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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)
Intervention-based fiber optics have proved a valuable and cost-effective tool in understanding during-fracturing and post-flowback well and section performance. During-fracturing diagnostics, such as crosswell strain measurements from an offset monitor well, describe where fractures intersect the monitor well and reveal details such as azimuth, fracture-propagation velocity, and activation and reactivation statistics. These critical data points help inform cluster, stage, and well-spacing decision-making.
- North America > United States > Texas (0.47)
- North America > United States > New Mexico (0.47)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.97)
- North America > United States > Texas > Permian Basin > Yates Formation (0.97)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.97)
- (21 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (0.54)
- 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)
Abstract Continuing from the previous publication (Navaiz et al. 2023) detailing the hydraulic fracturing energy system and energy transfer as fluid and proppant are pumped from the surface into formation. this paper focuses on the validating the importance of effective energy delivered to formation and its correlation to total productivity. Combining extensive in-house pumping data and well-production data available from the public domain, a two-dimensional approach cross-plotting total effective energy injected per unit area against production output shows a highly correlative positive relationship (R2>0.75) across several basins in North America. This strong relationship not only reinforces the value of this energy analysis concept in hydraulic fracturing established by the authors previously. It also validates the conservation of energy principle highlighting the usefulness of relating effective energy injected into formation to a direct increase in reservoir energy potential and therefore a greater potential for total productivity. With the unconventional oil and gas industry highly focused on capital efficiency, the effective energy metric enables near-instantaneous optimization of development costs rather than iterating on 6-month or 1-year production performance. Time and capital can then be invested in technologies and processes that maximize effective energy and resultant productivity or minimize energy losses in the system.
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (36 more...)
The CO2 Storage Resources Management System (SRMS) provides a classification and categorization system that reflects geologic certainty and project maturity of storable quantities. This short course explains the classes used to indicate the level of project maturity, which is indicative of data available for the assessment. The Storage Capacity indicates the highest level of project maturity, while Prospective Storage Resources is the class for undiscovered storage resources, with the lowest level of project maturity. The categories indicate geologic certainty, e.g. The course includes discussions of commercial evaluation of storage projects and estimating CO2 storable quantities, with examples.
- North America > United States > Colorado (0.30)
- North America > United States > New Mexico (0.29)
- Energy > Oil & Gas > Upstream (1.00)
- Education (1.00)
- Government > Regional Government > North America Government > United States Government (0.51)
- 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)
- (24 more...)
Abstract In unconventional reservoirs, spacing and stacking directly influence the hydrocarbon resources available to be drained by a given lateral. Hypothetically, these available resources, rock properties and stimulation effectiveness will drive the well performance (i.e., Estimated Ultimate Recovery (EUR)). Characterization of the effectively contacted volume is an important element in understanding the well performance and the depletion efficiency of the intended development. This paper will present a simple but novel way of characterizing a well's drainage volume and demonstrates how this characterization can be applied to improve the understanding of expected well recovery, primary depletion efficiency (i.e., recovery factor), and their relationship with petrophysics and geology. The methodology is proposed as a method to help lead to optimum development and resource economic value for the operator. The proposed method uses the concept of no flow boundaries driven by frac geometry established between wells to define a drainage polygon surrounding neighboring laterals. Incorporating supplementary datasets allows further characterization (i.e., well-log to obtain fluid-in-place distribution). The method provides insights which can be tied back to the well performance. For example, the method shows the importance of geology and petrophysics, reflected through the Original Oil in Place (OOIP) within the drainage volume, driving the well's EUR and recovery factor. Significance/Novelty: Improved reservoir drainage volume and well performance characterization can significantly impact the optimum development plan, maximizing both the exploitation efficiency and value for operators.
- 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)
- (24 more...)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Reserves Evaluation > Estimates of resource in place (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (2 more...)
Abstract The producing GOR trend of unconventional wells is a function of the complex interaction of fluid properties, geology, completion design, well spacing/stacking geometry, and operational changes. These complexities bring as an outcome a wide variation of GOR trends with time. This paper introduces a novel normalized forecasting process to build GOR type curves along with the uncertainty ranges. The long-term GOR range is comparable to theoretical PVT model expectations and offset wells with longer production history. The proposed methodology requires integrated multi-discipline efforts and is not a machine-learning modeling process. Groups of wells are selected based on similar geology and fluid properties while removing wells with poor data quality and operational issues. Next the normalized cumulative oil/EUR is introduced to compare the cumulative GOR curves. Empirical models are then generated to fit the GOR curves and forecast long-term GOR trends. A novel approach for terminal GOR range is applied to constrain the results from empirical models. The normalized process creates proven accurate gas predictions compared to the first three years of well performance. Two different approaches are used to validate the forecasted GOR. The first approach is to derive the terminal GOR range with the available PVT report. The second approach is to benchmark with offset wells with long history. Both approaches show the forecasted GOR is within the reasonable range. The normalized forecasting method has been tested for different areas in Delaware and Midland basins, covering a wide GOR range, and demonstrates its robustness in the forecast.
- 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)
- (24 more...)
Abstract Numerical Rate Transient Analysis (RTA) and production forecast models for unconventional reservoirs usually rely on single well analysis, with relatively simple assumptions regarding the geometry of the hydraulic fractures (identical and uniformly distributed). In this paper, we describe a transient numerical model for deviated well trajectories intercepting a complex distribution of fractures. The model can incorporate multiple wells and account for various modes of interference, including fracture hits. This approach enables the initialization and calibration of new types of transient models, which are directly compatible with the results of advanced completion diagnostics. In the proposed approach, the near-well region is discretized with a fully automated unstructured grid, rigorously constrained to the fractures. The algorithm accounts for independent fracture properties (ex: azimuth, half length, thickness, offset…). Hydraulic fractures originating from a given well can intercept one or several other wellbores or existing fractures. Complex transient interference modes between fractures, as well as fracture-driven communications between wells can then be analyzed. The geometrical grid resulting from complex fracture distributions may contain a very large number of cells. To overcome this issue, a new "aggregation" scheme is proposed, which reduces the size of the computational system and considerably accelerates the calculations. The model is validated in single and multiwell configurations, with different fracture distributions and interference modes. The impact of wells interference on the RTA interpretation and the production forecast is accounted for. This model is also tested for multiphase simulation - including phase changes. The proposed aggregation scheme results in a reduction of the computational system size by up to 2 orders of magnitude, leading to much faster direct simulations. Comparisons of the log-log derivatives show that the different flow regimes are accurately captured with the new scheme, even at very early-time. Because the aggregation scheme proceeds on zones with similar pressure behavior, there is no need for pseudo-relative permeability derivations, and the results remain accurate for multiphase flow and pressure-dependent petrophysical properties. This model provides a new solution for transient, nonlinear numerical simulation of fractured horizontal wells with complex geometries. The model can be applied to numerical Rate or Pressure Transient Analysis in unconventional reservoirs, without being limited to a geometrical element of symmetry.
- North America (0.29)
- South America (0.28)
- 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)
- (21 more...)
Abstract This paper presents an integrated workflow for generating type curves using dynamic models with limited historical production data and significant subsurface uncertainty, as well as the corresponding horizontal and vertical interference factors for forecasting well performance with different well spacings and a given stimulation design. We present a dynamic reservoir simulation workflow for four co-development horizontal wells in three landing zones within the black-oil window of the Vaca Muerta formation. History matching included 39 reservoir, fluid, completion, and hydraulic fracture parameters. Twelve thousand simulation model runs yielded 222 unique cases that best match historical bottom-hole pressure and production rate data. A ranking method was used to identify the most representative P90, P50, and P10 individual subsurface models based on pad-level 30 year-life cumulative oil and gas production forecasts. The core objectives of this extensive dynamic modeling exercise were 1) to provide a base P50 forecast to regress Arps parameters upon to support long-term decline curve analyses; 2) to provide a range of expected P10/P90 outcomes to quantify subsurface performance uncertainty; 3) to support vertical and horizontal interference factors that quantify a relationship between well spacing and well performance. Local grid refinements and element of symmetry methods were employed for modeling simplicity. Selection of P90, P50, and P10 production cases was non-trivial due to the presence of multiple wells. The P50 history-match case was chosen based on its alignment with the reservoir model input parameters, i.e., the P50 case matched the P50 of the input parameter distributions. Multiple methods of comparison were used on both a pad and an individual well level to justify the P90, P50, and P10 simulation history-match cases. Further, to assess oil recovery efficiency, a well drainage area was assumed, accounting for overlap of hydraulic fracture boundaries and drainage areas. Based on a combination of rate transient analysis of multiple wells and the four-well dynamic model, a regression was performed on each of the four wells to establish a set of Arps parameters for decline curve analysis. An updated look-back including another two and a half years of production was performed and reaffirmed the Arps parameters. Future work will consider a six well pad spanning two landing zones with two fully confined wells, following the same methodology.
- North America > United States > Texas (0.93)
- South America > Argentina > Neuquén Province > Neuquén (0.34)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (23 more...)
- Reservoir Description and Dynamics > Reservoir Simulation > History matching (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)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Evaluation of Flow Units and Capillary Pressures of the Giant Chicontepec Tight Oil Paleochannel in Mexico and a Fresh Look at Drilling and Completions
Gutierrez Oseguera, Alejandra (Schulich School of Engineering, University of Calgary / Now with Kyera Corporation) | Aguilera, Roberto (Schulich School of Engineering, University of Calgary (Corresponding author))
Summary The Chicontepec Paleochannel in Mexico is a giant shaly sandstone reservoir with volumes of original oil in place (OOIP) ranging between 137 and 59 billion STB (Guzmán 2022). However, the oil recoveries are very small, ranging between 0.32% and 0.75% of the OOIP. Under these conditions, consistent interpretation of flow units and mercury injection capillary pressures up to 55,000 psi provide useful information that helps in deciphering the rock quality and pore sizes at levels that might not be reached by thin-section petrography. This is important because the Chicontepec Paleochannel (Misantla-Tampico Basin) has been recently equated to the Permian Basin in the United States and has been termed by Guzman (2022) “a premier super basin in waiting.” The current cumulative oil production of Chicontepec is 440 million STB. Although it is a significant volume, it represents a very small percentage of recovery from the reservoir (0.32–0.75% of the OOIP). To help improve recovery, a method is developed for characterizing the tight Chicontepec Paleochannel using flow units and capillary pressures. Like in the case of many tight unconventional reservoirs, the capillary pressures can go to very high values, reaching 55,000 psi in the Chicontepec case. Therefore, a special procedure is developed to generate a consistent interpretation of all the available capillary pressure curves for the entire range of pressures. The results highlight the important oil recovery potential. The assessment is supported by quantitative formation evaluation work performed by Gutierrez Oseguera and Aguilera (2023). Although natural fractures are present, most wells must be hydraulically fractured to achieve commercial success. Process or delivery speed (the ratio of permeability and porosity) for the Chicontepec samples used in the capillary pressure experimental work range between 159.1 md and 0.17 md (porosity in the denominator is a fraction). Flow units show pore throat radii (rp35) range from less than 0.1 µm to about 4.5 µm. These values and flow units compare well with data available for prolific unconventional reservoirs such as the Cardium sandstone in Canada and the giant Permian Basin in the United States. The radius rp35 refers to the pore throat radius at 35% cumulative pore volume (PV) of injected mercury. This is different from rp also discussed in this paper, which is the pore throat radius at any water saturation (for example, at 40% water saturation). Thus, in the case where water saturation is 65%, rp is equal to rp35. The novelty of this study is the development of a consistent procedure for interpreting the entire range of pressures measured during mercury injection capillary pressures. Such pressures go up to 55,000 psi for the core samples considered in this study. The integration with flow units and formation evaluation suggests that the potential of the Chicontepec unconventional reservoirs can rival successful results obtained in the Cardium sandstone and the Permian Basin. The key ideas discussed in this paper for improving Chicontepec oil recovery include specialized petrophysical evaluation, determination of flow units and capillary pressures, improved drilling and completion methods, and geological support.
- North America > United States > Texas (1.00)
- North America > Canada > Alberta (1.00)
- Phanerozoic > Paleozoic > Permian (1.00)
- Phanerozoic > Cenozoic > Paleogene > Paleocene (0.46)
- Geology > Sedimentary Geology > Depositional Environment > Continental Environment > Fluvial Environment (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.96)
- 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)
- (58 more...)
- Reservoir Description and Dynamics > Reserves Evaluation > Estimates of resource in place (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)