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The interpreted pressure transient test is a primary source of dynamic reservoir data. Tests on oil and gas wells are performed at various stages of drilling, completion, and production. Most pressure transient tests can be classified as either single-well productivity tests or descriptive reservoir tests. Productivity tests are conducted to: * Determine well deliverability * Characterize formation damage and other sources of skin effect * Identify produced fluids and determine their respective volume ratios * Measure reservoir pressure and temperature * Obtain representative fluid samples suitable for PVT analysis * Evaluate completion efficiency * Evaluate workover or stimulation treatments. Descriptive reservoir tests are conducted to: * Assess reservoir extent and geometry * Determine hydraulic communication between wells * Characterize reservoir heterogeneities * Evaluate reservoir parameters.
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Abstract This paper focuses on production forecasting of a tight oil reservoir using numerical sector modeling technique and its advantages over conventional decline curve analysis (DCA) and material balance methods. Sector modeling has resulted in better control over prediction as compared to the actual performance. This is mainly due to better understanding and handling of vertical reservoir heterogeneity and pore pressure depletion, where in, the later is treated as an implicit constant thereby falling short of capturing pore pressure changes and resulting impact over well rates and drainage areas. A well was drilled in the South Indus basin to explore, assess, and produce hydrocarbons from cretaceous age sandstone reservoirs. This field has a complex structure due to multiple splay faults. The well logs indicated hydrocarbon and perforations were carried but the well did not flow naturally due to tight nature. Hydraulic frac was executed and well was commissioned on Artificial lift and produced at optimized rate of ~180 Bopd. A pressure buildup survey was also carried out which indicated ~1 mD permeability. The objective of this study was to determine the reliable tool for prediction of tight oil fields and evaluate future development scenarios. Analytical approaches including conventional Material balance & DCA as well as numerical simulation technique was adopted for performance prediction. Therefore, material balance and DCA was performed based on available data, and subsequently, a sector model was developed using commercial simulator. Sufficient structure around the wellbore was imported in the static modeling package wherein the grid model was created having vertically varying layers based on interpreted well logs. All the available petrophysics, PVT, pressure and production data were incorporated in the sector model along with completion and history details. The numerical model predictions are more realistic as compared to conventional methods. Comparison with actual performance of the well for ~1 year shows that it is closely in agreement with prediction from numerical model whereas results from analytical methods were showing pessimistic forecast with significant offset from actual well rates. The calibration of numerical model with the actual performance provided confidence on the model for field development. To develop and optimally produce the field, various sensitivities were run on the model which concluded drilling of a new horizontal well in the structure with multi-stage fracs to be the best option for improving production rate and significant recovery from the field. This study concludes that for tight oil reservoirs, conventional analytical methods such as material balance or DCA do not provide adequate results in comparison to numerical reservoir simulation technique. Even simple grid model is best suited because it incorporates reservoir heterogeneities, important structural complexities, overall acreage and can better predict dynamic behavior of these reservoirs. This case study is unique in comparison with the conventional sector modelling in a way that it captures the structural shape, different petrophysical properties for each layer based on well logs & offset core data, and also involves the history match of available data. It also effectively captures the impact of hydraulic fracturing in the well, hence helps to create realistic production profiles.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.69)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Production forecasting (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Multi-Stage Hydraulic Fracturing Using High- Temperature Fracturing Fluids in the Deepest Offshore Well in China- Case Study of Lab Test and Field Execution
Feng, Yi (CNOOC China Limited Tianjin Branch, Tianjin, China) | Zhang, Ming (CNOOC China Limited Tianjin Branch, Tianjin, China) | Li, Junbao (CNOOC EnerTech-Drilling & Production Co., Tianjin, China) | Zhang, Bo (CNOOC China Limited Tianjin Branch, Tianjin, China) | Hu, Lipeng (CNOOC China Limited Tianjin Branch, Tianjin, China) | Wang, Yisheng (CNOOC EnerTech-Drilling & Production Co., Tianjin, China) | Zhang, Xuefeng (CNOOC China Limited Tianjin Branch, Tianjin, China) | Liang, Tian (Halliburton China, TEDA, Tianjin, China) | Wang, Zichao (Halliburton China, TEDA, Tianjin, China) | Feng, Liang (Halliburton China, TEDA, Tianjin, China) | Wuauthor, Changhong (Halliburton China, TEDA, Tianjin, China)
Abstract Bohai Bay is one of the world's largest oil and gas fields, consisting of different reservoirs with multiple lithologies. BZ condensate oil and gas reservoir is discovered in recently past years. It is planning to develop this field in future years. This field are fractured buried hill condensate gas reservoir, buried deeply and it is not property researched. Several Wells drilled at early stage of the production schedule is not stable and economic value is not enough, so hydraulic fracturing technology is needed to realize the maximization of the production. Due to the well was deep with extremely high temperature and high pressure, the choice of the method of completion, fracturing process design and the realization of the project are challengeable. When the target well depth over 5000m with temperature over 195 °C, we usually use metal crosslinked fluids, particularly using CMHPG and crosslinked with Zirconate crosslinker designed for high temperature. This system delivers a great combination of benefits: availability, low cost, ease to use, high viscosity, and fluid recovery. BZ 9 well is the deepest offshore in China by far. We finish the multi-stage hydraulic fracturing using High-temperature fracturing fluids. We conduct DST test, production evaluation, DFIT Test, Hydraulic Fracture for BZ 9 well. Data analysis and caliber the production evaluation is also tried to do. The high temperature fracture fluid stability test, break test, surface tension test, core perm recovery test is shown is this article. At the same time, also show the well fracturing design idea and method of pump schedule, fracturing model result, DFIT and SRT process, understanding of the reservoir, display and analysis of fracturing plot, the full 3D GRID- ORIENTED HYFRAULIC FRACTURE STIMULATOR corrective, the analysis of the pressure plot, flowback and production, and further suggestions are put forward.
- Asia > China > Bohai Basin (0.99)
- North America > United States > Louisiana > China Field (0.96)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Abstract Diagnostic fracture injection tests contain critical information for reservoir characterization and hydraulic fracturing design, defining every input and output of the simulation modeling process. They help to assess the expected fracture geometry, proppant pack conductivity, formation flow capacity, and optimum hydraulic fracture design. At the same time, these data provide the necessary means to place a frac job adequately. However, interpretation challenges and inherent modeling nonuniqueness demonstrate the need for more constraints to reduce the solution space. Proprietary workflows have been applied using a 3D planar shear decoupled hydraulic fracture simulator to several vertical wells in the Vaca Muerta play in Argentina. The generated information makes it possible to build models consistent with multiple independent measurements from bottom-hole gauges, near wellbore, and far-field assessments of fracture geometry, which permit us to better understand production performance of the wells. The proposed workflow can be utilized to collapse the learning curve in a significant and meaningful way, playing a vital role in the optimization of horizontal wells and the field development strategy.
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Aguada de la Arena Block > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Aguada Federal Block > Vaca Muerta Shale Formation (0.99)
- (3 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Field Wide Intervention-Less Reservoir Pressure Data Acquisition through the Application of Echometer – A Case Study
Basri, Abdul Hakim (Petronas Carigali Sdn. Bhd.) | M Noordin, Fuad (Petronas Carigali Sdn. Bhd.) | Zainul, Zaimi (Petronas Carigali Sdn. Bhd.) | Hassan, Faidzal Haslah (Petronas Carigali Sdn. Bhd.) | Chin, Alvin Zhi Siang (Petronas Carigali Sdn. Bhd.) | Ho, Dylan Zhe Xin (Petronas Carigali Sdn. Bhd.) | Haslan, M Hanif (Petronas Carigali Sdn. Bhd.)
Abstract This paper aims to present a field-wide case study that explores the use of Echometer survey as an alternative method for acquiring static reservoir pressure data. In Field X, located in the East Malaysia Region, conventional static gradient surveys (SGS) were typically deployed to measure the static reservoir pressure. However, conducting SGS in Field X posed challenges related to balancing data acquisition with production enhancement activities, limited operation windows availability, and minimizing production deferment. The Echometer application addresses these challenges by offering non-invasive data acquisition with minimal equipment requirements. The Echometer application employs a non-invasive approach by shooting acoustic waves into the well. As these waves travel downward and encounter any abrupt changes in the well, some of the waves are reflected towards the surface. By analyzing these reflections, which indicate disturbances to the acoustic waves, the fluid level inside the tubing can be determined. By combining this information with shut-in tubing head pressure (SITHP) and fluid gradient measurements, the static reservoir pressure can be estimated. In Field X, 17 surveys targeting 14 different reservoirs were conducted using the Echometer, and the results were compared with available permanent downhole gauge (PDG) data, reservoir pressure trends, and the latest SGS conducted to assess the reliability of the application. The Echometer campaign has demonstrated its effectiveness and reliability in determining static reservoir pressure. It can be considered as an alternative to SGS in fields with limited wireline windows due to its minimal equipment requirements, minimal production deferment, and absence of invasive well intervention. A presentation and discussion on the successful outcomes, limitations, best practices, and lessons learned from the Echometer campaign aim to contribute to the repertoire of production surveillance tools in the oil and gas industry by providing alternatives to conventional SGS for data acquisition.