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Collaborating Authors
Results
Fracture Propagation-Rate and Fracture Half-Length Estimated for an Individual Fracturing Stage Using Dynamic Balancing of Fluid Pressures: Eagle Ford Case Study
Oshaish, Ali (King Fahd University of Petroleum & Minerals (KFUPM) – Dhahran) | Weijermars, Ruud (King Fahd University of Petroleum & Minerals (KFUPM) – Dhahran)
Abstract This study presents a new analytical model for determining the growth-rate of hydraulic fractures during the pumping of a fracturing stage. Unlike existing commercial and numerical tools for final fracture half-length estimation, the present model is able to accommodate time-dependent parameters used in actual field operations and shows how this controls the stepwise evolution of fracture half-length over the duration of the stage treatment. The model analyzes the pressure gains and losses across the well system during the fracturing treatment operation, which solves for the Sneddon pressure used subsequently to estimate the extent and rate of the hydraulic fracture growth from the perforation clusters outward until the ultimate half-length is established. Using a practical spreadsheet template, the pressure balance model accounts for all the pressure gains and losses occurring during a typical hydraulic fracturing job. The model revealed practical results and reasonable values for the fracture half-length, in close agreement with independent estimations of fracture half-length for the same Eagle Ford well. The average propagation rate of a planar fracture, with an elliptical cross-section (in map view) of 1.8 mm width for the minor axis and fixed height of 100 ft, is 1.54 ft/min (0.026 ft/s), with high and low rates ranging between 2.81 and 0.220 ft/min. The final hydraulic fracture half-length at the end of the fracturing job was 212 ft. However, the effectively propped fracture half-length determined in independent studies using production analysis is somewhat smaller (144 ft), which indicates that the tip-end of the final fracture (212-144 ft= 68 ft) was not effectively propped, and effectively closed after the treatment.
- North America > United States > Texas (1.00)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.46)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- (4 more...)
Lesson Learned from the Hydraulic Fracturing of China's Shale Oil Field
Li, Shuai (Research Institute of Petroleum Exploration and Development, PetroChina) | Cai, Bo (Research Institute of Petroleum Exploration and Development, PetroChina) | Xin, Jin (Fengcheng Oilfield Operation Area of Xinjiang Oilfield Company, PetroChina) | Yi, Xinbin (Oil and Gas and New Energy Company, PetroChina) | Li, Jianmin (Engineering Technology Research Institute of Xinjiang Oilfield Company, PetroChina) | Wang, Mingxing (Engineering Technology Research Institute of Xinjiang Oilfield Company, PetroChina) | Li, Jiacheng (Engineering Technology Research Institute of Xinjiang Oilfield Company, PetroChina) | He, Chunming (Research Institute of Petroleum Exploration and Development, PetroChina) | Zhang, Haoyu (Research Institute of Petroleum Exploration and Development, PetroChina) | Yan, Xingming (Research Institute of Petroleum Exploration and Development, PetroChina) | Gao, Yuebin (Research Institute of Petroleum Exploration and Development, PetroChina)
Abstract With the gradual deterioration of oil and gas resources quality, more companies are targeting the unconventional reservoirs. In China, unconventional reserves have accounted for more than 80% in total newly found proven reserves, taking tight oil for an example, China has tight oil geological resources of more than 12 billion tons. In this paper, we firstly introduced the main geology and reservoir characteristics of the target block, the strong formation heterogeneity, low permeability, low abundance, etc. This kind of reservoir has no economical production without hydraulic fracturing, while the stimulation operation still faced with difficulties such as un-predicate fracture propagation, high cost and low efficiency. Aiming to solve these difficulties, we summarized the status, experience and field application of the main hydraulic fracturing technologies in this area. (1) Horizontal well multi-stage fracturing (HWMF) technologies, featured with small well spacing, dense cutting, large fracture stages and small clusters, were widely used and applied as the main hydraulic fracturing method. (2) Widely used soluble sleeve bridge-plugs and soluble ball seats in the P’N’P completion wells, saving working time and reducing the construction cost. (3) Multi-functional fracturing fluids, featured with imbibition mechanism and increase oil recovery. (4) Replacement of ceramsite by low-cost quartz sand. (5) Factory-fracturing construction model, with maximum 12 well in one well platform. The integrated technologies have been applied in more than 200 wells, the daily oil production per well has increased from 3-5t/day to 15-25t/day. Application of the integrated technologies and the experience can be references for the efficient development of similar tight oil reservoirs.
- North America > United States > Texas (1.00)
- Asia > China (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.90)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.70)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- (5 more...)
Tackling Breakdown and Proppant Placement Issues in a Deep, High-Pressure/High-Temperature Volcanic Reservoir: Lessons Learned Through Multistage Fracturing Campaigns in Minami-Nagaoka Gas Field, Japan
Kidogawa, Ryosuke (INPEX Corporation, Tokyo, Japan) | Yoshida, Nozomu (INPEX Corporation, Tokyo, Japan) | Kaneko, Masayuki (INPEX Corporation, Tokyo, Japan) | Takatsu, Kyoichi (INPEX Corporation, Tokyo, Japan) | Kubota, Ayumi (INPEX Corporation, Tokyo, Japan) | Boucher, Andrew (Fenix Consulting Delft BV, Delft, The Netherlands) | Shaoul, Josef (Fenix Consulting Delft BV, Delft, The Netherlands) | Tkachuk, Inna (Fenix Consulting Delft BV, Delft, The Netherlands) | Spitzer, Winston J. (Fenix Consulting Delft BV, Delft, The Netherlands) | De Pater, Hans (Fenix Consulting Delft BV, Delft, The Netherlands)
Abstract Fracturing treatments are often challenging in high-pressure/high-temperature, tectonically stressed areas with heterogeneous and complex lithology. This study presents case histories of two multistage fracturing campaigns executed on a tight gas formation in a deep volcanic reservoir onshore Japan. This work begins by highlighting the technical difficulties experienced during the first campaign, reviews the countermeasures developed over the course of the decade between campaigns, and finishes lessons learned from execution and evaluation of the second campaign. A root-cause analysis was undertaken to understand the poor treatment results from the first campaign where stages were defined by no formation breakdown, poor injectivity or early screen-out. It included re-evaluation of core/petrophysical interpretation, stress model and net pressure history matching, and development of injectivity index diagnostic plots. The findings were used to identify updated technologies and workflows for the second campaign with consideration of limitations in the target well drilled +10 years before and uncompleted. Finally, details of field execution and post-job logging results are presented to verify effectiveness of proposed techniques and extract lessons learned for future operations. The breakdown and injectivity issues of the first campaign appear to be tied to the initiation interval location and facies, where initiating in a massive lava facies was most problematic due to high stress and extreme tortuosity. Uncertainty in the propped height from the net pressure history matches showed room for optimization in treatment design. In the second campaign, with mitigation plans for breakdown issues, premature screen-outs and detection of propped height in place, nine fracture stages were attempted. Eight stages achieved successful breakdown with careful target selection and weighted brine. Two conventional treatments with crosslinked gel were placed in the intervals with high injectivity and, as a field trial, two slickwater treatments with high viscosity friction reducer were placed in intervals to deal with low injectivity. Issues with high apparent net pressure due to tortuosity continued, comparable to the first well, and efforts to further reduce treating pressure for future campaigns continues. Logging of the non-radioactive traceable proppant pumped revealed thin propped heights while production logging showed contribution from the zones treated with slickwater indicating it may be a viable solution for this type of challenging reservoir. This work highlights a series of technical issues and possible solutions of multistage fracturing in a volcanic reservoir, validated through field execution. Proposed solutions partially solved the challenges, but at the same time they open further questions for future campaigns. This study can serve as a reference for fracturing operations in challenging analogue reservoirs.
- North America > United States > Texas (1.00)
- Asia > Japan > Chūbu > Niigata Prefecture (0.40)
- Overview (0.46)
- Research Report > New Finding (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Volcanology (0.91)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.46)
- North America > United States > Texas > East Texas Salt Basin > Cotton Valley Group Formation (0.99)
- North America > United States > Louisiana > East Texas Salt Basin > Cotton Valley Group Formation (0.99)
- North America > United States > Arkansas > East Texas Salt Basin > Cotton Valley Group Formation (0.99)
- (9 more...)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics (1.00)
The trend in fracturing designs has been longer stages with more perforation clusters, which save time and money. Based on papers at this year's SPE Hydraulic Fracturing Technology Conference and Exhibition, the thinking that has sharply reduced the number of perforations per cluster and improved the effectiveness of fracturing is becoming the industry norm. But there are a couple of companies questioning the consensus by fracturing wells with shorter stages and fewer clusters to see if they deliver more oil and gas production. ConocoPhillips has been considering "going backward to fewer clusters per stage," said Dave Cramer, a senior engineering fellow at the company. "In some areas, we are testing out fewer clusters per stage based on fiber-based observations in offset wells that (indicate) far‑field treatment uniformity is improved as a result," he said, adding "another advantage of reducing stage length is that injection rate into the hydraulic fractures is increased, which leads to increased fracture width and improved proppant transport."
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (0.91)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (0.69)
ABSTRACT Horizontal drilling and multi-stage/multi-cluster hydraulic fracturing are critical technologies that enable the economic production of hydrocarbons from unconventional reservoirs. However, achieving uniform growth from multiple perforated clusters remains a challenge. In hydraulic fracturing operations, some fractures can be overgrown while others are fully suppressed. Near-wellbore diversion is commonly used to promote uniform growth of each cluster in a stage. In this study, a continuum approach of particle transport was implemented and coupled with a fluid flow solver in FLAC to simulate the nonlinear particle propagation and bridging in the near-wellbore diversion process. The effect of swelling behavior of diverters on the bridging location and time inside a fracture, as well as pressure buildup at the fracture entrance, was evaluated. Simulation results showed that the use of swelling particles resulted in the formation of a closed bridging loop with fewer particles and a shorter injection time, and higher fluid pressure at the fracture entrance. INTRODUCTION Horizontal drilling and multi-stage/multi-cluster fracturing have become standard practices for the completion of unconventional reservoirs (Economides and Nolte, 2000). However, due to the heterogeneity of the formations, local stress concentration from geological structures, and stress interference from nearby fractures, uneven growth of multiple fractures is commonly observed in the field (Cipolla et al., 2011; Miller et al., 2011). To promote uniform growth, hydraulic fracturing operations often use diverting particles that temporarily block off the over-grown fractures, allowing more injected fluid to be diverted to under-stimulated fractures (Barraza et al., 2017; Daneshy, 2019; Shahri et al., 2016). Numerical modeling is a valuable tool for understanding, predicting, and designing hydraulic diversion operations. The numerical schemes to model particle transport can be classified into two groups: discrete and continuum approaches. While the discrete approach (Mao et al., 2021; Mondal et al., 2016; Suri et al., 2020; Zeng et al., 2019) has demonstrated accuracy in capturing fluid-particle interactions at the pore-scale and applications in investigating problems related to fluid flow through proppant packs and sand erosion inside fractures and perforations (Fan et al., 2019, 2018; Han and Cundall, 2013, 2011), it suffers from a major drawback of high computational cost.
- 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...)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Well Drilling > Drilling Operations > Directional drilling (0.69)
- (2 more...)
Abstract Currently, the most effective way to extract resources from shale reservoirs is through the use of multi-stage fracturing of horizontal wells. However, the process of flowback after fracturing can affect the extent of damage done by the fracturing fluid to the formation and fracture conductivity, which ultimately impacts the success of the fracturing process. Unfortunately, the control of flowback in fracturing fluid relies on empirical methods, and lacks a reliable theoretical foundation. As a result, it is important to optimize the flowback process by controlling the velocity and flowback of the fracturing fluid. Additionally, previous research on the productivity of multi-stage fracturing horizontal wells after fracturing is limited, and the equation derivation process has been oversimplified, leading to reduced accuracy. This paper introduced a new model to adjust a choke size to optimize flowback velocity and predicts production performance following fracturing. To enhance fracture clean-up efficiency, choke sizes are dynamically adjusted based on wellhead pressure changes over time. A two-phase flow model is used, and factors like proppant particle forces, filtration loss, fluid compressibility, wellbore friction, and gas slippage are taken into account. Using mass conservation theory, the model predicts production performance for multi-fractured horizontal wells, considering dual-porosity, stress-sensitivity, gas adsorption and desorption, and gas and water relative permeabilities. The above model was used to evaluate a multi-fractured horizontal well (MFHW) based on shale reservoir parameters in order to study the factors affecting flowback and production after fracturing. The study examined the relationship between proppant particle diameter, choke size, and wellhead pressure, as well as the impact of different choke sizes on gas production after flowback. The findings showed that as proppant particle diameter increased, choke size also increased. However, if the choke size is too large or too small during the flowback process, it will reduce fracture conductivity. The optimal choke size was found to be between 4-6 mm and dynamic adjustment of choke size based on changes in wellhead pressure resulted in the best fracture conductivity and highest productivity for a horizontal well.
- North America > United States > Texas (1.00)
- Asia (0.68)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- Asia > China > Sichuan > Sichuan Basin (0.99)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- (4 more...)
Abstract Nowadays, the only economic and effective way to exploit shale reservoirs is multi-stage fracturing of horizontal wells. The backflow after fracturing affects the damage degree of a fracturing fluid to a formation and fracture conductivity, and directly influences a fracturing outcome. At present, the backflow control of the fracturing fluid mostly adopts empirical methods, lacking a reliable theoretical basis. Therefore, it is of positively practical significance to reasonably optimize a flowback process and control the flowback velocity and flowback process of a fracturing fluid. On the other hand, the previous research on the productivity of multi-stage fracturing horizontal wells after fracturing is limited, and an equation derivation process has been simplified and approximated to a certain extent, so its accuracy is significantly affected. Based on previous studies, this paper established a new mathematical model. This model optimizes the flowback velocity after fracturing by dynamically adjusting a choke size and analyzes and predicts the production performance after fracturing. To maximize fracture clean-up efficiency, this work builds the model for a dynamic adjustment of choke sizes as wellhead pressure changes over time. It uses a two-phase (gas and liquid) flow model along the horizontal, slanted and vertical sections. The forces acting on proppant particles, filtration loss of water, the compressibility of a fracturing fluid, wellbore friction, a gas slippage effect, water absorption and adsorption are simultaneously considered. With the theories of mass conservation, we build a mathematical model for predicting production performance from multi-fractured horizontal wells with a dynamic two-phase model considering dual-porosity, stress-sensitivity, wellbore friction, gas adsorption and desorption. In this model, the gas production mechanisms from stimulated reservoir volume and gas and water relative permeabilities are employed. Based on shale reservoir parameters, wellhead pressure, a choke size, a gas/liquid rate, cumulative gas/liquid production, cumulative filtration loss and a flowback rate are simulated. In the simulations, the influential factors, such as shut-in soak time of the fracturing fluid, forced flowback velocity, fracturing stages and fracture half-length after fracturing, are studied. It is found by comparison that in the block studied, when a well is shut in four days after fracturing, the dynamic choke size is adjusted with wellhead pressure changing over time, the fracturing stage is 11, and the fracture half-length is 350 meters, the fracture conductivity after flowback is the largest, and the productivity of the horizontal well is the highest.
- North America > United States > Texas (1.00)
- Asia (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- Asia > China > Sichuan > Sichuan Basin (0.99)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- (2 more...)
Stimulation of a High-Temperature Granitic Reservoir at the Utah FORGE Site
McLennan, John (University of Utah) | England, Kevin (E-K Petro Consulting LLC) | Rose, Peter (Energy & Geoscience Institute, University of Utah) | Moore, Joseph (Energy & Geoscience Institute, University of Utah) | Barker, Ben (Energy & Geoscience Institute, University of Utah)
Abstract Utah FORGE (Frontier Observatory for Research in Geothermal Energy) is a field laboratory for developing, testing, and prototyping technologies that could be adopted for commercializing Enhanced Geothermal Systems (EGS). The principle of developing an EGS is to use multiple hydraulic fracturing stages to interconnect an injection well and a production well – forming the surface area within a large heat exchange system. At the Utah FORGE site, near Milford, Utah, an injection well (65° to the vertical) has been drilled and a three-stage fracturing treatment was carried out at the toe of this well. A production well will be drilled into the stimulated domain determined from microseismic measurements. The objectives of the treatments were to establish if the created fracture networks will form independent flow networks between the injector and the producer, and ultimately to test long-term connectivity between the two wells. In addition, the mechanics of isolating stages and developing fracturing fluid viscosity in a naturally fractured granitic reservoir at 435°F [224°C] were evaluated. Three stages were pumped. Geophones in three offset wells and shallow distributed acoustic sensors (DAS) and surface monitoring devices tracked the fracture evolution. The first stage was slickwater in a barefoot section, pumped at rates up to 50 bpm [7.95 m/min]. Bridge plugs were used in 7-inch [177.8 mm] casing to isolate the next two stages, which each used a single long perforation cluster (20 ft [6.096 m] long, with six shots per ft at 60° phasing for each of the latter two stages). The second stage was slickwater pumped at rates up to 35 bpm [5.56 m/min]. The final stage was crosslinked carboxymethyl hydroxypropyl guar (CMHPG) polymer fluid pumped at rates up to 35 bpm [5.56 m/min] with low concentrations of microproppant. The well was flowed back between each stage to mitigate the potential for stage interference, facilitate running bridge plugs, and reduce the possibility of undesirable microseismicity. Isolation technology had been a significant concern before the treatment. However, bridge plugs successfully functioned at these high temperatures – isolating stages 1 and 2 and stages 2 and 3. Treatment records show a significant morphological difference between pumping in the openhole section (stage 1), and in the two cased and perforated zones (stages 2 and 3). Microseismic data suggest nominally planar growth orthogonal to the wellbore for the two cased and perforated zones – favoring intersection with the soon-to-be-drilled production well. These treatments superficially seem mundane. However, they successfully demonstrated the viability of hydraulic fracture creation in a cased well in hot, low permeability granitic rocks, a prerequisite for EGS development, revealed conditions for limited natural fracture interaction, and this was one of the few high-temperature granitic stimulation treatment programs since Fenton Hill in the 1980s.
- North America > United States > Utah (1.00)
- North America > United States > New Mexico > Los Alamos County (0.34)
- Geology > Rock Type (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Energy > Renewable > Geothermal > Geothermal Resource (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.93)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- (3 more...)
Abstract The paper aims to describe the design, testing/validation, applications, and field trial results of a 15K Multi-Stage Fracturing (MSF) Intervention-less sleeve system for use in single-point entry or multi-cluster design. Field proven results show efficiencies over plug n perf, coil annular frac and ball drop operations and significant environmental savings. Today, pad design can depend highly on how fracturing operations will be performed. Time between stages, water usage and services required can determine the optimal design of choice when choosing between a single well or multi well pad. Implementing an intervention-less sleeve system reduces the time and water usage between stages and eliminates the need for zipper operations to achieve surface efficiencies. These systems provide completion efficiencies regardless of the number of wells on a pad. By identifying the critical operational limitations of legacy MSF technologies, this paper demonstrates clear benefits between the new intervention-less system and legacy multistage fracturing tools and methods. Performance of current dissolvable solutions is dependent on wellbore conditions and highly variable from one well to the next. Using material science and product design, the time to production is significantly reduced by eliminating the variability experienced when using the current dissolvable products. An operating efficiency and downhole frac performance comparison between the intervention-less system and Plug n Perf applications in single well operations is provided. The elimination of interventions, wireline, pump down, explosives, and drill out prove to provide significant benefits over current completions methods and reduced; cost, time, and environmental impact.
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (0.94)
Abstract Multi-horizontal well pads are the norm in unconventional reservoirs development with wells having multi-stage fracture treatments pumped across predefined perforation cluster configurations, horizontal landing positions and well lateral spacings. Inter-intra stage and inter-well stress shadow patterns for a predefined chronological fracturing sequence can be utilized to enhance proppant distribution across the host rock, contacting additional net pay and improving the production performance of wells in ultra-tight reservoirs. 3D geomechanical models of a middle cretaceous carbonaceous shale are calibrated to UAE Shilaif Shale conditions and incorporated into a grid-oriented planar 3D fracture simulator. A large number of simulations are utilized to develop knowledge and understanding regarding the stress shadow effects on fracture geometry related to the geological heterogeneity, completion parameters, hydraulic fracture design and different chronological hydraulic fracturing sequences. The main purpose of this paper is to develop a hydraulic fracturing completion methodology focused on finding a chronological fracturing sequence across several wells that will maximize their production performance and longevity by enhancing the proppant coverage in the host rock.
- North America > United States > Texas (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous > Cenomanian (0.34)
- Phanerozoic > Mesozoic > Cretaceous > Lower Cretaceous > Albian (0.34)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.56)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (1.00)
- Geophysics > Borehole Geophysics (0.67)
- 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)
- (31 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- (2 more...)