Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
complex reservoir
- North America > United States > Texas > Permian Basin > Midland Basin (0.99)
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
- (11 more...)
We are in a period of energy evolution where technological advancements and private investments cause innovation to bloom and become the centerpiece of human progression. During this SPE Live, the URTeC 2023 technical program co-chairs share their thoughts on how unconventional reservoir technology evolved over the years.
Department of 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
- North America > United States > Texas (0.51)
- North America > United States > Oklahoma (0.43)
- Geology > Geological Subdiscipline > Geomechanics (0.77)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.49)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.48)
Diamondback Energy has announced its acquisition of Permian Basin rival Endeavor Energy Resources in a cash-and-stock deal valued at approximately 26 billion. The consolidation will create a firm worth almost 60 billion. It also underscores the recent shake up of the US shale sector, following a year in which mergers and acquisitions topped 192 billion, with an additional 40 billion occurring in this quarter alone, according to figures from Enverus Intelligence Research (EIR). The trend underscores the drive of large operators to add significant volumes of flowing barrels along with untapped drilling locations to secure long-term viability. Prior to today, Diamondback itself has made more than 4 billion in other cash-and-stock deals to enhance its drilling inventory and cash flow from mineral rights since 2022.
- 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...)
- Management > Asset and Portfolio Management (0.95)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (0.72)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (0.72)
- Management > Energy Economics > Unconventional resource economics (0.72)
Optimization of Enhanced Geothermal System Operations Using Distributed Fiber Optic Sensing and Offset Pressure Monitoring
Titov, A. (Fervo Energy Company, Houston, TX, USA) | Dadi, S. (Fervo Energy Company, Houston, TX, USA) | Galban, G. (Fervo Energy Company, Houston, TX, USA) | Norbeck, J. (Fervo Energy Company, Houston, TX, USA) | Almasoodi, M. (Devon Energy Corporation, Oklahoma City, OK, USA) | Pelton, K. (Devon Energy Corporation, Oklahoma City, OK, USA) | Bowie, C. (Devon Energy Corporation, Oklahoma City, OK, USA) | Haffener, J. (Devon Energy Corporation, Oklahoma City, OK, USA) | Haustveit, K. (Devon Energy Corporation, Oklahoma City, OK, USA)
Abstract Enhanced Geothermal Systems (EGS) have emerged as a promising method to generate electricity from geothermal resources in areas that lack natural fractures and/or faults needed to connect injector/production well sets, virtually eliminating dry hole risk. EGS leverages much of the learnings from the past two decades of unconventional developments, connecting horizontal wells with multi-stage stimulations to create connectivity to flow water between wells to mine heat from the subsurface. This paper presents a case study in measuring EGS fracture geometry, utilizing measurements from vertical and horizontal permanent fiber optic cables and offset pressure monitoring. The Devon Quantification of Interference (DQI) analysis is also applied to multi-stage stimulated geothermal wells, integrated with fracture and reservoir simulation. Fervo Energy, a first mover in EGS, is leading the way in developing this technology. Devon, an industry leader in unconventional oil and gas development, leverages their learnings in this field to optimize EGS operations. Optimal well spacing and completions design, much like in oil and gas, are critical to optimizing for a successful EGS development. Analysis of strain rate in offset well and multi-well microseismic recorded with fiber optic cables during stimulation and well testing allowed to characterize stimulated reservoir volume created by hydraulic stimulation and optimize well placement. The DQI analysis examined the well-to-well connectivity of the multi-stage stimulation between the two wells in the case study, providing insight into the conductive fracture geometry. The paper also discusses the execution of well preparation, stimulation, and high-level well performance. This study provides valuable insights into the development of EGS using vertical and horizontal permanent fiber optic cables and offset pressure monitoring. The findings suggest that this approach can be effective in optimizing EGS operations. Fervo Energy’s expertise in EGS development, combined with Devon’s expertise in unconventional oil and gas development, can be leveraged to further advance EGS technology at scale and generate electricity from geothermal resources. This paper serves as a valuable resource for operators looking to optimize EGS operations.
- Overview (0.48)
- Research Report > New Finding (0.34)
- Energy > Renewable > Geothermal > Geothermal Resource (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Renewable > Geothermal > Geothermal Resource for Power Generation > Enhanced Geothermal System (0.61)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
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...)
Abstract Hydraulic fractures tend to propagate in a plane that is perpendicular to the least principal stress. As a result, unconventional oil and gas wells are typically drilled in the direction of minimum horizontal stress (Shmin) to maximize drainage area. However, in some regions, due to acreage constraints, wells are drilled to maximize the number of wells instead of the ideal orientation with respect to subsurface stresses. We studied the impact of changing well orientation on well productivity in the Bakken Play by simulating a wide range of operational scenarios including proppant loading, well spacing, cluster spacing, and depletion. Our simulation results were compared to historical Bakken well performance data filtered based on the same well orientations and completion designs. The simulation results show that drilling wells parallel to Shmin maximizes well productivity, consistent with the reported actual data. However, the degree of production uplift in actual data cannot be fully attributed to well orientation. We demonstrate that job size, depletion, cluster spacing, and well spacing all affect the impact of well orientation on performance. It is challenging to rigorously quantify the effect of well orientation versus completion design on well productivity in historical data. Simulation studies help to determine the impact of each parameter, helping operators optimize their development strategy. Simulation sensitivity analyses show that depletion, wider cluster spacing, and wider well spacing can lessen the effect of well orientation on well productivity.
- North America > United States > North Dakota (0.49)
- North America > United States > South Dakota (0.35)
- North America > United States > Montana (0.35)
- (2 more...)
- Research Report > Experimental Study (0.49)
- Research Report > New Finding (0.49)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.98)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation (0.98)
- North America > United States > Montana > Williston Basin > Bakken Shale Formation (0.98)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Well performance, inflow performance (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
A Comprehensive Review of Casing Deformation During Multi-Stage Hydraulic Fracturing in Unconventional Plays: Characterization, Diagnosis, Controlling Factors, Mitigation and Recovery Strategies
Uribe-Patino, J. A. (University of Alberta) | Casero, A. (bp) | Dall'Acqua, D. (Noetic Engineering) | Davis, E. (ConocoPhillips) | King, G. E. (GEK Engineering) | Singh, H. (CNPC USA) | Rylance, M. (IXL Oilfield Consulting) | Chalaturnyk, R. (University of Alberta) | Zambrano-Narvaez, G. (University of Alberta)
Abstract The objective of this paper is to provide a review of casing deformations that are related to the placement of Multi-Stage Hydraulic Fracturing (MSHF) in unconventional plays. This work aims to identify practical mitigation and management strategies to reduce the overall impact of such events on the economic outcome of any development. The methodology incorporates a comprehensive literature review and leverages insights from the authors’ extensive field experience. This approach aims to explore the current state of knowledge regarding casing deformations associated with MSHF in unconventional reservoirs across key global basins. This paper encompasses the identification, diagnostics, surveillance, and monitoring of such deformations as they manifest and progress, along with the implementation of mitigation and management strategies prior to and during the well-completion process. The authors recognize the disparity between the number of publications available and the actual incidence of casing deformation in specific basins and are conscious that obtaining an exact estimate may often be elusive. The technical aspects of the review rely on the examination of numerous case studies from various unconventional basins. This is achieved by establishing a comprehensive understanding of the potential causes and mechanisms of casing deformations, including their occurrence, detection, and identification. Subsequently, an analysis is performed that presents the inherent characteristics of the different types of casing deformation, encompassing their nature, severity, distribution, and frequency across the basins considered, their lateral locations, event occurrence, specific nature and other pertinent factors. Additionally, the review addresses the geological, geo-mechanical, engineering and operational control factors that are likely to contribute to such deformations. Furthermore, it identifies a range of potential mitigation strategies aimed at minimizing the occurrence and ultimately the economic effects of casing deformation occurrence. This review builds upon various ongoing industry technical initiatives undertaken by the SPE Well Integrity Technical Section - Casing Deformation Work Group. The study findings can potentially provide practical measures to manage and mitigate casing deformation in unconventional basins within horizontal wells, thus minimizing the associated economic impact. Remaining knowledge gaps that require consideration should be addressed by actively sharing best practices and case histories within the industry on a global scale. This collaborative review paper, involving operating companies and other experts, serves as an initial step in that direction, aiming to catalyse further discussion among professionals working in this sector. It is intended as a rallying cry to encourage broader participation, deeper and shared consideration of the considerable effects of casing deformation occurrence.
- North America > United States > Texas (1.00)
- North America > Canada > Alberta (1.00)
- Asia > Middle East (1.00)
- (5 more...)
- Geology > Structural Geology (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.50)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- Oceania > Australia > Northern Territory > McArthur Basin > Beetaloo Basin (0.99)
- North America > United States > Wyoming > Powder River Basin (0.99)
- (71 more...)
- Information Technology > Knowledge Management (0.46)
- Information Technology > Communications (0.46)
Protecting Parent-Well Production Using Far-Field Diverters in Unconventional Wells
Ajisafe, F. O. (Liberty Energy, Houston, Texas, United States) | Porter, H. (Lime Rock Resources, Houston, Texas, United States) | Kothare, S. (Lime Rock Resources, Houston, Texas, United States) | Colson, E. (Lime Rock Resources, Houston, Texas, United States) | Ellis, R. (Liberty Energy, Houston, Texas, United States) | Heaton, N. (Liberty Energy, Houston, Texas, United States) | Demars, B. (Liberty Energy, Houston, Texas, United States) | Mayerhofer, M. (Liberty Energy, Houston, Texas, United States)
Abstract The impact of fracture driven interaction (FDI) is an increasing concern in mature developed unconventional plays in the US. In this study, parent well production performance after infill well stimulation is evaluated to understand the effectiveness of far-field diverter in mitigating FDI's. Studies to determine if FDI's result in a negative or positive impact, have concluded that it varies from basin-to-basin (Miller et al 2016). In this project, the purpose of pumping far-field diverter is to mitigate wellbore sanding and production loss in existing parent wells. The far-field diverter pill includes a blend of multimodal particles to bridge the fracture tip, preventing excessive fracture length and height growth. Fracture modeling with a unique particle transport model is typically used to design the far-field diverter pill impact on fracture geometry. The pill design and contingency designs are executed in the infill well stimulation job, right after the pad step, in the beginning of the pump schedule. Optimization of the far-field diverter can be complemented with real-time pressure monitoring or cross-well fiber strain data on the parent well. Over the years, far-field diverter has, in one form or the other, been used for various applications in stimulation design. However, since mid-2010's, far-field diverter has been used to address growing concerns of FDI's observed in most mature plays in the US. In this study, since 2018, far-field diverters have been pumped in several wells for the purpose of mitigating the negative impact of FDI's between parent and child wells. While these jobs were operational successes, the next crucial step was to evaluate and quantify the effectiveness of the far-field diverter in mitigating production loss in the parent wells. It is important to note that the operator whose wells utilized far-field diverters, had experienced negative impact of FDI's in their parent wells in the form of production loss and sand in the wellbore which required clean outs at a significant cost. In this study, production data was evaluated comparing pre-stimulation production before shut-in and post-stimulation production after the parent wells were brought back online. Overall, about 75% of the parent wells protected show positive uplift in oil production. And about 80% of the child wells show superior or comparable production decline after about a year of production when compared with offset parent wells It is evident that far-field diverters for fracture geometry control in child wells can be extremely helpful in mitigating negative impact of FDI's. In unconventional reservoirs, where infill (child) well drilling is prevalent, the impact of far-field diverter in controlling fracture geometry has the potential to be a value added FDI mitigation technology to mitigate wellbore sanding and subsequent clean outs as well as optimize production performance of both child and parent wells. The early part of the project resulted in ~$2.5million in savings in well cleanup costs. In addition, fracture diagnostics along with production data evaluation can be highly beneficial in understanding the role of production depletion, completion design and well spacing on fracture driven interaction.
- North America > United States > North Dakota (1.00)
- North America > Canada > Saskatchewan (0.80)
- Geology > Geological Subdiscipline (0.46)
- Geology > Petroleum Play Type > Unconventional Play (0.34)
- North America > United States > North Dakota > Williston Basin > Lodgepole Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation > Middle Bakken Shale Formation (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.97)
- (3 more...)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper URTeC 3871303, “Using a Multidisciplinary Approach to Reservoir and Completion Optimization Within the Woodford Shale Play of the Arkoma Basin,” by Stephen C. Zagurski, SPE, and Steve Asbill, SPE, Foundation Energy Management, and Christopher M. Smith, Advanced Hydrocarbon Stratigraphy, et al. The paper has not been peer reviewed. _ Subsurface complexities related to the formation of peripheral foreland basins can have significant effects on unconventional resource development. In the Arkoma Basin of southeast Oklahoma, the onset of thrusting and tectonic loading induced a complex series of dip/slip and strike/slip faults during basin formation. The operator used a series of technologies to increase understanding of the reservoir and its hazards and provide insight into economic implications for future development plans and strategies. Introduction The Woodford is primarily a Type II kerogen source rock. The formation typically is classified as either siliceous mudstone or cherty siltstone. Variable thermal maturity across the basin places the Woodford in both the wet-gas and dry-gas phase windows (moving west to east across the basin). Complex faulting regimes within the Arkoma add a layer of complexity to horizontal development of the Woodford. The operator wanted to increase the understanding of the Woodford and the effects of faulting through the reservoir in a recent development unit in the liquids-rich fairway. The development unit consists of an existing parent well (Well X) and a pair of child wells (Well Y and Well Z). The background of Unit XYZ begins with the completion of parent Well X 4–6 years before infill development. In this portion of the basin, Well X’s initial production rate and its cumulative production to date rank it in the top 25% of wells. The wellbore is subjected to a pair of faults and was drilled in the upper half of the Woodford. Placement of Well X is substantially further east than most parent wells because it is approximately 1,600 ft from the unit boundary. This limited infill development to two wells instead of three; the Arkoma typically has seen spacing of four, and sometimes five, wells per section. Wells Y and Z were planned and drilled east of Well X with 1,100–1,600 ft of well spacing. Well spacing in the unit was slightly hindered by surface location limitations and limited true vertical depth (TVD) between surface casing and landing point. Structural complexity within the unit partially impaired infill development of the unit. Specifically, Well Y and its lateral length was shortened. In this portion of the Arkoma, fault-derived water production typically is the highest-weighted variable in a well’s operating expenditure. Thus, the ability to limit excess water production within Unit XYZ and the surrounding acreage is of paramount importance.
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.91)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.54)
- North America > United States > Oklahoma > Arkoma Basin > Cana Woodford Shale Formation (0.99)
- North America > United States > Oklahoma > Anadarko Basin > Cana Woodford Shale Formation (0.99)
- North America > United States > Arkansas > Arkoma Basin > Cana Woodford Shale Formation (0.99)