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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)
- 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)
Summary The heterogeneity of tight reservoirs, along with their complex geologic characteristics and the diverse completion practices used, presents challenges in developing accurate models to forecast the productivity for multifractured horizontal wells (MFHWs) completed in these reservoirs. This paper introduces a new early-time diagnostic tool that leverages early-time two-phase flowback data to forecast long-term productivity and evaluate completion efficiency. To achieve this, two novel models were developed. The first model, the water/oil-ratio model (WORM), uses a hybrid analytical and data-driven approach to describe the observed log-linear relationship between water/oil ratio (WOR) and load recovery (amount of fracturing water produced back after hydraulic fracturing operations) as an analogy to the log-linear relationship between the water/oil relative permeability ratio and water saturation. Next, a neural network is used to couple WORM parameters with key petrophysical properties to analyze the impact of fracture and formation properties on WOR performance, predict WOR as a function of load recovery, forecast ultimate load recovery, and estimate effective fracture volume and initial water saturation in fracture. The second model, the cumulative oil production model (COPM), is a data-driven model that predicts oil production as a function of load recovery during the matrix-dominated flow regime. The application of WORM and COPM on Niobrara and Codell formation wells showed that Codell wells generally exhibit better load recovery and larger effective fracture volume compared with Niobrara wells, but both formations exhibit similar oil recovery performance, indicating independent flow regimes within the effective fractures. The effective fracture volume estimated by WORM was validated against the estimated volume from recorded microseismic events. The results also showed that using the same completion practice to achieve a similar effective fracture volume in child wells does not necessarily lead to similar oil productivity. This paper introduces a holistic workflow that links early two-phase flowback data with well productivity and completion efficiency and is anticipated to aid petroleum engineers in optimizing hydraulic fracturing operations.
- North America > United States > Texas (0.93)
- North America > United States > Colorado (0.66)
- Research Report > New Finding (0.93)
- Research Report > Experimental Study (0.67)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.41)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Codell Formation (0.99)
- North America > United States > Texas > Anadarko Basin (0.99)
- North America > United States > Kansas > Anadarko Basin (0.99)
- (10 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- (2 more...)
Microfluidics for Carbonate Rock Improved Oil Recovery: Some Lessons from Fabrication, Operation, and Image Analysis
Duits, Michel H. G. (University of Twente, Physics of Complex Fluids Group (Corresponding author)) | Le-Anh, Duy (University of Twente, Physics of Complex Fluids Group) | Ayirala, Subhash C. (Exploration and Petroleum Engineering Center - Advanced Research Center (EXPEC ARC)) | Alotaibi, Mohammed B. (Exploration and Petroleum Engineering Center - Advanced Research Center (EXPEC ARC)) | Gardeniers, Han (University of Twente, Mesoscale Chemical Systems Group) | Yousef, Ali A. (Exploration and Petroleum Engineering Center - Advanced Research Center (EXPEC ARC)) | Mugele, Frieder (University of Twente, Physics of Complex Fluids Group)
Summary After the successful implementation of lab-on-a-chip technology in chemical and biomedical applications, the field of petroleum engineering is currently developing microfluidics as a platform to complement traditional coreflooding experiments. Potentially, microfluidics can offer a fast, efficient, low-footprint, and low-cost method to screen many variables such as injection brine composition, reservoir temperature, and aging history for their effect on crude oil (CRO) release, calcite dissolution, and CO2 storage at the pore scale. Generally, visualization of the fluid displacements is possible, offering valuable mechanistic information. Besides the well-known glass- and silicon-based chips, microfluidic devices mimicking carbonate rock reservoirs are currently being developed as well. In this paper, we discuss different fabrication approaches for carbonate micromodels and their associated applications. One approach in which a glass micromodel is partially functionalized with calcite nanoparticles is discussed in more detail. Both the published works from several research groups and new experimental data from the authors are used to highlight the current capabilities, limitations, and possible extensions of microfluidics for studying carbonate rock systems. The presented insights and reflections should be very helpful in guiding the future designs of microfluidics and subsequent research studies.
- North America > United States (1.00)
- Asia > Middle East (0.67)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.81)
- Geology > Mineral > Carbonate Mineral > Calcite (0.53)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (4 more...)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 211167, โSelective and Reversible Water-Shutoff Agent Based on Emulsion System With Nanoparticles Suitable for Carbonate Reservoirs at High-Temperature and High-Salinity Conditions,โ by Masashi Abe, SPE, Jumpei Furuno, and Satoru Murakami, Nissan Chemical Corporation, et al. The paper has not been peer reviewed. _ The complete paper presents the evaluation results of a water-shutoff (WSO) agent based on an emulsion-type chemical material with nanoparticles. The WSO agent, which the authors call an emulsion system with nanoparticles (ESN), has several advantages to existing polymer and gel materials, including high thermal stability, low sensitivity to mineralization, thixotropic characteristics, selectivity of blocking effects for oil and water, and reversibility of blocking effects. In WSO applications, these properties of ESN could be well-suited for improved oil recovery. Introduction ESN is recognized as a proven technology for carbonate reservoirs. However, the reservoir under study did not feature harsh conditions; therefore, this work evaluated ESN potential for carbonate reservoirs in the UAE typically having high-temperature and high-salinity conditions. A primary purpose of the technology, aside from improved oil recovery, is contributing to greenhouse-gas emission reduction and building competitive low-CO2-intensity oil-brand value. In general, produced water volume dramatically increases in maturing oil fields. Reducing water production also can contribute to saving water injection from a reservoir-voidage-replacement viewpoint. Therefore, the functional chemical WSO concept has a significant effect on contributing to the International Energy Agencyโs sustainable development scenario. Materials and Physicochemical Property Tests Oil, Water, and Carbonate Core. Dead oil is sampled from an offshore carbonate field in the Middle East containing light crude oil (32.3 ยฐAPI). Brine and plug core properties are summarized in Tables 1 and 2 of the complete paper. For thermal-stability tests, both brines were used for making the ESN. The WSO coreflood tests used the ESN made with injection water. Advanced Features of ESN. Rheology. The viscosity of ESN is controllable by changing the water/oil ratio; viscosity becomes lower with increasing oil content and higher with increasing water content. These components were stirred, and two ESN samples were prepared using Crude Oil A (from Oil Field A, UAE) or diesel oil. The samples are referred to as Crude Oil A-based ESN and Diesel Oil-based ESN in this paper. Both ESN samples showed similar viscosity curves; such thixotropic characteristics are an important property of ESN. ESN is flowable at stirring conditions. In particular, the viscosity of ESN can be decreased to less than 50 cp at high shear rates, so it can be injected into the reservoir by pumping. On the other hand, ESN becomes highly viscous and less flowable when no energy is applied to it (the ESN surface looks semisolid in this condition). In field operations, the viscosity of ESN decreases depending on the pressure generated by injection pumps on the surface. However, the injection pressure also releases in a radial direction from the bottomhole zone. As a result, ESN recovers a high-viscosity state because of decreasing shear rate with pressure release.
Development of Novel Thermoactive Polymer Compositions for Deep Fluid Diversion Purposes
Veliyev, E. F. (OilGasScientificResearchProject, Institute, SOCAR, Baku, Azerbaijan / Composite Materials Scientific Research Center, Azerbaijan Sate University of Economics, Azerbaijan) | Aliyev, A. A. (OilGasScientificResearchProject, Institute, SOCAR, Baku, Azerbaijan) | Poladova, G. Sh. (OilGasScientificResearchProject, Institute, SOCAR, Baku, Azerbaijan)
Oil and gas production is a vital component of the global economy, serving as the primary source of hydrocarbons, which are not only essential for various products but also as the primary energy source. Global energy consumption, as reported by the International Energy Agency (IEA), has been steadily increasing due to population growth and improved living standards, with a 2.9% increase in 2019, surpassing the 1.9% average annual growth rate of the previous decade [1]. Despite the growing interest in renewable energy resources, they currently represent a small portion of the global energy mix. In 2020, fossil fuels still dominated electricity production in the United States, accounting for approximately 80%, while renewables contributed around 20% [2, 3]. Additionally, renewable energy sources face challenges such as environmental dependence, high initial costs, and environmental consequences related to their production. In light of these circumstances, hydrocarbon production remains crucial to meet the rising energy demand, achieved through the exploration of new reservoirs or enhancing the productivity of existing ones. Exploring new reservoirs is resource-intensive and often located at greater depths, necessitating innovative technologies [4-5].
- North America > United States (0.35)
- Asia > Azerbaijan (0.32)
Feasibility of Foam-Enhanced Water-Gas Flooding for a Low-Permeability High-Fractured Carbonate Reservoir. Screening of Foaming Agent and Flooding Simulation
Derevyanko, V. K. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Bolotov, A. V. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Minkhanov, I. F. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Varfolomeev, M. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Usmanov, S. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Saifullin, E. R. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Egorov, A. N. (CJSC, Aloil, Bavly, Russian Federation) | Sudakov, V. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Zhanbossynova, S (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Sagirov, R. N. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation)
Abstract The carbonate reservoirs of the Alekseevskoye field (Russia, Republic of Tatarstan) are complicated by high heterogeneity and the presence of fractures, which make development difficult due to early water or gas breakthrough depending on the injected agent, as well as low of the productive horizon. To increase sweep efficiency and introduce fractured reservoirs into development, it is necessary to use gas enhanced oil recovery (EOR) technologies. To find the optimal technology in terms of technological complexity and efficiency, three technologies were compared: Water Injection (WI), Water-Alternating Gas (WAG), and Foam Assisted Water-Alternating Gas (FAWAG). Series of core-flooding tests were implemented under reservoir conditions on carbonate cores, and cores with artificial fractures, saturated with original reservoir fluids. For FAWAG method compatible with high-mineralization water surfactant was chosen. Total recovery factor for each test was calculated. It was equal to 33%, 76% and 53% respectively for WI, WAG and SWAG, on the original core models. Therefore, WAG and SWAG were chosen as most effective techniques to improve oil recovery for in comparison with CWI. In artificially fractured cores, the WAG method recovery rate was 40%; subsequent injection of a foaming active substance mixed with FAWAG formation water proved effective, increasing the oil recovery rate to 47% due to partial blockage of the fracture.
- Geology > Rock Type > Sedimentary Rock (0.46)
- Geology > Petroleum Play Type > Unconventional Play > Fractured Carbonate Reservoir Play (0.40)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.37)
- Europe > Russia > Volga Federal District > Bashkortostan > Alekseevskoye Field (0.99)
- Europe > Russia > Volga Federal District > Tatarstan > Volga Urals Basin > Romashkinskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Fyodorovskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Samotlorskoye Field (0.94)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (4 more...)
Abstract To unlock Mishrif reservoir potential in West Kuwait, a new development strategy involving analysis with Distributed Temperature Sensing (DTS) and downhole intervention with instrumented coiled tubing (Active CT) followed by high-rate stimulation by bull-heading has been applied to the tight carbonate formation. The goal was to find a cost-effective stimulation strategy that would increase the number of productive wells through an integrated production enhancement project approach. The operation encountered various challenges, primarily driven by a high-permeability areas across the open hole, which was detected by DTS. Modifications were made to the CT stimulation procedure, including diversion techniques such as high-pressure jetting, dual injection and the pumping of a near-wellbore fully degradable diverter composed of a customized blend of multimodal particles and degradable fibers to temporarily isolate the highly permeable streaks. Real-time downhole telemetry had a paramount importance in ensuring the injection rate was kept below preset pressure limits and in monitoring downhole dynamics for optimal use of the high-pressure jetting tool. In most of the interventions, following the CT stimulation, a second post-stimulation DTS log was conducted to evaluate the fluid coverage and effectiveness of the diversion strategy allowing for further adjustment of the bullhead stimulation program for an optimum fluid coverage and avoiding the high-intake zones.
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Najmah Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Marrat "C" Formation (0.99)
- (13 more...)
Experimental Study on Nano Polymer Microspheres Assisted Low Salinity Water Flooding in Low Permeability Reservoirs
Yuan, W. (China University of Petroleum-Beijing) | Hou, J. (China University of Petroleum-Beijing) | Yang, Y. (China University of Petroleum-Beijing) | Zhao, Y. (China University of Petroleum-Beijing) | Nie, H. (PetroChina Southwest Oil & Gasfield Company)
Abstract Water flooding in low permeability reservoirs generally results in severe channeling and a large amount of remaining oil. Polymer microspheres and low-salinity water are proven practical approaches for profile control and oil displacement, respectively, and their combination is expected to achieve both effects. This paper evaluates the co-injection of nano-polymer microspheres and low salinity water and its impacts on oil displacement in low permeability reservoirs. Firstly, the influence of injection velocity and injection concentration on the plugging effect of nano-polymer microspheres was evaluated by core displacement experiments. Secondly, the nano-polymer microsphere solutions were prepared using 10-time and 100-time diluted formation water to evaluate the impacts of the co-injection of nano-polymer microspheres and low-salinity water. Meanwhile, the Nuclear Magnetic Resonance T2 spectrum and imaging test were used to reveal the extent of residual oil in pores of various sizes during core flooding as well as the mechanism of oil displacement. The experimental results showed that, compared with nano-polymer microsphere flooding, the composite system of low salinity water and nano-polymer microsphere increased the recovery rate from 17.8% to 24.4%. The subsequent waterflooding stabilization injection pressure increased from 1.40 MPa to 2.43 MPa, and the corresponding plugging efficiency increased from 49.3% to 67.9%. The NMR study indicated that, in the polymer microsphere drive stage, the produced oil mainly came from the large pore spaces, accounting for 75% on average. With a lower solution salinity, the percentage of crude oil produced from the medium pore space to the total oil produced in the microsphere drive stage increased from 15% to 23%. The lower the salinity, the higher the oil produced from small- and medium-sized pores. Our results showed that polymer microspheres eliminated water channeling and changed flow direction, forcing the low-salinity water to enter smaller pores and improving the sweep and oil displacement efficiency. This study confirms the potential of synergistic flooding with low salinity water and nano-polymer microspheres in enhancing oil recovery in low permeability reservoirs. This study is the first to visually assess the impacts of nano-polymer- assisted low-salinity water flooding using NMR online tests. We confirmed that this combined technology successfully achieved both profile control and oil displacement. The nano-polymer-assisted low-salinity water flooding holds the advantages of low cost and simple construction, implying great potential in low permeability reservoirs.
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
Integrated Workflow for Reservoir Management in Mature Waterflooded Reservoir within a Complex Geological Environment: Gullfaks Case Study
Kareb, Ahmed (University of Houston, Houston) | Dindoruk, Birol (University of Houston, Houston) | Chiboub-Fellah, Abd Elaziz (IFP School, Paris) | Gareche, Mourad (University of Boumerdes, Boumerdes)
In the context of field development planning, the project workflow has to be outlined beforehand to ensure the most optimal and accurate outcomes within time limits. The workflow started by utilizing a G&G software, Petrel, to depict the rock type and fault distribution within the geological models by incorporating interpreted seismic data and well logs. This integrated approach facilitated a comprehensive understanding of the reservoir's structural and geological characteristics. Furthermore, standard geostatistical techniques applied in software generated property models that ensured alignment of permeability and porosity distribution with the corresponding well logs. Interpretation of production data, PVT, and SCAL served as the basis for initializing the model using a reservoir simulator, Intersect, as a dynamic flow simulator. The accuracy and reliability of the model were ensured through quality checks, which include volume estimate comparison starting with equilibrium runs. Additionally, sensitivity analysis was performed by adjusting model parameters to achieve a history match and align simulated results with actual reservoir behavior in various ways. The calibrated model explored using a high-resolution simulator for high accuracy and more options for development strategies such as infill wells (horizontal and vertical), well conversions, water shut-off (zonal isolation and selective perforation), stimulation operations, and ESP systems in order to optimize reservoir performance and maximize production while improving sweep efficiency. Lastly, economic evaluation based on net present value (NPV) analysis considered techno-economic factors to identify the most suitable development strategy that balanced technical feasibility with economic viability.
- North America > United States (0.94)
- Europe > Norway > North Sea > Northern North Sea (0.70)
- Geology > Rock Type (0.88)
- Geology > Geological Subdiscipline (0.68)
- Geology > Structural Geology > Fault (0.47)
- Geophysics > Borehole Geophysics (0.88)
- Geophysics > Seismic Surveying (0.54)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation > Middle Bakken Shale Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > Statfjord Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 050 > Block 34/10 > Gullfaks Field > Statfjord Group (0.99)
- (7 more...)
- Information Technology > Software (0.50)
- Information Technology > Modeling & Simulation (0.47)
- Information Technology > Software Engineering (0.41)