bluuebunny/crossref_metadata_2025_split huggingface dataset:
Property Modeling: An Aid To Exploration Of Deep Jurassic Reservoirs In North Kuwait
Authors: Dey Arun Kanti , Singh Sunil Kumar , Al-Awadi Mishari Ameen , Rao N. Srinivasa 
Published: December 2007

Abstract
The emergence of multiple Jurassic carbonate play has opened up a new vista of exploration in the state of Kuwait. A strong need is felt to focus the exploratory efforts on the deep reservoirs below the oil producing Tertiary – Cretaceous strata across Kuwait. In absence of good quality seismic data below the Late Jurassic salt – anhydrite sequence the methods derived from the analyses of subsurface information obtained from exploratory drilling are utilized to complement to seismic study. The present paper describes one such method used as an aid to exploration of deep Jurassic reservoirs in North Kuwait.
Three exploratory wells have penetrated Jurassic Middle Marrat reservoir facies in the Raudhatain field. The wells are drilled 5 to 9 km apart in an area of about 160 sq. km. The initial test results show that this carbonate reservoir has a potential of producing light oil @ 3800 to 5300 BOPD and gas @ 8.5 to 15.5 MMscf / D. The production has been obtained from both limestone matrix as well as from secondary fracture and dolomite porosity.
Middle Marrat section was divided into eight zones on the basis of lithological heterogeneity. The log data was processed and was subsequently populated in the structure grids of different layers to develop a fine scale geocellular model. Porosity and water saturation are the properties used in this study. They were interpolated to decipher the distribution in vertical as well as in horizontal direction. The study was integrated with other geoscientific information to delineate the porous and oil saturated locations.
The model is useful in formulation of future exploration strategy in the area. In addition, it will also be used as an effective working model as the exploration and appraisal efforts mature.
Improved Understanding of Reservoir Fluid Dynamics in the North Sea Snorre Field by Combining Tracers, 4D Seismic, and Production Data
Authors: Huseby O. , Andersen M. , Svorstøl I. , Dugstad Ø. 
Published: December 2007

Abstract
To obtain improved oil recovery (IOR) it is crucial to have a best possible description of the reservoir and the reservoir dynamics. In addition to production data, information can be obtained from 4D seismic as well as tracer monitoring. Interwell tracer testing (IWTT) has been established as a proven and efficient technology to obtain information on well-to-well communication, heterogeneities and fluid dynamics. During such tests, chemical or radioactive tracers are used to label water or gas from specific wells. The tracers are then subsequently used to trace the fluids as they move through the reservoir together with the injection phase.
One of the appealing features of IWTT is that at first tracer breakthrough in a producer, immediate and unambiguous information on injector - producer communication is given. However, gas and water re-injection might complicate this simple evaluation, and later in the production history, this effect should be evaluated. Despite the appealing features of IWTT, they are still underutilised in the petroleum industry, and few of the tracer studies that are actually performed utilise the data to their full capacity - most tracer data are used in a qualitative manner [1].
To improve this situation, we combine tracer data evaluation, 4D seismic and available production data in an integrated process. The integration is demonstrated using data from the Snorre field in the North Sea. In addition to production data, extensive tracer data back to 1993 and results from three seismic surveys acquired in 1983, 1997 and 2001 were considered.
Evaluation of Steam Injection in a Fractured Heavy-Oil Carbonate Reservoir in Iran
Authors: Bahonar M. , Ataei A. , Masoudi R. , Mousavi Mirkalei S. M. 
Published: December 2007

Abstract
Steam injection in naturally fractured heavy oil reservoirs provides an extremely challenging problem as well as a potentially effective and efficient improved oil recovery method. Coupling of the two distinct and contrasting matrix and fracture systems results in a highly non-linear problem, and it gets even more complicated as a result of steep changes in fluid properties due to the thermal effects of steam injection. Modeling and designing an optimum steam injection operation in such systems requires an accurate characterization and representation of a naturally fractured heavy oil reservoir and steam injection operation parameters and dynamics1.
In this communication, the results of a feasibility study of steam injection in a highly fractured carbonate reservoir are discussed. The field is a giant structure located in south west of Iran at the coast of Persian Gulf. It is a symmetrical anticline with 56 mile length and 10 mile width in the surface with about 3.6 billion barrels of initial oil in place. The initial pressure is 927 psi at 1700 ft depth. The gravity of the oil is 7.24 °API with viscosity of about 2700 cp.
The Geological model was constructed based on the available 2D and 3D seismic investigation and conventional core data from different samples. Extensive fracture characterization has been conducted using core data as well as the petrophysical interpretation using imaging logs. Dynamic reservoir simulation model with thermal option has been developed and used for optimization of different parameters for steam injection and their effect on reservoir performance and recovery factor.
Reservoir simulation of the field showed that steam injection could improve oil recovery from zero up to nearly 12 %. Furthermore, the results illustrated that the important parameters for designing the steam injection are different strategies for perforating, well spacing, well type, pattern type and size. Additionally, the effect of other parameters such as injected steam quality, oil-water capillary pressure in matrix blocks, steam injection and oil production rate have been studied.
A Comprehensive Approach to Well-Integrity Management in Adma-Opco
Authors: Tarmoom Ihaab , Thabet Hussein Bin , Samad Saleh , Chishti Khalid , Hussain Ashiq , Arafat Mohamed 
Published: December 2007

Abstract
The last few years have seen a renewed emphasis on Well Integrity (WI) worldwide, and ADMA-OPCO in particular.
ADMA operates, more than 600 wells, in two offshore fields, which include oil producers, water injectors, gas producers/injectors and observation wells. A dedicated team was setup to focus entirely on WI and related issues. The team was given the objective to achieve the following. –Determine the Well Integrity Status of the entire well stock through risk review and ranking.–Recommend appropriate action plan for each well with unacceptable level of risk.
The team used a comprehensive and novel approach for handling this project. This paper is a case study of the methodology adopted by the team to achieve this task.
Since the main objective was to risk review and rank the entire well stock, a dedicated risk-ranking process was designed, which served as an automatic guide to risk review and ranking of wells. The industry Risk Ranking matrix was modified to make it more objective and easy to use.
It soon became obvious that risk evaluation of wells was only possible based on availability of good data organized in a user-friendly format. A dedicated database was setup in parallel with other activities. The web-based database was designed to contain all the data required for WI review of any well and is capable of tracking well integrity related tasks automatically.
Well Integrity data included well construction, annuli pressures, production, well intervention, etc. The data existed in the office files were promptly transferred into the database.
The team made a strong effort towards building the capabilities to acquire missing WI data such as Annulus Leak Rates, Integrity Test Results, Wellhead and Xmas Tree status. Annulus leak rate measurement skid was designed and built, in-house. One-off contracts were established to hot tap blind-flanged annuli and to perform Xmas tree and wellhead inventory survey and cavity checking/testing.
A completely new system of WI certification has also been established. So far, the team has successfully reviewed and risk ranked majority of the wells in the two assets of ADMA-OPCO.
New Injection-Allocation Tool Significantly Improves the Value of Water Injection in Large Clastic Reservoirs
Authors: Mandal Dipak , Nik Ahmad Nik Nabilah Bt. 
Published: December 2007

Abstract
Water injection is one of the most commonly used methods for pressure maintenance in clastic and carbonate reservoirs worldwide. Monitoring this injection mechanism has remained essential to understand near term pressure response, evaluate pattern behaviour and injection potential for further expansion if required.
Increasing oil price and thus pressing business needs to produce more than earlier planned, led often to the critical situation of available injection volumes being less than that required to maintain IVRR=1. To reduce potential loss of reserves due to increased drawdown, operators around the world have tried various modes of prioritization of the limited water supply. The intention has been to maximize the value of the available injection.
To develop thus a rationalized prioritization process, a mathematical tool has been developed which calculates the individual reservoir water injection needs and then optimizes them through key ranking criteria. The criteria included voidage replacement ratio, threshold operating pressure above bubble point, conformance loss due to injection out of pay, oil response per barrel of water injected and crude quality. Unique influence functions help to assign weighting factors to each of the criteria and mathematical algorithms have been developed in Excel to allocate injection to each reservoir. This tool has been tested on a number of clastic reservoirs and a more rigorous form is currently in the process of being used in some of the waterflooded reservoirs in Peninsular Malayasia to allocate injection. It thus acts as a successful yardstick for management to ensure maximum value for injection.
This paper summarizes the process of building this allocation tool, describing the different criteria used, the generation of weighting factors from the influence functions and the mathematical algorithms that help to maximize the value of injection water.
Horizontal-Well-Production Logging Experience in Heavy-Oil Environment With Sand Screen: A Case Study From Kuwait
Authors: Oosthuizen Ricardo U. , Al-Naqi Ahmad , Al-Anzi Khalaf , Gok Ihsan Murat , Zeybek Murat , Cig Koksal , Al Hashim Hashim 
Published: December 2007

Abstract
Because flow regimes in highly deviated and horizontal wells are quite different from those of vertical wells, velocity and hold up distribution are required for accurate flow rate and fluid entry determinations in multiphase flow. Production logging in horizontal wells can be challenging due to undulations and completions such as sand screen.
In this paper, we present a field example that utilized advance production logging tool with distributed velocity and hold up distribution using tractor conveyance in sand screen completion. In this job, advanced production logging tool was further integrated with an additional spinner and pulse neutron tool to detect fluids in possible annulus space between screen and open hole. Results were exceptionally good measuring hold up and velocities. All the measurements showed that annulus space was filled with sand and fluid entries were determined confidently. In addition, it was shown that the single spinner in multiphase horizontal flow could not determine velocities of each phase unless totally immersed in one phase. The observations and recommendations were further discussed in this challenging production logging environment.
Missed, Bypassed, and Underestimated Hydrocarbon Traps: Analysis of BHT Records Reveals "Undiscovery Wells" in North Arabia
Authors: Ibrahim Muhammad W. 
Published: December 2007

Abstract
The search for hydrocarbons in Middle Eastern and North African (MENA) countries began essentially as an exploration for giant oil fields, and several exploration wells may have been suspended, plugged and abandoned and declared "dry" under giant-prone early exploration strategies, obsolete logistics, drilling technology, and production methods. Some of these "dry holes" are now proven oil producers or "undiscovery wells". Geothermal gradient anomalies associated with hydrocarbon traps have been recognised since the early days of modern hydrocarbon exploration. The goals of this study are: (1) mapping the geothermal gradients of North Arabia, (2) delineating geothermal gradient fairways and anomalies of oil and gas traps, then (3) identifying and reviewing similar anomalies in the same area as they may be indications of undrilled, under-rated or bypassed hydrocarbon traps.
In this study an exclusive computer programme was used to create BHT database, correct, test the statistical significance of BHT measurements, calculate and plot Compensated Geothermal Gradients (CGG) and Extrapolated Surface Temperature Intercepts (ESTI) of 50 exploration and development wells in the study area covering onshore Kuwait, NW Saudi Arabia, Iraq, and parts of W. Iran, E. Jordan and E. Syria (Long. 39.00 °E to 48.00 °E and Lat. 29.00 °N to 37.00 °N). The study recognised 30 Proven geothermal gradient anomalies of hydrocarbon entrapment (i.e. associated with proven oil and gas fields), and used their model to identify and delineate 3 Potential, 6 Probable and 5 Possible geothermal gradient anomalies of hydrocarbon entrapment in the area.
There are thousands of BHT data dormant in borehole records of every producing basin that can be used in similar analysis to investigate old dry holes for commercially producible traps.
Global hydrocarbon exploration history recorded many cases of early "dry holes" or "dry" anomalies becoming hydrocarbon producers at later dates. Examples are numerous; such as well K1-13 of Libya, which was classified as "dry hole" at completion date, then proved to be an oil producer at later dates is probably one of many potential "undiscovery wells" in Middle Eastern and North African (MENA) countries.
Crosswell Electromagnetic Resistivity Tomography: Pushing the Limits
Authors: Sanni M. L. , Yeh N. , Al-Afaleg N. I. , Kaabi A. O. , Ma S. M. , Levesque C. , Donadille J. M. 
Published: December 2007

Abstract
The cross-well electromagnetic (EM) resistivity method is emerging as one of the technologies that can be deployed for very deep reservoir surveillance/monitoring measurements. It has the potential to provide fluid distribution mapping at inter-well scale, and thus can be used for identification of bypassed hydrocarbon, monitoring of macroscopic sweep efficiency, planning infill drilling and improving effectiveness of reservoir simulation.
A cross-well EM trial is being conducted in an Upper Jurassic carbonate reservoir in Saudi Arabia to monitor the flood-front and fluid distribution with a well separation at the upper limit of the operating envelope allowed by this technology. For best results, current technology limits the maximum distance between wells to circa 1000 m for open-hole to open-hole and 300 m for cased-hole to cased-hole. Extensive pre-job forward modeling was carried out to investigate the feasibility of obtaining useful results from the measurements with such large inter-well spacing. Several scenarios of flood-front movement, such as edge water due to super-K or fracture swarms, bottom water encroachment, coning and cusping, etc., were modeled.
The modeling results were encouraging and many of the anticipated subsurface scenarios were successfully detected.
An Integrated Approach To Efficiently Unlock the Resource Potential in a Large Cluster of Fields
Authors: Kraaijveld Martin A. , Hognestad Jon B. , Samantray Ajay , Udeh Pius , Bulushi Waleed , Cerutti Andres E. , Nijman Madelon P. Y. , Al kindy Zaher , Ibrahim Ayman , Janusz Norbert 
Published: December 2007

Abstract
An integrated study on a cluster of 23 fields in South Oman was performed in the Petroleum Development Oman (PDO) Study Center, in order to derive a coherent view on the cluster development as well as to write (waterflood) FPDs for the individual fields. The study combined conventional and state-of-the-art workflows and was conducted by a large integrated team over a period of three years. The study was conducted in four phases: screening, full field modelling, infra-structure development and FDPs for the 6 large fields and the writing of appraisal / development plans for the remaining 17 fields. This paper describes the workflow and learnings of the study.
Preventive Treatment for Enhancing Water Removal From Gas Reservoirs by Wettability Alteration
Authors: Panga Mohan K. R. , Ismail Suzylawati , Cheneviere Pascal , Samuel Mathew 
Published: December 2007

Abstract
Water blocks and condensate drop out near the wellbore in a gas reservoir can cause rapid production decline. The liquid (water/condensate) is trapped near the wellbore due to strong capillary forces and/or viscous fingering of gas through the liquid. To remove this liquid, alcoholic solvents are injected into the near wellbore area; however, this remedial solution needs to be reapplied in case of any subsequent water or condensate banking in the well. In this paper, we present a preventive and permanent chemical treatment for the removal of water and condensate blocks. Three types of tests have been conducted to evaluate the performance of the chemical system which include contact angle, imbibition and core flow test. A total of 41 chemicals have been tested using contact angle and imbibition tests and only 2 chemicals, A5 and A6 were selected for core flow test as they were stable at high temperature and did not damage the cores excessively during the imbibition tests. The core treated with a solution containing 5% A5 and 95% brine (2-wt% KCl) in the core flow test gave higher clean up of trapped water due to reduction in capillary force. This treatment system also shows a better alteration of the formation wettability from liquid wet to non-liquid wet conditions compared to the other chemical systems tested.
A Novel Approach of Detecting Water Influx Time in Multiz one and Multilateral Completions Using Real-Time Downhole Pressure Data
Authors: Aggrey G. H. , Davies D. R. , Skarsholt L. T. 
Published: December 2007

AbstractIncreasing use of advanced (intelligent) completions has provided the facility for real time reservoir monitoring through use of permanent downhole instrumentation and control of production from different zones within the reservoir through use of surface operated inflow control devices. The potential for the real-time data generated by advanced completion solutions is now being exploited to a greater extent.The paper will demonstrate that trending analysis of the pressure drop (dP trending) using the data delivered by sensors located strategically in a multi-zone horizontal or multilateral intelligent completion can identify the time and location of water influx into a well. It will be shown that "pressure drop trend signatures" can identify the location of the water influx and application of this approach will be illustrated by use of two, three and four zone completions in synthetic reservoirs. A more complex, field based example will also be employed to illustrate the robustness of the technique. Prompt recognition of the influx of unwanted fluid and its location can be achieved using the technique described in this paper.
Recent Advances in the Understanding and Incorporation of the Multiphase Fluid Flow Properties of Fault Rocks Into Production Simulation Models
Authors: Al-Hinai Suleiman M. , Fisher Quentin J. , Grattoni Carlos A. , Harris Simon D. , Al-Busafi Bader S. 
Published: December 2007

Abstract
For many years it has been common practice to adjust fault transmissibility multipliers within production simulation models to achieve a history match without any scientific justification. In effect, this often means that faults are made ‘scapegoats’ to compensate for inadequacies in reservoir characterisation. In recent years it has become increasingly popular to calculate geologically-realistic transmissibility multipliers based upon measurements of absolute fault permeability and fault rock thickness. A key problem with this method is that it does not take into account the multiphase flow properties (relative permeability and capillary pressure) of fault rocks. This is hardly surprising as the multiphase flow properties of fault rocks are still largely unknown. Here we present measurements that show that under reservoir conditions cataclastic fault rocks may often have maximum gas relative permeabilities that are over two orders of magnitude lower than the undeformed reservoir sandstone adjacent to the fault. Incorporating the multiphase flow properties of faults into production simulation models is still challenging as their static and dynamic properties vary significantly compared with the undeformed reservoir. We review different existing methods for incorporating the multiphase flow properties into simulation models, and we recommend some possible approaches for treating faults that improve on the existing knowledge and software.
An Accurate Multiphase Upscaling for Flow and Transport in Heterogeneous Porous Media
Authors: Li Yan , Efendiev Yalchin , Ewing Richard E. , Qin Guan , Wu Xiao-Hui 
Published: December 2007

Abstract
Subgrid effects can have a strong influence on flow and transport in oil reservoirs. In this work a new model for the representation of subgrid terms is introduced and applied to two-phase reservoir flows. The model entails a construction of pseudo relative permeabilities using accurate inlet boundary conditions for the saturation field. Motivation for the form of the model is provided through a consideration of asymptotic techniques for two-phase flow. The numerical computation of the subgrid terms and the implementation of the overall method are described. The accuracy of the new subgrid representation is compared to that of coarse scale models with no subgrid treatment and to coarse models based on traditional pseudo relative permeabilities. In essentially all cases the new model provides more accurate coarse scale predictions relative to reference fine scale results. These are preliminary results.
Analyses of Wellbore Instability in Drilling Through Chemically Active Fractured Rock Formations: Nahr Umr Shale
Authors: Nguyen Vinh , Abousleiman Younane , Hoang Son 
Published: December 2007

Abstract
Numerous time-dependent wellbore instability problems have been reported when drilling through the chemically active Nahr Umr shale formation in the Arabian Gulf. The shale is characterized by the abundance of not only bedding planes at the macro scale but also networks of smaller natural fractures at the micro scale. The presence of fractures weakens the shale mechanically and produces higher permeability fluid flow paths within the low permeability rock formation. Because of different fluid diffusion rates, there are two distinct pore pressure fields in saturated fractured shales. Additionally, in chemically active shale formations, osmotic pressure arises due to the imbalance in mud/shale chemical activity. These facts necessitate a dual-porosity/dual-permeability approach to analytical modeling that incorporates time-dependency, fracture networks, and chemical effects on wellbore stability. However, it is difficult or almost impossible to properly characterize the necessary shale modeling parameters due to the lack of standard-size samples required by conventional testing techniques. In this paper, a comprehensive approach to simulating instability problems for drilling in fractured shale formations from an innovative laboratory characterization technique for "tiny" shale samples to field analytical modeling is presented.