas system.Considering a highly reliable flare gas ignition system.Selecting a proper flare tip to suit the operating conditions of the Flare Package.Conducting a proper design for storage tanks and using N2 inert gas blanketing instead of fuel gas.Considering a flow meter to measure the gas being sent to flare.Transfer of technology know-how and system design.
There are many significant benefits for operators using zero flaring systems rather than continuous flaring system, such as: Reducing Co2 emission in wasted gas.Saving of gas otherwise wasted in combustionSaving expenses for shut down and flar tip replacement.Reduction in maintenance requirements of the flare system.Significant reduction in the OPEX costs.
Time Lapse PTA to Determine the Impact of Skin, Reservoir Compaction, and Water Movement on Well Productivity Loss: a Field Example from WDDM, Egypt
Authors: Ugoala O.. , Gad K. H. , Whittle T. M. , Stone M.. , Butter M.. , Galal S. K. , Mahmoud H. S. 
Published: April 2013

Abstract
Three productivity loss mechanisms - skin damage, water invasion, and reservoir compaction - are identified in one of the concessions co-owned by BG Group in the Nile Delta of Egypt. To inform the decision if and how to intervene to reverse the loss in productivity, it was important to understand the relative level of impact of each of these mechanisms on the observed drop in productivity.
Pressure Transient Analyses (PTA) of permanent downhole gauge (PDHG) build-up data, obtained during well shut-ins, allows identification of the contribution of skin and effective permeability thickness (kh) to a given well productivity loss. By monitoring build-ups over time, any loss in observed productivity can be attributed either to increased skin or reduced effective kh.
Knowing that effective kh reduction can be as a result of reservoir compaction, a reduction in net reservoir thickness due to water movement, or a reduction in relative permeability due to saturation changes, a number of control wells were selected and categorised, based on their levels of water production - negligible to low water, and moderate to high water producers. The moderate to high water producers already give indication of water breakthrough and possible gas-water-contact (GWC) movements.
Time lapse PTA from these control wells enabled the tracking of changes in skin and effective kh over their producing life.
The results of the investigation showed that although reservoir compaction may be occurring, the effective kh reduction for the low liquid producers is minimal. Hence increasing skin is believed to be the primary cause of the observed productivity losses. For the wells with high water cut, the productivity loss is attributed to both an increase in skin and a reduction in effective kh due to reduced net reservoir thickness and two phase flow in the reservoir.
Enhancing The Overall Productivity of GASCO Integrated Plants Using Available Process Flexibility and Reliability
Authors: Riad Tamer Hamdy 
Published: April 2013

Abstract
GASCO operates two NGL plants located in Alexandria; Amerya LPG plant and Western Desert Gas Complex (WDGC). The Amerya LPG plant receives & treats 300 MMSCFD of western desert gases from Badr 2,3 (Bapetco), Abu-Sanan, south dabah, petro-alm, (neag & sheba), west setra and septco fields, to produce 250 MT/Y LPG for local market and 25 MT/Y condensate to use for the refineries and the other is WDGC plant receives & treats 600 MMSCFD of western desert gases from Al-Obayed (Bapetco), Salam, Tarek and El-Qaser (Khalda) fields, to produce 465 MT/Y of Ethane/Propane mixture used as a feed stock for petrochemical industry (SIDPEC Company) to produce Ethylene and 280 MT/Y & 59 MT/Y of LPG and condensate for the local market consumption adding value for national economy by reducing the imported quantities of the same products and 210 MT/Y of Commercial Propane for export to the international market increasing income from the hard currency to support the national economy. Recently, GASCO has started up a new project to receive & treat extra 300 MMSCFD and also to integrate the two plants to maximize Ethane and Propane productivity. The project design is based on adding new process facilities in Amerya plant to start producing C2+ that directed to WDGC, while a new train is added in WDGC to increase the feed gas capacity and maximize C2+ recovery by applying the Gas Subcooled Process (GSP) as Ethan mode of operation scheme. This paper presents a study to increase the productivity of the two plants by using simulation software applied on field to help the decision making for what the optimum conditions should be applied in different modes of operation to increase the production.
Integrating New Technology Utilizing Risk Management
Authors: Wael Abouamin P. E. 
Published: April 2013

Abstract
Building an ultra-deepwater (UDW) drilling rig that incorporates the latest technology while meeting internal requirements, client specifications, and budget constraints, can be a daunting challenge. Doing so in a post-Macondo environment with a shortage of qualified personnel to man the rig adds even more obstacles to overcome. Ensuring that a variety of rig systems supplied by different vendors will be integrated into a workable rig that is properly maintained is another task for the drilling contractor.
Rowan Companies, Inc. is building 3 UDW drillships in Hyundai's shipyard in Ulsan, Korea. The rigs will incorporate the latest in offshore drilling technology including dual, fully redundant BOPs and BOP control systems, heave compensating drawworks, knuckle boom cranes, and other innovations. They will be capable of drilling at 12, 000 feet with a maximum hookload capacity of 1250 tons and a variable deck load of 20,000 tons.
This paper attempts to demonstrate how implementing a risk management plan during the design and construction of such rigs can help reduce risks associated with major accidents and downtime. This can be accomplished by applying the results of the risk assessments into training of personnel, updating of operational procedures, updating of maintenance procedures, modifying designs, changing control systems and re-programming software.
This paper presents the results of a risk management plan as it was applied to 17 different rig systems: Active Heave DrawworksAnticollision SystemBilge & Ballast SystemsBOP Handling SystemCooling Water SystemsCyberbase and Drilling Control Network SystemFirefighting SystemsFire and Gas Detection SystemIron RoughneckKnuckle Boom CranesPipe Handling SystemRiser Handling SystemTDX 1250 Top DriveThruster SystemWater Tight IntegrityWell Control System - Subsea SystemsWell Control System – Topsides Systems
The risk management plan was implemented in the form of individual risk assessments focused on each of the above mentioned systems utilizing primarily the failure modes, effects, and criticality analysis(FMECA) methodology. It can be quite surprising to evaluate the results of these sessions and realize how powerful these tools can be and how effective they can be in identifying potential faults and weaknesses in the systems. The end result of the risk management plan was a rig that is better integrated, operated by crews that are more familiar with the systems they will man, and functioning in an environment that will reduce accidents and downtime.
Unlocking Resource Plays in Egypt - Opportunities and Challenges
Authors: Carnell Andrew , Emam Mourad , Boering Martijn 
Published: April 2013

Abstract
Resource plays are at the centre of worldwide attention following the rapid growth in tight and shale gas production in North America over the last 5 years. This paper examines the opportunities and challenges that the exploration, appraisal and development of resource plays can bring to Egypt. Resource plays are defined in this paper as "technically difficult to extract" hydrocarbons found in tight sandstones, carbonates and shales.
As the energy demand is increasing in Egypt and oil and gas production from the conventional development asset base is declining, resource plays may hold the future for Egypt's energy supply. Resource plays are attractive because they typically have relatively low exploration risks, material in-place and recoverable volumes, long lasting production and can often utilize available ullage in existing infrastructure and facilities. Unlocking these plays, however, also pose significant challenges.
This paper will 1) summarize learning's from North America projects and how they may apply in Egypt, 2) investigate the key technical challenges of resource plays and 3) examines the current regulatory and contractor landscape and its opportunities and hurdles for resource plays.
Gas Shale Characterization - Results of the Mineralogical, Lithological and Geochemical Analysis of Cuttings Samples from Radioactive Silurian Shales of a Palaeozoic Basin, SW Algeria
Authors: Hofmann Andreas , Rigollet Christophe , Portier Eric , Burns Suzi 
Published: April 2013

Abstract
The successful recovery of hydrocarbons from shales is dependent on physical rock properties such as lamination, brittleness and the presence of natural fractures, as well as chemo-physical properties such as absorption and adsorption. The key parameters defining the hydrocarbon potential of shales are the mineralogy, organic carbon content (TOC) and burial history. These parameters are commonly derived by conventional and special core analysis of SWCs or cores.
This study highlights that most of the analyses and techniques used to determine the hydrocarbon potential of shales can also be performed on cuttings material with a high degree of confidence. The usage of cutting material has significant advantages with respect to sample availability, sample coverage and acquisition costs. Accurate depth allocation of cuttings is problematic but, by careful reference of the measured mineralogical and textural features to the available mudlog and wireline data, the effects can be minimised.
As part of a research project, SGS analysed the mineralogical and lithological composition of 80 cuttings samples, from various wells in the Radioactive Silurian Shale (drilled a Palaezoic Basin, SW of Algeria) by QEMSCAN. In addition, the geochemistry and maturity parameters were determined by Leco (TOC) and RockEval (S1-S3) methods. Furthermore high resolution 3D computer tomography scans (CT) were performed in order to analyse the cutting material for lamination and micro-fractures. The compilation and interpretation of the mineralogical, lithological and geochemical data indicate significant vertical and lateral heterogeneities, probably induced by local facies changes, which possibly lead to strong variances in the shale gas potential.
The properties of the Silurian hot shale samples were compared with QEMSCAN results of shale samples from Canada, UK, published data from the US gas shales and source rocks from Netherlands and Sweden. Based on the comparison, a distinct trend could be established, indicating significant differences in mineral composition between producing gas shales and other more "conventional" gas source rocks.
Pre-Messinian Extensional Tectonics and exploration potential of related structures; in Central Nile Delta Basin, Egypt
Authors: Matresu J.. , Talaat A.. , El Belasy A. M. , El-Meadawy M.. 
Published: April 2013

AbstractThis paper discusses the exploration potential of extensional structures in pre-Messinian formations in central Nile Delta Basin. The study aims at detailed description of extensional events and discusses the exploration potential of specific structures generated.Particularly, structural elements of pre-Messianian sequences were partially deciphered in the past, due to quality of seismic data and spare and scarce wells drilled to these levels. The newly acquired high quality 3D seismic data has been able to improve the image underneath the pre-Messinian. This has resulted in the understanding of tectonic activity, faults system and structures developed.Two extensional events characterize the tectonic activity in the Late Oligocene through Messinian.First extensional event is related to onset of Gulf of Suez rifting and generate a W-E system of basement involved faults and reactivation of syn-rift hinge zone. Related structures of this extensional phase are represented by growth anticline, drag folds and rotated blocks.The second extensional tectonic event occurred in Tortonian. The structural style corresponds to tilted and eroded fault blocks dipping to north and being aligned in a north- south direction corresponding to the main normal faults trend.This study of the pre-Messinian extensional structures described here will have a direct impact on the exploration activities design, several important prospects being delineating among the structures developed during both extensional phases.