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Collaborating Authors
Bass Strait
Abstract The Permian Basin is currently the most active unconventional resource play in North America. The combination of high quality Petrophysical and Geomechanical characteristics together with advances in horizontal drilling, and completion innovations in hydraulic fracturing has allowed the successful development of several stacked reservoir targets within this basin. This paper focuses on horizontal wells targeting different benches, from Wolfcamp to the First Bone Spring formation. It presents the use of reservoir flow facies defined from the guidance of the geological and petrophysical facies to predict best potential landing targets. These flow-quality facies were created using machine learning techniques. Geological and petrophysical facies were initially defined using 756 petrophysical wells, 9 facies training wells and 64 "high tier wells" with NMR, Sonic and Minerology logs. 34 Core-calibrated petrophysical models were also incorporated. Rock mechanical facies were defined from sonic and geological data integrated with closure pressure gradients, net pressure and end-of-job shut-in pressure matching for hundreds of fracture treatment stages. Through an integrated multidomain workflow combined with experience from neighboring areas, 14 Production Quality Faces were defined from the combination of 9 Geo-Facies and 11 Rock Quality Facies This facies definition evolved into a 3D geo-model, where sector models were cut across multiple areas of interest where engineering datasets (micro-seismic, DFIT, core data, etc) existed. Finally, several poro-perm relations and facies-based relative permeability curves were defined through the history-matching of production data. Using the presented workflow, different potential landing targets in the Delaware Basin were evaluated for optimal development strategies, from Avalon to Wolfcamp A. Machine-Learning Based Facies Model for the Permian Basin A series of property-specific machine learning based facies models were created using a set of training wells spread across the Permian Basin and extending from the Upper Bone Springs through Wolfcamp-A formations. The model is underpinned by the wireline logs and is extended to three coupled discipline-centric facies sets. The first of these is the Reservoir Quality Facies (RQF), which discriminates the porosity, saturation and kerogen properties of the reservoir independent of geologic characteristics. Next is the Geofacies (GF), which does the reverse. It discriminates the mineralogic properties of the formation independent of the pore system. Third is the Geomechanical Facies (GMF), which discriminates the mechanical properties of the rock independent of the other influences. Each of these coupled facies sets allows for independent analysis but can be combined to produce additional facies sets that can be used for a 3D reservoir model. For this purpose, the GF and RQF were cross-tabulated to produce Production Quality Facies, PQF. This interplay of RQF and GF shows how the mineralogy (independent porosity/saturation) and porosity/saturation (independent mineralogy) relate. It is the combination of these two fundamental properties sets that describes expected flow behavior but by providing the fundamental inputs (porosity and mineralogy) separately, we can also evaluate them independently. This is a benefit of having discrete coupled sets of property facies.
- North America > United States > Texas (1.00)
- North America > United States > New Mexico (1.00)
- South America > Argentina > Neuquรฉn Province > Neuquรฉn (0.28)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- South America > Argentina > Patagonia > Neuquรฉn > 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)
- (27 more...)
Stratal Surfaces Honoring Seismic Structures and Interpreted Geologic Time Surfaces
Wang, Fu (University of Science and Technology of China, Tongji University) | Wu, Xinming (University of Science and Technology of China) | Zeng, Hongliu (The University of Texas at Austin) | Janson, Xavier (The University of Texas at Austin) | Kerans, Charles (The University of Texas at Austin)
Seismic horizons play a significant role in reservoir model construction and sedimentary facies interpretation, providing crucial low-frequency constraints for seismic inversion. In basin and regional interpretations, the assumption that seismic reflections represent a stratigraphic surface with constant geologic time is significant for guiding seismic interpretation. This assumption may fail when applied to local reservoir scales due to common geologic time transgressions of a particular event in regular wavelet frequency. There will be inconsistencies between seismic events and stratigraphic surfaces. To address this issue and obtain relatively accurate stratal interpretations, we develop a hybrid horizon extraction method honoring both seismic structures and time-stratigraphic frameworks, in which seismic reflection structures provide local details and interpreted geologic time surfaces offer critical constraints. First, we develop concepts and a workflow using a realistic outcrop model. We propose a new geology-guided structure tensor by fitting a gradient vector of seismic images and geologic time surfaces. We also consider existing geologic conditions, such as unconformities, and fuse them into our method to calculate accurate slopes and generate reliable relative geologic time (RGT) images at a fine scale, followed by making slices. Further, we extend the proposed method to 3D seismic data volumes. Our experiments, conducted using simulated and field data, show the superiority and accuracy of our hybrid method compared with the slope-based and stratal slicing methods. These results highlight the potential for applying the proposed method to fine-scale subsurface modeling.
- North America > United States > Texas (1.00)
- Asia (0.67)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.34)
- 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)
- (23 more...)
Scaling Issue in the Platform Area of Tengiz Field and Preventing Solutions
Myrzabayeva, A. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Kydyrgazy, A. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Sadyrbakiyev, R. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Kalzhekov, N. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Gaziz, D. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Orazov, B. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Williams, D. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Lu, H. (TengizChevroil, Atyrau, Atyrau region, Kazakhstan) | Yan, C. (Chevron, Houston, Texas, USA)
Abstract Even though most wells in the Tengiz Field produce virtually water free oil (less than 1% water cut), inorganic scales have been observed in many wells. Acid stimulation treatment programs for existing wells with deteriorated productivity include implementation of scale inhibitors, however this reactive approach might not always be the best way to proceed. The scope of the paper is to identify the main parameters which increase the probability of scale formation before a well is put on production and proactively treat such wells with scale inhibitors. Previously Tengizchevroil (TCO) has conducted an extensive research project to reduce the need for frequent acid treatments while maintaining well deliverability at sustained rates. Compatibility and core flood tests have been performed to choose the best scale inhibitor, and an extensive surveillance program has been developed to track residual inhibitor concentration to timely plan subsequent stimulation treatments. This paper covers the next step of the study and includes analysis of the recent cases of scale formation including identification of similar properties between the cases to enable forecasting of the tendency of all new wells to encounter scale formation. The study consists of three main steps โ analysis of formation water and solid samples, analysis of open hole log data and analysis of production history for Tengiz and Korolev wells. The formation of precipitates is dependent on ion concentration in the water. Analysis of the water composition for each region and formation has been performed to identify which set of parameters increases the tendency to form scale. Solubility of inorganic salts is highly dependent on pressure and temperature changes taking place in the wellbore; therefore, the scale prediction study also includes these factors with the correlation to well region and reservoir properties each well penetrates. Weighted ranks for every parameter have been developed to rank a well after the drilling stage and make a proactive decision on whether scale inhibitor injection should be included in the primary acid stimulation treatment program, or if it should be considered only for reactive acid treatments in case of loss in well productivity. This paper aims to share the best practices in scale inhibitor design, analysis of well parameters at the well completion stage and calculation of well tendency to scale formation. The decision tree for identification of well candidates for proactive scale treatments applicable for the Tengiz field presented in the paper can potentially be used in other carbonate fields.
- Geology > Mineral > Sulfate (0.69)
- Geology > Geological Subdiscipline (0.68)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Oceania > Australia > Victoria > Bass Strait > Gippsland Basin (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Tengiz Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Korolev Formation (0.99)
Genesis, Distribution, and Characterization of a Paleokarst Subsurface River System in the Tahe Area, Tarim Basin, Western China
Lyu, Xinrui (School of Energy Resources, China University of Geosciences (Beijing)) | Ju, Binshan (Petroleum Exploration and Production Research Institute, SINOPEC) | Wu, Xingwei (School of Energy Resources, China University of Geosciences (Beijing) (corresponding author)) | Xiao, Fengying (Petroleum Exploration and Production Research Institute, SINOPEC)
Summary Subsurface river systems constitute one of three major paleokarst types that make up Ordovician reservoirs in the Tahe area of the Tarim Basin. The total length of the river system is approximately 400 km, and the reserves associated with this karst type are more than 200 million tons. However, it is manifested that 47% of drilled wells have not encountered river paleokarst, while 50% of wells that have encountered river paleokarst are fully filled due to the poor understanding of the paleokarst of this region, resulting in a significant variation of production capacities. In this study, we propose a detailed data integration approach with outcrops, drilling, logging, seismic profiles, and dynamic data to delineate the complex paleokarst river system in the Tahe area. The karst geological theory with reservoir characterization is combined in particular. The workflow of clarifying the main controlling factors, architecture types, and development distribution modes of the subsurface river system is established. Fill material type, sequence of fill structure, and fill controlling factors are also revealed. A quantitative characterization method of the subsurface rivers is established adopting predictions based on seismic data and high-resolution geostatistical and geological modeling. The Ordovician reservoirs in the Tahe area comprise three paleokarst river systems with different characteristics. Karst paleogeomorphology is the main control over the overall flow direction and plane distribution of the subsurface rivers. Changes in the surface of the phreatic zone are crucial in controlling the vertical layers and scale of the rivers. The combined action of faults plays a decisive role in controlling the anastomosing pattern of the rivers. Single-branch channels, reticulated channels, and structural corridors in single-layer or multilayer styles are the main subsurface river types. Trunk channels, branch channels, hall caves, and inlets/outlets are dominant structures in the architecture of the river system. Sand-mud, breccia, and chemically precipitated materials are the most common fill types. Three typical sequences of fill structure and four spatial combination modes exist in the subsurface river system. The morphology and fill characteristics of rivers are predictable using seismic attributes, such as frequency division energy, frequency division inversion, and coherent energy gradient. 3D models are constructed by multivariate control multipoint geostatistical method, which can characterize the strong heterogeneity characteristics of subsurface river systems. This complex paleokarst system enables remarkable results for the adjustment of the reservoir development plan through quantitative characterization.
- Asia > China > Xinjiang Uyghur Autonomous Region (1.00)
- North America > United States > Texas (0.67)
- North America > United States > Texas > Fort Worth Basin > Northwest Field (0.99)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin > Tahe Field (0.99)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin > Tabei Field (0.99)
- (2 more...)
Gulf of Mexico (GOM) Lease Sale 261 will not be held on 8 November as scheduled by the US Bureau of Ocean Energy Management (BOEM). The agency said this week that as a result of the order issued by the US Court of Appeals for the Fifth Circuit on 26 October in Louisiana v. Haaland(Case No. 23-30666), it would postpone the sale. An appeals panel stayed a preliminary injunction granted earlier to plaintiffs, the American Petroleum Institute, State of Louisiana, and Chevron, who petitioned the court to have the sale move forward. The next arguments in the case are set for 13 November. Sale 261 was originally scheduled for 27 September, and later scheduled for 8 November, in response to judicial orders.
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas (1.00)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Pโnyang Field (0.89)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Elk-Antelope Field (0.89)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Angore Field (0.89)
- (11 more...)
Properties of high-performing horizontal wells in the Midland Basin
Male, Frank (Pennsylvania State University at University Park) | Dommisse, Robin (University of Texas at Austin) | Sivila, Livia J. (SWORD) | Hamlin, Scott (University of Texas at Austin) | Goodman, Emery D. (University of Texas at Austin)
Abstract What do the best horizontal wells in the Midland Basin Spraberry and Wolfcamp tight oil plays have in common? What differentiates them from less productive wells? In this study, we address these questions with data assembled from a high-resolution geomodel and public and vendor-sourced completions data. From 10,064 tight oil horizontal wells, 101 (1%) of the most productive wells by first-year oil production and 101 of the most productive wells by length-normalized first-year production are selected. We compare the completion, spacing, petrophysical, landing, and fluid properties between the most productive wells and others. Among the discoveries, we find that Wolfcamp A wells are more likely to be in the top 1%, especially those drilled in the carbonate-poor rock. Average hydrocarbon-filled pore volume and oil formation factors still lead to high-performing wells. High pressure is an important consideration for Wolfcamp B top producers. All of the best oil producers have low producing gas-oil ratios. The top 1% of wells are usually the first well in the pad to be completed, and they come from above-average pads. The top 30% of completions lead to the top 1% of wells more often than extremely intense completions. Operators can apply these results to the further development of the Midland Basin. Specifically, they can prioritize development areas in Wolfcamp A with low carbonate abundance and save costs by not implementing extremely intense completions.
- Geology > Rock Type > Sedimentary Rock (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (0.98)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.46)
- 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)
- (36 more...)
Mero Field: Integrated Development, Challenges and Innovations
Neder, Ana Luiza (Petrobras, Rio de Janeiro, RJ, Brasil) | Calรดba, Guilherme Marques (Petrobras, Rio de Janeiro, RJ, Brasil) | da Silva, Letรญcia Soares (Petrobras, Rio de Janeiro, RJ, Brasil) | Hayashi, Mauro Yuji (Petrobras, Rio de Janeiro, RJ, Brasil)
Abstract Mero field is among the biggest hydrocarbon discoveries in Brazilian pre-salt province and turned out to be a giant and high productivity reservoir. However, it has characteristics such as thick and heterogeneous carbonate reservoir, high reservoir pressures, high Gas-Oil Ratio (GOR), high CO2 content and presence of H2S that makes exploration and production challenging, as it requires specialized equipment and advanced technologies. An important pillar for the field, integrated development, is the Project Based Technology Development. Mero leverages existing or innovative technologies and aims to identify and close technology gaps in an integrated approach to maximize project value and increase its attractiveness. One of the primary challenges in highly complex reservoir, such as Mero, is deep reservoir understanding, and a robust drainage plan strategy. To mitigate all the main risks that could affect the Project results, Data Acquisition in the Production Phase must be planned and executed to minimize impacts on the Project deployment, obtain the information in time for optimizing the Project, and maximize the production and results at every moment. To maximize oil recovery and obtain a sustainable development, Mero Project considers the reinjection of gas and CO2 through alternating water and gas injection method (WAG) in all injector wells. A variety of offshore technologies were pushed beyond its previous limits, establishing industry "firsts", which have enabled an accelerated approval process and the development of the next production systems. To overcome all the technical and economic challenges, the Consortium created an integrated cooperative environment. As a result of the big integration between Consortium members and the supply chain companies involved, Mero Project is conceived through the application of several cutting-edge technologies, enabling the recovery of this large reserve with competitive break-even and robust carbon storage in the reservoir. Those practices were key to deploy two early production systems (FPSO Pioneiro de Libra) and one definitive system (FPSO Guanabara) โ currently the higher FPSO in production in Brazil. The total field production is around 230.000 bpd and there are three others FPSOs to be deployed in the coming years. A compiled of practices applied to overcome the Mero field challenges and maximize the project's results. Those practices came from all the technical disciplines, such as Reservoir, Wells, Subsea, FPSO and Operations, as well as Compliance, HSE and management of the Production Sharing Contract. Some Technologies developed include but are not limited to Permanent Reservoir Monitoring (PRM), Cargo Transfer Vessel (CTV) and HISEPยฎ, a Petrobras patented technology specifically designed to deal with high CO2 and gas content in Mero Reservoir.
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Libra Block > Mero Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Libra Block > Libra Field > Guaratiba Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Libra Field > Guaratiba Formation (0.99)
- (2 more...)
Horizontal Well Design to Optimize CO2 Sequestration and Oil Recovery in the Permian
Gang, T. (Occidental Petroleum Corporation) | Jones, A. (Occidental Petroleum Corporation) | Bandyopadhyay, P. (Occidental Petroleum Corporation) | Tovar, F. (Occidental Petroleum Corporation) | Bealessio, B. (Occidental Petroleum Corporation)
Abstract This paper presents a reservoir modeling study about positioning horizontal wells to optimize carbon sequestration and oil recovery simultaneously in the Wasson field, which is one of the largest reservoirs in the Permian Basin with 6 billion barrels of original oil in place. A significant portion of this field has been under CO2 injection for enhanced oil recovery for decades, so the CO2 gathering, processing, and distribution network in the area makes the Wasson area extremely cost-competitive as a CO2 storage site. Transitioning the source of CO2 injected in the Wasson area from natural to anthropogenic has the potential to sequester hundreds of millions of metric tons of carbon in the coming decades. Although the traditional development strategy has achieved attractive economic returns in the better-quality rock, novel well configurations are needed to be economically successful as development is expanded to areas with lower rock quality. We used a compositional, history-matched reservoir model to perform a sensitivity study of lateral section length, horizontal orientation, spacing, and vertical placement for both production and injection wells. We also studied the vertical placement of the wells with respect to the main oil column (MOC) and the residual oil zone (ROZ), a distinctive characteristic of the Permian Basin. In all the scenarios, the MOC is to be co-developed with the ROZ. Since our focus was on the lower-quality rock areas, we selected horizontal wells due to their success in the cost-effective development of tight reservoir rocks. The significant remaining greenfield potential in the Wasson area offers an opportunity for a complete revolution of the development strategy from vertical to horizontal wells. The most important finding of this study is that the vertical placement of the horizontal injector has a significant effect on oil recovery and lifecycle CO2 retention. Placing the injector close to the bottom of the ROZ and the producers in the MOC resulted in the highest carbon sequestration. The optimized case improved CO2 sequestration by 40% over the base case. The absence of significant vertical flow barriers in the area, along with our prior understanding of the reservoir heterogeneity and CO2 phase behavior, enabled us to optimize well placement to take advantage of gravity drainage. This configuration exposed a larger section of the reservoir volume to the injectant, resulting in a higher sweep efficiency. Our work provides relevant guidance on the design of future developments using horizontal wells to optimize carbon sequestration and incremental oil recovery simultaneously during CO2 EOR and carbon capture, use, and storage (CCUS) projects. These findings are likely to lead to technical and economic success, even in the poor rock quality areas in the Wasson reservoir, significantly increasing the sequestration and oil recovery potential of this field.
- North America > United States > Texas > Yoakum County (0.35)
- North America > United States > Texas > Gaines County (0.35)
- Geology > Geological Subdiscipline (0.68)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.46)
- 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)
- (25 more...)
Abstract High uncertainty of water saturation from petrophysical interpretation has been recognized as a challenge in the Permian Basin for years. Such challenges include, but are not limited to, variable Archie's parameters (m and n) due to the formation heterogeneity, variable formation water salinity, and thinly bedded nature. These challenges make dielectric logging a unique opportunity in tight unconventional reservoirs. Dielectric logging is sensitive to water content and provides water-filled porosity without having to know Archie's empirical parameters or water salinities, which are required with resistivity log interpretation. In addition, dielectric logging offers high vertical resolution logs to address thin-bed issues. Moreover, because of the extremely low permeability of the shale reservoirs, there is effectively no invasion of the borehole fluids into the formation. Thus, in these reservoirs, dielectric logging directly provides water-filled porosity of the undisturbed zone. In this paper, we will share two case studies of dielectric logging in several formations of the Permian Basin which wide-band dielectric measurements on core samples in the lab were also made. A recently developed interpretation model, DCRIM (Dual-frequency Complex Refractive Index Method) is tested and further extended to a wider frequency band. It is observed that the DCRIM method is valid at the frequency as low as 100 MHz in the studied wells. Compared with several traditional interpretation methods such as CRIM, bi-modal, and SMD methods, the new method has significant advantages over the existing approaches since it does not require inputs for either matrix or hydrocarbon permittivity, including kerogen permittivity, to derive water-filled porosity as do existing approaches. The new method enables the elimination of all associated uncertainties with formation mineral models in complex lithologies, unknown mineral permittivity endpoints and, most importantly, the poorly defined permittivity of kerogen. It only requires the relatively well-known input of formation temperature. Thus, the new method provides a more robust, streamlined, and consistent interpretation of the dielectric dispersion logs in tight rocks and potentially reduces the uncertainty on the estimation of hydrocarbons in place. The new method was applied in two selected wells with the availability of water saturation from core samples and other advanced logs such as Nuclear Magnetic Resonance (NMR). After Quality Assurance/Quality Control (QA/QC) the raw dielectric logging data, the water-filled porosity (or water saturation when the total porosity is available) from dielectric logging data is benchmarked against the core data. It is concluded the new method using dielectric logging data from two frequencies presents a good solution to reduce the petrophysics uncertainty and should be considered as a reliable alternative of resistivity-based interpretation when optimizing petrophysical analysis workflows in the Permian Basin.
- North America > United States > Texas (1.00)
- North America > United States > New Mexico (1.00)
- Geology > Mineral (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.36)
- 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)
- (28 more...)
CO2 WAG Huff-N-Puff for Waterflooded Conventional Reservoirs: Design and Field Learnings from Deployment in the Permian Basin of West Texas
Bandyopadhyay, P. (Occidental Petroleum Corporation, Houston, TX, USA) | Andel, D. (Occidental Petroleum Corporation, Houston, TX, USA) | Hampton, D. W. (Occidental Petroleum Corporation, Houston, TX, USA) | Stone, L. D. (Occidental Petroleum Corporation, Houston, TX, USA)
Abstract Single well Huff-N-Puff schemes have been attempted in waterflooded conventional reservoirs in the past, to limited success. The novelty of the method discussed in this paper is the inclusion of a water-injection cycle post CO2-injection "huff". Simulation models showed that this modification significantly increases the yield of incremental oil and increases retention of injected CO2 in the reservoir. A field experiment was designed and implemented in a San Andres field, using a specially designed CO2-gas lift bottom hole assembly that allowed injection and production with the same bottom-hole assembly. This design reduced the need for workover operations between production and injection cycles, as well as allowing injection and production logging of the reservoir zone to better understand the results of the process. We describe the design process for a cyclic CO2-alternating-water injection scheme for waterflooded conventional reservoirs from simulation to field execution. We also discuss operational learnings and resulting best practices for artificial lift, three-phase separation, and well testing that were developed for this recovery method. Results from the field pilot yielded peak incremental oil production rates over six times above the baseline water flood at the producer-well level. Additionally, the gas-lift assembly proved effective in allowing real-time wellbore monitoring, which greatly enhanced the understanding of the CO2-HnP in a single-well system.
- North America > United States > Texas > Hockley County (0.28)
- Europe > United Kingdom > North Sea > Central North Sea (0.24)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.68)
- 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)
- (27 more...)