bluuebunny/crossref_metadata_2025_split huggingface dataset:
Implication of Properly Tuned EOS and Properly Measured SCAL on Prediction of Rates, Reserves, and Field Performance Using a Full-Field, Fully Compositional Model for an Offshore Complex Carbonate Field in Abu Dhabi, UAE
Authors: Al Hajeri Salma , El Mahdi Ahmed , Negahban Shahin 
Published: December 2007

Abstract
Reservoir simulation is the most accurate tool for forecasting rates, reserves and field performance, provided that accurate information is used to build the model. To overcome major uncertainties associated with a fully compositional simulation model, it is of utmost important to obtain accurate SCAL data and EOS description. The accuracy of model initialization (including matches of log saturation profiles and oil in place) and prediction of historical field performance are strong function of these measurements.
This paper discusses the impact of newly measured SCAL data and a newly tuned EOS on model prediction for an off-shore complex carbonate field in Abu Dhabi, UAE. The subject reservoir has been put on production using a combination of Gas/Water/WAG injection schemes in early 2006. An advanced EOR/PVT study was carried out using representative oil and gas samples from the field. The results of experiments were used to build a new EOS fluid description. In addition, a detailed SCAL study was performed to measure pertinent relative permeability and capillary pressure data.
The interpreted SCAL data and the EOS description were tested extensively and then were used to update full field fully compositional model. The data was further verified during the history-match of the historical field data (early production scheme) before utilizing it for updating the forecast plan. Results indicated significantly improved reservoir performance prediction (increased ultimate recovery factor and production plateau duration) compared with the results of the previous model which uses non-accurate analog input data.
This paper will present implication of properly tuned EOS and properly measured SCAL on prediction of rates, reserves and field performance using a full field fully compositional model for an off-shore complex carbonate field in Abu Dhabi, UAE.
Tight Reservoirs—A Development Challenge Example From a Carbonate Reservoir Offshore Abu Dhabi, UAE
Authors: Al Hajeri Salma , Al Shehhi Abeer , Ribeiro Maria Teresa , Ayoub Mohamed , Negahban Shahin , Bahamaish Jamal 
Published: December 2007

Abstract
Tight carbonate reservoirs, although less well understood and believed to require higher development costs and risks than conventional reservoirs, have become an important resource. Historically, tight reservoirs have been unpopular and unfavorable with geologists and reservoir engineers mainly due to difficulty associated with their development with no commercial productive value. Recently, with the increase in demand for oil and continuous development of new technologies, the time is right to carefully examine and develop such reservoirs.
This paper discusses the development of one of the tightest carbonate reservoirs offshore Abu Dhabi, UAE. Initially, this reservoir was not planned to be developed based on the appraisal data collected. The average reservoir permeability is around 1 mD with a productivity index of 0.4 bod/psi. However, an intensive work was performed to evaluate the reservoir potential as being commercially attractive. Such process included gathering of additional data during the development of a major reservoir located below and the review of the core and test permeability data across the reservoir.
Several model scenarios were created both on static and dynamic sides as well as an evaluation of the uncertainties and associated development risks.
Effectiveness of the study took place when drilling horizontal wells across the most permeable intervals resulted in a production five times higher than expected. This resulted in a decision to embark on the field development and additional production data gathering for development optimization.
Improvement of Business Processes Through Knowledge Management
Authors: Gatta S. R. 
Published: December 2007

Abstract
Under the present budgeting system that is in vogue for many years, there is significant uncertainty concerning the Scope of Work (SCOW) at the Budget Proposal stage, giving rise to escalated cost estimates, which in turn lead to excessive carried over expenditure. That process gave rise to rush at the eleventh hour detrimental especially to the functioning of the executing arms (Controlling Groups) within the Company. A number of lacunae have been noticed. No feasibility study indicating the detailed evaluation of various alternatives and their economics was provided. The cost estimates are furnished without any front-end engineering. Sufficient time was not allowed to seek budgetary quotations. More often than not, nearly 50% cushion was provided in the estimated costs. Owing to these shortfalls inherent in the budgeting process, there was too much carried over expenditure with unspent funds (under-expenditure).
In an effort to resolve these shortcomings, the Company came forward with an innovative approach with the following merits:
▪ Precise cost estimates and implementation schedules, ▪ Precise capital expenditure phasing, thereby minimizing the Carry Over expenditure, ▪ Expedited project completion, incurring minimum or no project delays, ▪ Opportunity to apply value engineering to ensure quality at reasonable cost, ▪ More effective project appraisals, and, ▪ Well-defined Scope of Work, minimum number of variations to the original SCOW, minimum number of Authorization For Expenditure (AFE) revisions and minimum adjustment orders.
This novel scheme termed as Capital Project Proposals (CPP) Process was implemented within the corporate level Capital Investment Process through a management directive issued during Planning Group's Presentation in June 2002. The CPP Process provides the Company with a business practice that improves the development of the relevant capital project concepts and assists Top Management in their investment decision-making.
The case study presented through this paper adequately demonstrates the novel approach.
Enhanced Oil Recovery by Hot CO2 Flooding
Authors: Picha Mahesh Shrichand 
Published: December 2007

Abstract
Enhanced Oil Recovery (EOR) techniques helps to recover residue oil after Primary and secondary recovery of reservoir. This paper deals with a new Carbon Di Oxide (CO2) EOR technique, "HOT CO2" which includes combination of thermal and solvent techniques where miscibility and viscosity reduction are primary concern. In the proposed method CO2 will be superheated above the reservoir temperature to reduce the oil viscosities at the same time partially mix with crude oil which improves oil mobility. Heavy Oil field-Bati Raman from Turkey which is under CO2 Flooding, after the application of HOT CO2 flooding theoretical calculation shows it reduces the viscosity and partially mix with oil to increase the swelling factor which ultimately increase the recovery factor comparative with the CO2 flooding. Thus the screening criteria for HOT CO2 Flooding can now include highly viscous oil and covers wide variety of reservoirs which was not possible with CO2 flooding earlier. For the injection of HOT CO2 a special surface facility requires to prevent corrosive and thermal effect. Before implementation of HOT CO2 flooding method simulation model work, laboratory work and pilot field test are necessary areas to work. HOT CO2 flooding should be preferred absence of any major fault makes this technique more effective. "HOT CO2 flooding" will going to be one the best option for EOR in future.
A Novel Approach to Fracture Characterization Utilizing Borehole Seismic Data
Authors: Dutta Pradyumna , Singh Sunil Kumar , Al-Genai Jarrah , Akhtar Azhar , Akbar Mahmood 
Published: December 2007

Abstract
The Najmah, Sargelu and Marrat are the main Jurassic reservoirs in Kuwait. These fractured carbonate reservoirs with moderate to low porosity were deposited in an inner to mid ramp warm marine environment. The fracture systems play a significant role in production from these reservoirs and it is imperative to identify areas of high fracture density. It has been observed that fractures associated with certain faults have facilitated the flow in the Jurassic reservoirs. Identification of faults and associated fractures has been mainly based on 3D/2D seismic data, image logs, cores and thin sections.
A recent successful exploratory well in the Arifjan Prospect located on the eastern flank of the Greater Burgan Field, has opened up a large area which was previously considered to be nonproductive. There is excellent correlation between the fractures observed in cores, image logs and those predicted from the converted component of the zero-offset VSP. After registration of the z-component image with the converted image for various prominent reflectors, the discontinuities in the reflectors in the converted component image revealed fracture swarms which could be traced away from the well bore.
This technique of processing the VSP data to identify fracture clusters could form a bridge between surface and borehole data and improve confidence in predicting fracture swarms away from the well bore in addition to assisting in planning for future surface seismic and 3D VSP surveys.
Connection Qualification for Casing-Drilling Application
Authors: Lu Qing , Wu Jiang , Hannahs Dan 
Published: December 2007

Abstract
The advancement of casing drilling technology requires the casing connection to perform in more stringent conditions, i.e. in HTHP and directional wells under dynamic loading. Casing connection fatigue, sealing ability, and structural ability are therefore a primary concern.
As no commonly accepted industry standard exists in qualifying connections for casing drilling applications, a big question for the industry is how to qualify connections for casing drilling applications with a reasonable and practical approach. This paper presents the initial test results of connections for casing drilling applications with a new test procedure1, which combines the current industry standard ISO 13679 (the regular casing connection test specification2) worst-case tolerance strategy with dynamic loading testing (fatigue test simulating casing drilling condition3). The testing demonstrated the DWC/C-SR connection performance with the new test procedure. The predetermined service life was based on established fatigue SN curves4. The testing showed that the connection thread tolerance may greatly affect the connection fatigue life.
The performance characteristics of connections for casing drilling can be accurately defined by combining fatigue testing with ISO 13679 combined load testing. The initial test results presented in this paper will help illustrate connection performance characteristics and develop a test procedure for qualifying connections. This will result in improved casing drilling operation success and cost reductions.
Design of Well Barriers to Combat Circulation Losses
Authors: Aadnoy Bernt S. , Belayneh Mesfin , Arriado Miguel , Flateboe Roar 
Published: December 2007

Abstract
The paper summarize a 10 -year research program at the U. of Stavanger in borehole fracturing and mud design. Novel fracturing cells and mud cells were built to better understand the mechanisms that lead to circulation losses. Numerous experiments are conducted using both oil- and water based drilling fluids.
The paper presents a new mechanistic model for fracturing called "the elastoplastic barrier model". It is different than other recent models, and it is verified with lab experiments. In simple terms it defines optimal barrier filtrate loss to place particles in the loss zone, and, also the mechanical strength of the particles required to resist losses. Selected lab experiments will be presented demonstrating that borehole fracturing resistance can be significantly improved by changing the mud composition.
Testing commercial LCM products it was found that some worked well, some were poor, and some worked only in synergy with others. Based on this, the compostion of an optimal LCM pill will be presented. Non-petroleum products have also been tested to search for improvements in mud design. One result is that calcium-carbonate can be replaced with more efficient materials. We have also shown that adding small amounts of carbon fibre have a positive effect.
This research has been conducted in close cooperation with major mud companies and operators. A field case will be presented from a shallow field. The mud was designed and tested during operation at the lab of the U.of Stavanger. The result was a clear increase in fracture pressure, resulting in a successful operation.
State of the Art in Geophysics and Wells Imaging for Giving a New Lease of Life to Giant Brownfield
Authors: Sanchez-Perez Zayda , Baud Emmanuelle , Jeanjean Frederic , Cassou Gilles , Lesueur Jean-Louis 
Published: December 2007

Abstract
The Abu Al Bukhoosh field extends offshore Abu Dhabi, near the UAE-Iran border. More than thirty years of production from the Upper and Lower Arab, but also Thamama reservoirs, under secondary and tertiary development schemes, allowed reaching significant recovery factor. At this time in the life of this very mature field, further applications of EOR techniques for enhancing the final field recovery lead to a deep revamping of the geological models.
The reprocessing of the 3D seismic data in 2002-2003 strongly improved the resolution and continuity of the reflectors. Despite evidenced through dynamic data, the second-order structural framework of this finely layered shallow-carbonate environment remains unclear.
The use of new filtering, and seismic-derived attributes combination significantly improves the structural interpretation. Noise attenuation, vertical discontinuities and horizon continuity enhancement provide a better imaging for faults and sub-seismic faults.
Among the newest attributes available in SISMAGE™ TOTAL proprietary software, the fault attribute associated with the "fault peeling" techniques were of crucial help for highlighting small-scale structural features.
It appears that most of the main faults were vertically and horizontally segmented and should not be treated in a reservoir model as linear vertical or slightly deviated straight line. In addition, several relays on these main faults have been defined, the most important ones being located at the intersection with broad diffuse N020-030 oriented trends.
The location of these trends and their relation with the second-order N110-120 oriented structural features should provide key for understanding the dynamic governing the flow regimes of the field.
Finally, a fully integrated approach from Geophysics and Geology to Reservoir leads to review the structural heterogeneity of the field. This achievement was a prerequisite for building representative simulation models mandatory to pursue IOR/EOR developments.
Kick Detection and Control in Oil-Based Mud: Real Well-Test Results Using Microflux Control Equipment
Authors: Santos Helio , Catak Erdem , Kinder Joe , Sonnemann Paul 
Published: December 2007

Abstract
Kick detection in oil and synthetic-based fluids has been a major concern for the industry for decades. Due to solubility issues, kick detection may be delayed and resulting well control operations may be problematic. Use of the Micro-Flux Control (MFC) method potentially offers a better way to address this problem in the same way it has been successfully demonstrated to work using water-based fluids (WBM).
To check the performance of the MFC method while using oil-based mud (OBM), a series of full-scale tests were conducted at Louisiana State University PERTT Laboratory using natural gas injected into test wells containing an 11-ppg 70/30 diesel/water OBM. Performance results were compared with results previously obtained with WBM gathered at the same facility.
The excellent and consistent character of the test results obtained encouraged the use of the MFC on a well to be drilled in Texas for Chevron. The well plan called for using OBM with mud density up to 17.4 ppg, at an anticipated depth of 13,000-ft. This would be the second well drilled with the MFC method, following one drilled in Brazil for Petrobras using WBM.
The paper presents the results obtained during the one – week long live well testing at LSU as well as details of the first field test of the MFC system on the actual well drilled with OBM in Texas. The results confirmed the ability of the MFC system to detect very small influxes of natural gas into OBM with subsequent control of the influx accomplished in a way very similar to that used with WBM. Several other tests were also performed in both wells to explore possible additional uses of the MFC system. These included dynamic leak-off and formation integrity tests, behavior with multiple kicks inside the wellbore simultaneously, identification of ballooning or "breathing" during connections, and early detection of loss of circulation. All of the results obtained in both test scenarios confirmed the potential value of the MFC system for identifying and dealing with the above listed issues when conducting drilling operations utilizing OBM.
Rotary Steerable System Technology Case Studies in a High-Volume, Low-Cost Environment
Authors: Akinniranye G. , Kruse W. D. , Bautista Gomez A. , Poedjono B. , Dubose B. , Goobie R. B. , Hobin J. 
Published: December 2007

Abstract
An efficient, safety-conscious wellbore drilling method features highly accurate wellbore placement, reduced drilling time, and improved safe drilling practices. Rotary steerable system (RSS) technology provided a cost-efficient solution in a high-volume environment for a US-based oil and gas exploration company drilling 80 to 100 wells per year in South Texas, USA.
Although vertical drilling has been in practice since the birth of the industry, maintaining verticality is still challenging and requires alternative drilling strategies. Traditionally, downhole positive displacement motors (PDMs) have been used to control the wellbore vertically in this drilling environment. This drive system typically requires one or two additional bit runs to achieve the target objectives. A reduction of the weight on bit (WOB), or feathering, was also required to maintain a vertical wellbore. The combination of this drive system coupled with the lower-than-optimum WOB leads to a dramatic reduction in rate of penetration (ROP) when steering is required, which is neither cost-efficient nor desirable. The introduction of RSS technology has addressed both of these concerns by allowing the application of higher WOBs for faster ROP while maintaining high levels of wellbore placement accuracy.
RSS technology in this environment increased the number of drillsites available as the surface location can be right on the "hard-line" of 467 ft from the lease-line required by the Texas Railroad Commission. Previously, fewer lease-line wells were drilled owing to the problems of keeping the accumulated displacement inside the lease dimensions.
This paper presents field studies from 2004 to 2006 demonstrating RSS success in maintaining verticality where the bit tends to walk related to highly faulted, fractured, and dipping formations. The RSS system provided real-time response and a vertical wellbore. Instantaneous wellbore corrections reduced drilling time in some cases more than 40%. In both the vertical and deviated wellbores studied, total depth (TD) was reached ahead of schedule with reduced costs.
The Introduction of Electromagnetic LWD Technology in Saudi Arabia—A Case History and Future Application to Underbalanced Campaigns
Authors: Muqeem M. A. , Jarrett C. M. , Jeffri A. M. , Weisbeck D. , Mallahy M. , Forge N. , Branch A. J. 
Published: December 2007

Abstract
The first Electromagnetic-Logging While Drilling (EM-LWD) Triple Combo operation with the Extended Range set-up was successfully completed in Saudi Arabia. The 6-1/8 inch horizontal section of the well was underbalanced drilled (UBD) from 8,109 feet to 11,189 feet in one run.
The objective was to evaluate the feasibility of EM transmission in conjunction with LWD triple combo and annulus pressure sensors in the 6-1/8 inch horizontal section. LWD is necessary for geo-steering of the well, and annulus pressure is required to monitor the underbalanced conditions. This particular well was drilled UBD with single phase fluid; future wells will require the use of gas injection to achieve UBD conditions. The injection of gas through the drill pipe precludes the use of mud pulse telemetry. As an alternative, EM telemetry needed to be proven to allow a continuation in the UBD planning process to include real-time LWD technology.
EM transmission of LWD triple combo and annulus pressure data in real time allowed 3,080 feet of 6-1/8 inch horizontal section to be successfully geo-steered and drilled in one bit run while maintaining underbalanced conditions. In addition, the well was flow and pressure tested with real time annulus pressure data acquired during pumps off operations (an advantage of EM versus conventional mud pulse telemetry is that real-time updates are possible, independent of well bore hydraulics). The conclusion was the successful EM-LWD operation in the well where all of the objectives were achieved.
The successful proof-of-concept of EM-LWD with annulus pressure extends the scope of development of future UBD campaigns that require two phase fluid utilising drill pipe gas injection.
Field Result of Equivalent-Circulating-Density Reduction With a Low-Rheology Fluid
Authors: Bolivar N. , Young J. , Dear S. , Massam J. , Reid T. 
Published: December 2007

Abstract
To qualify for use on a world record extended reach drilling (ERD) well, a trial well was selected to demonstrate the technical benefits of using a uniquely designed, low-rheology, synthetic-based drilling fluid. The 8½-in., production hole section was 1,755 ft (535 m) long and drilled to 20,472 ft (6,240 m) at an angle of 25°. Prior to drilling this section, a low-rheology drilling fluid was selected. Selection analysis was based on assessment of key drilling parameters as compared with wells drilled previously using a conventional API barite-weighted synthetic fluid. A unique characteristic of the low-rheology drilling fluid is its use of specially treated, micron-sized, barite-weight material (TMSB). It can be formulated with a much-reduced rheological profile without the risk of barite sag.
This paper presents the background work performed leading up to the field trial. Field data is presented comparing the drilling performance and fluid characteristics between the low-rheology fluid and the previously used conventional API barite-weighted synthetic fluid system. Significant reductions in equivalent circulating density and standpipe pressures were accomplished, as well as torque reductions of up to 30%. Results demonstrated the low-rheology, synthetic-based drilling fluid's ability to reduce drilling risk. This paper reports the economic and technical benefits realized from using this fluid, including the first use of 400-mesh prototype shaker screens (API 200 mesh), the much reduced dilution factors, and cuttings re-injection volumes.