bluuebunny/crossref_metadata_2025_split huggingface dataset:
Yakin West Waterflood Project: Looking for Opportunity To Maximising Recovery
Authors: Yamin M. , Yuliraharjo A. , Zahar R. U. , Saifuddin F. 
Published: December 2007

Abstract
The Yakin West Waterflood project, which commenced in 2000, applied on depleted reservoir 19-6 and 21-2 sands which had a forecast primary recovery of 27%. The business case scenario resulted from reservoir simulation, which demonstrated possible recovery enhancement (EUR) of up to 39 %. However, during the implementation, the waterflood system did not maintain the minimum design injection rate of 10,000 BWPD, and injection rate declined to 1,000 BWPD within 2 years. Processing low quality sea water caused the waterflood unit frequent shut-downs, necessitating higher preventive maintenance. Consequently, waterflood response delayed for six months and injectors plugging was common. Due to these adverse circumstances, expected ultimate recovery from the project as implemented is forecast to be 33%.
A 3D reservoir model and simulation was developed to evaluate Yakin West Waterflood performance, incorporating a revised geological interpretation, recent production and injection history, and pressure surveys. Full integration between the geo-model and the reservoir flow model was implemented successfully in this project. Using the reservoir model, the reservoir properties distributions were generated for alternate development scenarios. The reserves ranges primarily reflect in trapped saturation that effecting remaining oil to be drainned, and variation in water rate. An assessment of the robustness of the history match to grid size and facies distribution was also undertaken. This model was used as a tool for evaluating further well work activities and infill drilling opportunities. This methodology for obtaining accurate prediction of these outcomes has furthered our understanding of field performance and forecasting methods.
A Fracture Treatment Design Optimization Process To Increase Production and Control Proppant Flowback for Low-Temperature, Low-Pressure Reservoirs
Authors: Krismartopo B. D. , Notman L. , Kritzler T. , Kristanto T. , Nguyen P. 
Published: December 2007

Abstract
As the pumping pressure is released at the end of a fracturing treatment, the proppant remains in the fractures, holding them open and forming conduits for fluid to flow into the wellbore. If the proppant flows back into the wellbore, the width of the fracture channels will decrease. The loss of proppant from the fractures limits the flow-channel conductivity, choking the production potential of the well and impairing the effectiveness of the fracture treatment.
Resin-coated sands, oriented perforating, tip screen-out designs, and screens are just some of the technologies that have been applied in the past to overcome the aforementioned problem. For low-temperature, low-pressured reservoirs, the challenges increase because even small pressure drops or conductivity reductions can have a large influence on the final production results, and resin-coated sand will not cure effectively at temperatures below 130°F.
This paper highlights how a proppant production problem was successfully overcome through the application of several technologies. Statistical analysis was used to help evaluate these technologies during the trial period, indicating that orientated perforating had a limited influence on the proppant flow-back, but a negative impact on production. However, with the help of a tip screen-out design and a newly developed proppant flow-back control additive, the proppant flow-back problem was overcome and production was improved.
A Proposed Data Acquisition Program for Successful Geomechanics Projects
Authors: Chardac O. , Murray D. , Carnegie A. , Marsden J. R. 
Published: December 2007

Abstract
There has been a growing interest in geomechanics in the oil industry. From simple rock mechanical properties to fully coupled reservoir geomechanics simulation, real-time wellbore stability monitoring, stimulation job design, or sand management, the value of geomechanics has now been demonstrated and is applicable throughout the entire life of a field. Because it has become a key component for a number of departments, geomechanics is now considered a discipline by itself, and most of the major oil companies have established their own teams of rock mechanics experts.
The mechanical earth model is the core of any geomechanical work. It is an integration process characterizing the field in terms of rock mechanics properties. Like any other type of project, it requires a minimum amount of specific information to be successful. Practically speaking, because data acquisition programs rarely focused on rock mechanics aspects in the past, it often appears that part of the key data required to perform a proper evaluation is not available. In such a case, one may have to use correlations to estimate the missing information or apply default parameters with their associated uncertainties. Ultimately, there is no equivalent to real data to ensure the accuracy of any study.
The paper summarizes the data requirements for a reliable mechanical earth model and proposes a standard data acquisition program that would guarantee the availability of critical information. It will demonstrate that most of the data required are needed for other disciplines as well. The key is to make sure it is systematically acquired.
First Installation of Hydraulic Flow Control System (Smart Completion) in Saudi Aramco
Authors: Al-Dossary A. S. , Salamy S. P. , Mubarak H. K. , Al-Aqeel S. A. , Boyle M. S. 
Published: December 2007

Abstract
Saudi Aramco has successfully installed the first Hydraulic Down Hole Flow Control System in Saudi Arabia in March 2004, in Shaybah field. In 2002, Saudi Aramco optimized its drilling strategy by drilling Maximum Reservoir Contact (MRC) wells in Shaybah field to improve well productivity by providing maximum reservoir contact and to reduce the development unit cost of drilling and production. In addition, it was necessary to equip selected wells with the options of laterals isolation and a flow control system in order to maximize the benefits of these wells.
The objectives of using such a system are to improve the reservoir's management, increase the life of the well and to avoid intervention.
This well was drilled as a multilateral (Tri-lateral) well targeting one reservoir with total reservoir contact of 8.7 km (28,670 ft). This paper will discuss the difficulties that were encountered during the planning, drilling, and finally installation and testing of the system. Extraordinary efforts were made to ensure the success of this system as it has a great impact on future installations of such technology in Saudi Arabia.
Evaluation and Implementation of Coating Damage and Repair Techniques: A Case Study on 36-in. Badak-Bontang Pipeline
Authors: Priambudi A. , Tranggono N. W. , Somoprawiro S. , Sanjoto P. D. 
Published: December 2007

Abstract
Base on the intelligent pigging survey result, it is believed that the external corrosion was caused by disbondment of the asphalt enamel coating on the 36″ Badak-Bontang pipeline. An electromagnetic technology method is selected to locate and measure the coating damage level. In conjunction with the coating damage evaluation, coating repair was also being assessed. Following field demonstrations from various vendors, a liquid epoxy coating was finally selected, due to its performance, ease of application and relatively long pot life.
Following the receipt of the final coating survey report, the defective areas along the pipeline were positively identified, and excavated for verification. The pipe which have coating damage were repair by removing the existing coating, cleaned back to bare steel to allow application of the new liquid epoxy coating.
This was an excellent example where research, field-testing and evaluation through good engineering practices have resulted in significant cost savings.
Advanced Hydraulic Fracturing Treatments in the Wushenqi Low-Permeability Gas Field: A Workflow to Minimize the Learning Curve
Authors: Lei Qun , Tao Lu , Liu Hai , Tibbles Raymond , Guo Wei , Hou Hui Jun , Ramsey Lee , Meisenhelder Jeff 
Published: December 2007

Abstract
The Wushenqi gas field is a low permeability gas play under development by the Changqing Oilfield Company of PetroChina (PCOC). The first well in this field was drilled and hydraulically fractured in 1994. Out of the ten wells initially drilled, nine were hydraulically fractured using a design based on historical knowledge and area best practices. The average gas production of the 10 wells was 586000 scf/day (16,600 m3/day), which was less than the production required for economical development of the field.
This paper details how Changqing Oil Company and Schlumberger used an optimization workflow and integrated study to improve the completion procedure and increase well productivity.A new field development plan was created based on the following: Advanced seismic interpretation.Geological and petrophysical analysis.Analysis of postfracturing production data.Production forecasts from a new reservoir model and a model of hydraulic fracturing optimization.Completion optimization.Economic evaluation.
Some of the significant results from the study include: An improved understanding of the location of the sand bodies resulting in better control on placement of new wells.A correlation which adjusted the log- derived permeabilities in order to more closely match permeabilities obtained from transient testing and production analysis.An improved well design reflecting data acquisition, fracturing process, and production requirements.A modified fracturing treatment design tailored for the expected Kh and deliverabilty requirements of the various zones.An on-site test program using pre-fracture treatment injection testing to verify the permeability.
A Type of Advanced Mud-Hammer Applied to Oil Drilling
Authors: Jian Z. , Shang J. 
Published: December 2007

Abstract
A kind of percussion rotary drilling system applied to oil drilling, which includes a mud-actuated hammer as a key element. The overall goal of this system is to rise up the ROP and to provide significant cost reduction and technical advantage over current drilling practice particularly in deep, medium-to-hard rock formations. This paper describes a new type of efflux mud hammer, its structure principle and latest experiment results in some detail.
Reservoir Characterization Through Single-Well Numerical Simulation Study Using DST Matching for a Gas-Condensate Reservoir
Authors: Ariadji T. , Suryanto H. , Mariani S. 
Published: December 2007

Abstract
This paper applies a single well numerical model using a reservoir simulator and accommodating geological data such as depth structure, gross and net thickness, and distribution of petrophysical properties to interpret a DST data. History matching pressures and rates of the DST data is conducted after incorporating the geological, reservoir engineering, and production data.
In this single well simulation study, three DST data from well North Belut 3 are as the matching target used in the history matching using commercial numerical simulator with black oil formulation and three dimensional models. The PVT data is generated from an EOS model in which pseudoization is applied to reduce the components into 9. A one and a half foot model, or total of 1309 Z-grid dimension, is used to accommodate facies inconsistency and fluid gradient changes. Capillary pressures are obtained from mercury injection laboratory experiment of samples from four wells and are distributed according to permeability range values. On the other hand, the permeability curves are generated using the Corey function.
The interpretation through the history matching process is described in steps to show advantages of using this method. Correct PVT fluid type, absolute permeability, and skin factor are the most affected on the pressure and rate matching process. The steps could explain and improve the understanding of reservoir characterization. The results are also compared with the analytical interpretations, which study is already done before by other person, to see the reliability. A good agreement on the permeability value is gained, with a possiblility of different net to gross ration interpretation. The skin factors of the numerical method are reasonably positive values, and tend to much less than the analytical results. This SPE-93218 suggests that the near well bore damage may not as bad as the analytical interpretation implied.
A Novel Approach for the Evaluation of Oil and Gas Well Performances in Multiwell Reservoir Systems
Authors: Marhaendrajana T. 
Published: December 2007

Abstract
The current methods for estimating Oil- or Gas-In-Place and Reservoir Flow Capacity using dynamic data (pressure and/or rate) assume a single well in a closed system (or single well with constant pressure or prescribed influx at the outer boundary). In many cases a well produces in association with other wells in the same reservoir – and unless all wells are produced at the same constant rate or the same constant bottomhole flowing pressure, non-uniform drainage systems will form during boundary-dominated flow conditions.
The approach presented in this paper accounts for the entire production history of the well and the reservoir and eliminates the influence of well interference effects. This approach provides much better estimates of the in-place fluids in a multiwell system, and the methodology also provides a consistent and straightforward analysis of production data where well interference effects are observed.
This paper also presents the computation of flow capacity and skin factor using the multiwell approach.
Pressure Transient Results Demonstrate Utility of Cased-Hole Formation Tester
Authors: Joshi S. , Siwindono T. , Bunyamin M. , Basya D. , Harun H. , Krisna R. 
Published: December 2007

Abstract
Gunung Kemala is a mature oilfield located in South Sumatra province of Indonesia, which was discovered in 1937 by the Royal Dutch company and is currently owned by the Indonesian national oil company, Pertamina. Declining field production led Pertamina to target some previously unexplored deeper reservoirs in this field, termed as the "Upside Potential" zones. Drilling the wells was a challenging task because of the combined presence of depleted reservoirs and virgin zones. Hence acquiring correct pressure information was a primary objective in the re-evaluation plan.
Openhole wireline formation testing was ruled out due to the experience of high sticking risks in this environment. Pertamina had earlier tested these reservoirs using drillstem tests (DST's). However, the DST's had been extremely expensive and time consuming, due to the many layers that needed testing, and were sometimes inconclusive.
Consequently Pertamina decided to try out a new wireline conveyed cased-hole formation tester capable of drilling a hole through casing, measuring formation pressure, identifying formation fluids, capturing PVT samples and finally plugging the hole with a metal to metal seal. This could significantly reduce testing time as well as the chances of tool sticking. Another objective was to obtain formation radial permeability for the tested zones. Therefore, the testing program was designed to incorporate an extended pressure buildup (PBU) test for each zone.
This methodology was applied in 2 wells, GNK-X3 and GNK-X4, of the field. A total of 6 points were successfully drilled, formation pressures measured, reservoir fluids identified in real time and 6 PVT samples captured. Extended PBU's were also carried out at each point till radial flow was reached and radial permeabilities calculated. All but one of the zones tested as hydrocarbon bearing. In one well, 2 hydrocarbon-bearing zones with a large difference in pressure and permeability were identified. This led Pertamina to run a dual completion for optimum exploitation of the zones.
This cased hole formation testing program reduced the risk for Pertamina's operations and successfully achieved testing objectives in an efficient and economical manner as compared to conventional methods.
Effect of Quasi-Piston-Like Flow on Miscible Gasflood Recovery
Authors: LaForce T. , Johns R. T. 
Published: December 2007

Abstract
Multi-contact miscible (MCM) displacements of single-phase reservoir fluids are designed to achieve piston-like flow and optimal recovery of in-situ hydrocarbons. Piston-like displacements occur when the reservoir pressure is greater than the minimum miscibility pressure (MMP) or the gas is enriched beyond the minimum miscibility enrichment (MME). The effect of two hydrocarbon phase reservoir fluids on piston-like flow and recovery in MCM displacements have not been considered in detail in theoretical or experimental research. The consequences of two in situ phases may be significant for displacements in capillary transition zones, vertically-graded compositional reservoirs, surfactant floods, or gas condensate reservoirs.
The primary goal of this paper is to explore the ramifications of leading condensate or gas banks on recovery in MCM floods with two-phase initial conditions. We develop detailed method of characteristics (MOC) solutions for 1-D displacement of two-phase initial compositions by gases that are enriched below and above the MME. We consider ternary and quaternary systems to examine the effect of combined condensing/vaporizing (C/V) behavior on recovery.
The results show that in MCM displacements, recoveries can be seriously affected by the presence of two-phase initial reservoir fluids for injection times less than 1.0 PVL The delay in heavy component recovery is substantial for intermediate and large initial gas saturations and could significantly impact the economics of gas injection projects. The results also show that recoveries during dispersion-free MCM flow are affected by relative permeability for injection times less than 1.0 PVL Because flow is MCM, however, recovery increases rapidly to 100% at 1.0 PVL
Gas flood-Flow Pattern Evaluation: Mesozoic Chiapas-Tabasco Basin Field Revisited
Authors: Mercado M. , Martinez B. , Asadi M. , Casas D. R. 
Published: December 2007

Abstract
A gas interwell tracer program was designed and implemented to characterize the flow stream within the current injection/production pattern of the central part of the Mesozoic Chiapas-Tabasco Basin.The field includes one injector and four producers.Due to production, the average reservoir pressure fell and approached the dew point at reservoir conditions.Natural gas was injected to maintain reservoir pressure and optimize condensate production.A chemical interwell tracer was also injected to detect and evaluate the magnitude of any communication between the injection and production wells and to track the areal flow pattern within the field.The study was designed for 18 months and commenced in December 2000 and terminated in mid 2002.The results from the sample analyses provided information on the magnitude of highly permeable channels between the injector and producers as well as flow patterns within the field.Furthermore, the results provided valuable information on breakthrough time and fluid travel time.Sampling discontinued for over a year.In late 2003, it was decided to collect more samples from the same four production wells as well as one of the offset wells.The new sample analysis results indicated tracer concentrations at high levels from all of the wells except one.Based on these new results, a new sweep efficiency and total volume swept between the injection and production wells were calculated and are presented.Finally, an overview of formation heterogeneity, based on the three years interwell tracer study, is presented.
New Step Rate Test Analysis Technique Aids Determination of Fracture Pressure for Waterflood Design in Kuwait Reservoirs
Authors: Mandal D. , Qazi A. , Abdullah S. , Bu-Qurais A. , Hughes S. 
Published: December 2007

Abstract
Zubair and Upper Burgan are important clastic reservoirs in North Kuwait. Phase 1 of the North Kuwait Waterflood Project includes peripheral water injection for pressure maintenance of these reservoirs. Injection at matrix conditions commenced in mid 2001 and though initial injection rates were promising, injectivity declined rapidly in many wells. Various remedial actions were unsuccessful in achieving sustained injection at desired rates. Subsequently, a series of Step Rate Tests were conducted which indicated that desired injectivity could be achieved if injection was above fracture conditions. Consequently, measurement of fracture pressures for the reservoirs assumed key importance for forward planning and design of injection facilities for Phase 2 of the Waterflood Project.
However, it was found that interpretation of fracture pressures from the step rate tests was difficult in certain cases, using the classic approach of rate vs pressure plots, because the change in slope above fracture pressure was very subtle, leading to uncertainty in fracture pressure determination. To facilitate interpretation and reduce this uncertainty, a new diagnostic technique was developed.The technique involves plotting and analyzing the cumulative change of rate per unit pressure against bottom hole injection pressure. This provides more accurate interpretation of the data in those cases where slope change is difficult to interpret using the classic approach. As a result, the technique has ensured full use of the available data, which otherwise would have been inadequate for confident determination of the fracture pressure of the reservoirs. The results obtained are critical for determination of well head injection pressures for the design of surface injection facilities for Phase 2 of the waterflood project.
This paper summarizes the application of this new technique and demonstrates its distinct advantage over classic industry methodology in cases where fracture pressure analysis would otherwise be problematic.
Peciko Geological Modeling: Optimizing Fluid Distribution and Model Resolution of a Giant Gas Field in a Shale-Dominated Deltaic Environment
Authors: Samson P. , Dewi-Rochette T. , Lescoeur M. 
Published: December 2007

Abstract
A Geological model is the image of the understanding of a field according to available data. Through time new data allow generating more detailed models. Peciko Gas field is interpreted as complex shale dominated deltaic environment deposit. Modeling strategy is pragmatic, based on a 2D approach. Its resolution is optimized through time. Methodology focuses on multi-disciplinary data integration for interpreting and modeling fluid distribution. Final goal is to provide reservoir model with major flow barriers.