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Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- Research Report > New Finding (0.93)
- Overview (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.72)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- (2 more...)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
Filling borehole image gaps with a partial convolution neural network
Jiang, Lei (University of Science and Technology of China, University of Science and Technology of China) | Si, Xu (University of Science and Technology of China, University of Science and Technology of China) | Wu, Xinming (University of Science and Technology of China, University of Science and Technology of China)
ABSTRACT Borehole images are measured by logging tools in a well, providing a microresistivity map of the rock properties surrounding the borehole. These images contain valuable information related to changes in mineralogy, porosity, and fluid content, making them essential for petrophysical analysis. However, due to the special design of borehole imaging tools, vertical strips of gaps occur in borehole images. We develop an effective approach to fill these gaps using a convolutional neural network with partial convolution layers. To overcome the challenge of missing training labels, we introduce a self-supervised learning strategy. Specifically, we replicate the gaps found in borehole images by randomly creating vertical blank strips that mask out certain known areas in the original images. We then use the original images as label data to train the network to recover the known areas masked out by the defined gaps. To ensure that the missing data do not impact the training process, we incorporate partial convolutions that exclude the null-data areas from convolutional computations during forward and backward propagation of updating the network parameters. Our network, trained in this way, can then be used to reasonably fill the gaps originally appearing in the borehole images and obtain full images without any noticeable artifacts. Through the analysis of multiple real examples, we determine the effectiveness of our method by comparing it with three alternative approaches. Our method outperforms the others significantly, as demonstrated by various quantitative evaluation metrics. The filled full-bore images obtained through our approach enable enhanced texture analysis and automated feature recognition.
- Phanerozoic > Cenozoic > Neogene > Miocene (0.47)
- Phanerozoic > Cenozoic > Neogene > Pliocene (0.47)
- Geology > Geological Subdiscipline (0.86)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.69)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > Wyoming > Uinta Basin (0.99)
- North America > United States > Utah > Uintah Basin > Natural Buttes Field > Wasatch Formation (0.99)
- North America > United States > Utah > Uinta Basin (0.99)
- North America > United States > Colorado > Uinta Basin (0.99)
ABSTRACT Distributed acoustic sensing (DAS) is a technology that enables continuous, real-time measurements along the entire length of a fiber-optic cable. The low-frequency band of DAS can be used to analyze hydraulic fracture geometry and growth. In this study, the low-frequency strain waterfall plots with their corresponding pumping curves were analyzed to obtain information on fracture azimuth, propagation speed, number of fractures created in each stage, and restimulation of preexisting fractures. We also use a simple geomechanical model to predict fracture growth rates while accounting for changes in treatment parameters. As expected, the hydraulic fractures principally propagate perpendicular to the treated well, that is, parallel to the direction of maximum horizontal stress. During many stages, multiple frac hits are visible, indicating that multiple parallel fractures are created and/or reopened. Secondary fractures deviate toward the heel of the well, likely due to the cumulative stress shadow caused by previous and current stages. The presence of heart-shaped tips reveals that some stress and/or material barrier is overcome by the hydraulic fracture. The lobes of the heart are best explained by the shear stresses at 45° angles from the fracture tip instead of the tensile stresses directly ahead of the tip. Antennas ahead of the fracture hits indicate the reopening of preexisting fractures. Tails in the waterfall plots provide information on the continued opening, closing, and interaction of the hydraulic fractures within the fracture domain and stage domain corridors. The analysis of the low-frequency DAS plots thus provides in-depth insights into the rock deformation and rock-fluid interaction processes occurring close to the observation well.
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Greater Peace River High Basin > Pouce Coupe Field (0.99)
- (2 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Use of Resistivity and Density Borehole Image Logs to Identify and Distribute Facies in the Pikka Unit - A Case Study from the Nanushuk Formation, North Slope, Alaska
Perona, Ricardo (Repsol USA) | Armitage, Dominic (Repsol USA) | Bonelli, James (Repsol USA) | Capuzzo, Nicola (Task Fronterra Geoscience) | Tingey, Brady (Task Fronterra Geoscience)
Over the past decade, the North Slope of Alaska has yielded several major hydrocarbon discoveries in deltaic topsets of the Brookian Nanushuk Formation. Together the Nanushuk topsets and genetically related foreset and bottomset beds of the Torok Formation comprise part of a giant clinothem system that prograded across the Colville Foreland Basin during the lower Cretaceous (Aptian through Cenomanian). The discovered Nanushuk topset play contains stratigraphically trapped hydrocarbons within multiple fairways trending roughly north to south along the basins extent. The Nanushuk topset play was first discovered in the Pikka Unit by Repsol and partners during the 2013 winter drilling campaign. The Pikka Unit is located at the eastern edge of the Nanushuk-Torok clinothem system and underlies the modern-day Colville River. Here, the Nanushuk Formation comprises shelf-edge deltaic and shoreface deposits, characterized by intercalations of fine-grained litharenites and silty mudstones. The layered character of the formation is readily recognized in electric logs due to density and resistivity contrasts between those main lithologies. Following the initial Pikka discovery, 14 appraisal wells were drilled in the unit, including 2 horizontal and 2 high angle wells. An extensive and diverse borehole image dataset was acquired and includes wireline high resolution oil-based mud resistivity and logging-while-drilling azimuthal density images. In addition, more than 1000 feet of continuous core was collected in three wells (Qugruk-8, Pikka B, Pikka B ST1). Borehole images were then used to orientate the high resolution CT scan images of the cores, which afterwards were integrated with the image log analysis. This study presents a case on how the integration of core sedimentology and detailed borehole image log analysis were used to guide and predict the facies distribution across the Pikka unit.
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.68)
- Geology > Sedimentary Geology > Depositional Environment > Transitional Environment > Deltaic Environment (0.54)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > Alaska > North Slope Basin > Umiat-Gubik Area > Torok Formation (0.99)
- North America > United States > Alaska > North Slope Basin > Prudhoe Bay Field (0.99)
- North America > United States > Alaska > North Slope Basin > Pikka Unit > Nanushuk Formation (0.99)
- (3 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Borehole imaging and wellbore seismic (1.00)
- North America > United States > Texas (1.00)
- Europe (0.93)
- Research Report > New Finding (0.93)
- Overview (0.88)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
The main objective of this work is to understand the impact of fracture, stress, drilling direction and other reservoir properties on the production performance in horizontal well (HW). Taking advantage of seventy available borehole image logs helped to extend analysis beyond individual wells to a field scale evaluation. Three analysis techniques were developed to progress with the study: Digital Interpretation of Borehole Breakout in image log, Favored Drilling Direction Map, and a Reservoir Property Filter to gauge well performance. Results in cross plots showed complicated, cloudy and multi-dimensional relationships. The findings will be used to guide future HW drilling optimization, support dynamic modeling and improve models predictability for effective reservoir management.
- North America > United States (0.46)
- Asia > Kazakhstan > West Kazakhstan Region (0.29)
- Phanerozoic > Paleozoic > Permian (0.94)
- Phanerozoic > Paleozoic > Devonian (0.68)
- Geology > Structural Geology > Tectonics (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock (0.93)
- (2 more...)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.61)
- North America > United States > California > San Joaquin Basin > Lost Hills Field (0.99)
- North America > United States > California > Monterey Formation (0.99)
- Asia > Kazakhstan > West Kazakhstan > Uralsk Region > Precaspian Basin > Karachaganak Field (0.99)
- (5 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (0.93)
- (5 more...)
A Successful Acid Fracturing Treatment in Asphaltene Problematic Reservoir, Burgan Oilfield Kuwait
Al-Shammari, A. (Kuwait Oil Company, Kuwait) | Sinha, S. (Kuwait Oil Company, Kuwait) | Sheikh, B. (NAPESCO, Kuwait) | Youssef, A. (NAPESCO, Kuwait) | Jimenez, C. (Kuwait Oil Company, Kuwait) | Al-Mahmeed, F. (Kuwait Oil Company, Kuwait) | Al-Shamali, A. (Kuwait Oil Company, Kuwait)
Abstract The Burgan Marrat Reservoir is a challenging high-pressure, high-temperature carbonate oil reservoir dating back to the Jurassic age. This specific reservoir within the Burgan Field yields light oil, but it has a significant issue with Asphaltene deposition in the wellbore. Additionally, its well productivity is hampered by low matrix permeability. Addressing these challenges is crucial, and a successful acid fracturing process can not only enhance well productivity but also address Asphaltene-related problems. This study delves into a comprehensive methodology that was employed. The focus of well selection was on ensuring good well integrity and maintaining a considerable distance from the oil-water contact (OWC). The approach involved conducting a Multi-Rate test followed by pressure build-up to establish a baseline for understanding the reservoir's behavior, including darcy and non-darcy skin. The treatment design aimed at better fluid loss control and initiating highly conductive fractures in the reservoir. Specific measures, such as using suitable diverters and acid, were employed to maximize the length of the fractures. To validate the approach, a nodal analysis model was fine-tuned to predict how the well would perform under these conditions. The results post-stimulation were impressive. There was a substantial improvement in well production and flowing bottom hole pressure. In fact, the productivity index of the well increased significantly, representing a substantial enhancement in output. The pressure build-up test after the fracture demonstrated a linear flow within the fracture, indicating a successful treatment with a fracture half-length of approximately 110 feet and a negative skin, which signifies an improvement in flow efficiency. Furthermore, the treatment effectively mitigated the risk associated with Asphaltene deposition, a significant accomplishment given the historical challenges faced in this reservoir. This success can be attributed to an innovative workflow that incorporated a meticulous surveillance plan, a well-thought-out fracturing treatment design, and the application of advanced nodal analysis. Together, these components not only optimized the well's performance but also paved the way for the development of similar high-pressure, tight carbonate reservoirs. This approach not only enhances productivity but also ensures successful mitigation of Asphaltene-related issues, marking a significant advancement in reservoir engineering techniques.
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Field > Wara Formation (0.99)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Field > Ratawi Formation (0.99)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Field > Mauddud Formation (0.99)
- (15 more...)
In this article, the Editor of G provides an overview of all technical articles in this issue of the journal.
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (1.00)
- Geophysics > Electromagnetic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- (2 more...)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (22 more...)
Distributed Acoustic Sensing (DAS) is a technology that enables continuous, real-time measurements along the entire length of a fiber optic cable. The low-frequency band of DAS can be used to analyze hydraulic fracture geometry and growth. In this study, the low-frequency strain waterfall plots with their corresponding pumping curves were analyzed to obtain information on fracture azimuth, propagation speed, number of fractures created in each stage, and re-stimulation of pre-existing fractures. We also use a simple geomechanical model to predict fracture growth rates while accounting for changes in treatment parameters. As expected, the hydraulic fractures principally propagate perpendicular to the treated well, that is, parallel to the direction of maximum horizontal stress. During many stages, multiple frac hits are visible indicating that multiple parallel fractures are created and/or re-opened. Secondary fractures deviate towards the heel of the well, likely due to the cumulative stress shadow caused by previous and current stages. The presence of heart-shaped tips reveals that some stress and/or material barrier is overcome by the hydraulic fracture. The lobes of the heart are best explained by the shear stresses at 45-degree angles from the fracture tip instead of the tensile stresses directly ahead of the tip. Antennas ahead of the fracture hits indicate the re-opening of pre-existing fractures. Tails in the waterfall plots provide information on the continued opening, closing, and interaction of the hydraulic fractures within the fracture domain and stage domain corridors. Analysis of the low-frequency DAS plots thus provides in-depth insights into the rock deformation and rock-fluid interaction processes occurring close to the observation well.
- North America > Canada > Alberta (1.00)
- North America > United States (0.67)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation Field > Montney Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Montney Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Greater Peace River High Basin > Pouce Coupe Field (0.99)
- (2 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
A Unique Methodology and Successful Implementation While Testing Exploratory Well in Bahrah Field with Several Challenges: A Case Study in North Kuwait
Alotaibi, F. Z. (Kuwait Oil Company, Ahmadi, Kuwait) | Al-Ibrahim, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Ibrahim, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Binsafar, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Alkhulaifi, O. (Kuwait Oil Company, Ahmadi, Kuwait)
Abstract Objectives/Scope This paper presents a unique successful application and implementation of testing procedures in an exploratory cretaceous well in Bahrah field (North Kuwait). Used to evaluate productivity and characteristics of a reservoir and clearly understand the reservoir's potential, which helps in reducing the risks related to developing the field for a long-term with sustainable production, and selecting the optimum completion and artificial lift method. Methods, Procedures, Process The exploratory vertical well BH-X drilled to explore the hydrocarbon potential within the Northern Area of the Bahrah field targeting cretaceous Sandstone formation, with a total drilling depth 10,780 ft. Open-hole logs and collected WL open-hole fluid sample post drilling proved the oil bearing in the sandstone formation. The cement bond evaluation behind slim casing liner showed some doubt in quality in particularly cement image of ultrasonic tool. Decision was taken to proceed with testing without cement remediation, and perform a DST with down-hole real-time pressure gauges. The Formation interval was perforated using dynamic underbalance casing guns post displacing the completion fluid in hole OBM with filtrated brine. The Nitrogen (N2) lifting through Coiled tubing (CT) was used for well activation and to evaluate the well productivity on rig since the well ceased to flow naturally. Since these pressure events and analysis are crucial in making decisions in a low cost environment, It was decided to retrieve the downhole pressure data for preliminary Pressure Transient Analysis (PTA), which indicated that the formation skin was positive. Therefore, acid wash was performed to the sensitive sandstone formation to enhance the production rate. Results, Observations, Conclusions However, the results post the acid wash treatment showed increment in water cut. RIH with Water-Flow Log (WFL) to check the water source and identified channels behind pipe was challenging due to unavailability of E-coiled tubing. Thus, a unique solution was used to achieve a drawdown and dynamic condition while recording conventional WFL against the testing zone by using N2 and utilizing the DST tools functions. WFL results indicated the source of water behind casing above the test interval. Therefore, a cement squeeze job was performed and cement bond log was recorded again post the remedial job, which confirmed a good improvement in cement bond. The targeted interval was re-perforated utilizing dynamic underbalance perforation with STIM guns, the well was activated by CT using N2 lifting and showed clear improvement in production with zero water cut. Novel/Additive Information Overall, a unique methodology while using real time data has delivered better decision making and operational capabilities during rig and testing operations, which assists in reducing well testing operations cost and time.
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Bahrah Field > Marrat Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.98)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.98)