Ilam

Abstract Karachaganak is one of the world's largest oil and gas condensate fields in a deep heterogeneous carbonate reservoir with complex sour fluid system located in Western Kazakhstan. Karachaganak's estimated reserves are over 2.4 Bln bbls of condensate and 16 tcf of gas. The asset is co-operated by Shell and Eni through Karachaganak Petroleum Operating (KPO) b.v. Joint Venture. KPO successfully deployed a new KUAT operating center with aim to maximize production and improve collaboration among key functional groups managing day-to-day field activities. Maximizing oil production means getting the most condensate liquids to surface at a given gas (or other) constraints by routing producer wells through the network to arrive at the lowest field GOR. Experience showed that the key success factor was to establish a collaboration between Subsurface and Production departments built upon common understanding of field data. Physical embodiment of this collaboration is the Karachaganak Unified Action Team – KUAT, which means "power" in Kazakh. This center was established in 2020 with physical placement of Petroleum Engineers together with Production, Process and Planning Engineers in one Operating Center at the field site. The objectives of KUAT team include the following short-term integrated activities: Daily well line-up optimization as per integrated limit diagram views Integrated activity planning – e.g. optimized start-up of the new wells and projects Well surveillance planning and execution – from reference plans, EBS and opportunity-based GOR management Flow assurance KUAT team utilizes the industry standard digital solutions like PI and PI vision and Petex type of solvers as well as custom-made integrators like Data Integrator and Network Optimizer (DINO). In order to ensure that production is always maximized and potential downtime is minimized a robust understanding of the limit diagrams and well potentials is required. This information is provided by live integrated dashboards which include the real-time data from subsurface to export routes. The overall contribution from KUAT is estimated at ~7,000 BOPD or 3% of incremental field production. This paper will cover the overview of KUAT journey from early concept development to current state explaining how this center operates today. Workflows and improvements are included in the discussion as well as challenges faced throughout the implementation of newly developed team within the organization

OnePetro

doi: 10.2118/212053-MS

SPE

SPE-212053-MS

SPE Annual Caspian Technical Conference

Country:

Asia > Kazakhstan (0.51)
Asia > Middle East > Iran > Ilam (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Kazakhstan > West Kazakhstan > Uralsk Region > Precaspian Basin > Karachaganak Field (0.99)
Asia > Kazakhstan > Caspian Depression > Caspian Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Production and Well Operations (1.00)
(2 more...)

Technology:

Information Technology > Architecture > Real Time Systems (1.00)
Information Technology > Artificial Intelligence (0.94)

Add feedback

The Benefits of an Integrated Approach (Development, Completion, Production Operation, and Integrity) for Gas-Lift Design on an UAE Offshore Field

Dwivedi, Vibhuti (Petroleum Technology Company) | Al Zaabi, Fatema (ADNOC Offshore) | Jaffres, Benoit (ADNOC Offshore)

OnePetroOctober, 2022

Abstract Gas lift design and optimization contributes to one of the key focus areas of whole production optimization value chain. There have been numerous methods and best practices which goes into design of a successful Gas Lift well as well as established industry best practices for the optimal operations of wells and network (facilities), but still gas lift designs derived for present or future well conditions, fail to respond to every possible operating scenario and end up multipointing, slugging or sub-optimal orifice injections. Well completion and well Integrity are two other important focus areas which are independent from gas lift design but possess major challenges to any gas lift well. During completion of a gas lift well, traditionally GLM (Gas Lift Mandrels) carrying dummy valves are run in hole, to allow for setting packers and testing the tubing/annulus strings. These dummy valves require numerous slickline operations to be retrieved and replaced with live IPO (Injection Pressure Operated) and orifice valves, to be able to gas lift. Depending on the well completion complexity (depth, deviation) and number of gas lift valves, slickline operations performed via rig or barge may require up to 3-5 field days. Since GLV replacement operation requires the use of kick over tools, they are susceptible to incur heavy NPT's and associated HSE risks (Slickline and wireline operations accounts for major carbon footprints in upstream segment). During gas lift operations, high pressure gas injected into casing possess enormous risks to nearby wells and surface facilities in the event of uncontrolled annulus gas leak from a single barrier envelope. Operating a gas lift well below MAASP (Maximum Allowable Annuus Surface Pressure) remains a challenge in assuring the well is operating within its integral envelope. At times it also leads to deferred production should the well needs suspended production in the event of SAP (Sustainable Annulus Pressure) or workover caused by compromised well integrity. In this technical paper, authors will attempt to provide a holistic view of a successful Gas Lift well design by addressing the challenges raised (as above) in different phases and emphasizing on the design approach and technical solutions which were implemented, and benefits realized in terms of optimal gas lift operations, rig/ barge days and deferred production saved.

OnePetro

doi: 10.2118/211571-MS

SPE

SPE-211571-MS

ADIPEC

Country:

Asia > Middle East > UAE (0.71)
Asia > Middle East > Iran > Ilam (0.25)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines: Production and Well Operations > Artificial Lift Systems > Gas lift (1.00)

Add feedback

Effective Neural Networks Models for Inferred Production Prediction in ESP Equipped Wells

Popa, Andrei (Chevron) | Umbriaco, Jacob (Chevron) | Tirtawidjaja, Alexia (Chevron)

OnePetroApril, 2022

Abstract Well production measurement is critical for successful reservoir management and effective decision making to optimize day-to-day field production. The production measurement or well gauging is achieved through physical measurement using Automatic Well Testing (AWT) sites or manually using portable measuring units. When the AWT's are not operational, or in the case when measurements are lacking due to different reasons, well production data points become sparce and can lead to missed production opportunities, poor production allocation and even impact the reserves reporting. The article introduces an Artificial Intelligence approach that uses a neural network to successfully predict the daily well production rates for Electrical Submersible Pumps (ESP) operated wells in the absence of physical measurements. The methodology was applied in a brown field operated under waterflooding recovery mechanism. The predicted well production rates and intelligent guardrail controls were implemented in an established production monitor tool. The tool allows operation by exception through the use of a dashboard to alarm when well problems occur. This work demonstrated how digital technologies can either augment, or to some extent, replace the physical measurements from external devices or processes contributing to improved monitoring, better decision making, and cost reduction. The general example presented shows the value of the technology by generating critical information that helps quickly identify abnormal behaviors such as lost production and prompts timely corrective actions which ultimately lead to field optimization.

OnePetro

doi: 10.2118/209266-MS

SPE

SPE-209266-MS

SPE Western Regional Meeting

Country:

North America > United States (0.88)
Asia > Middle East > Iran > Ilam (0.24)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Reservoir Description and Dynamics (1.00)
Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Production and Well Operations > Artificial Lift Systems > Electric submersible pumps (1.00)
(2 more...)

Technology: Information Technology > Artificial Intelligence > Machine Learning > Neural Networks (1.00)

Add feedback

Data Science Use Case for Brownfield Optimization - A Case Study

Lal, Manish Kumar (Chevron) | Kim, Tae Hyung (Chevron) | Singleton, Darrin M. (Chevron)

OnePetroApril, 2021

Abstract Data Science is the current gold rush. While many industries have benefitted from applications of data science, including machine learning and Artificial Intelligence (AI), the applications in upstream oil and gas are still somewhat limited. Some examples of applications of AI include seismic interpretations, facility optimization, and data driven modeling – forecasting. While still naïve, we will explore cases where data science can be used in the day to day field optimization and development. The Midway Sunset (MWSS) field in San Joaquin Valley, California has over 100 years of history. The field was discovered in 1901 and had limited development through the 1960s. Since the start of thermal stimulation in 1964, the field has seen phased thermal flooding and cyclic stimulation. Recently there has been an increase in heat mining vertical and horizontal wells to tap the remaining hot oil. As with any brownfield, the sweet spots are long gone. Effort is now to optimize the field development and tap by-passed oil, thereby increasing recovery. The current operational focus includes field wide holistic review of remaining resource potential. Resources in the MWSS reservoirs are produced by cyclic steam method. Cyclic thermal stimulation has been effective as an overall depletion process and for stimulating the near wellbore region to increase production. It is imperative to properly identify target wells and sands for cyclic stimulation. Cyclic steaming in depleted zones or cold reservoirs is often uneconomical. The benefit comes when we can identify and stimulate only the warm oil. Identification of warm oil and short listing the wells for cyclic stimulation is a labor-intensive process. The volume of data can get so large that it may not be feasible for a professional to effectively do the analysis. In this paper, we present a case study of data analytics for high grading wells for cyclic stimulation. This method utilizes the machine power to integrate reservoir, and production data to identify and rank wells for cyclic stimulation and potentially increase success rate by minimizing suboptimal cyclic candidates.

OnePetro

doi: 10.2118/200781-MS

SPE

SPE-200781-MS

SPE Western Regional Meeting

Country:

North America > United States > California > Kern County (0.29)
Asia > Middle East > Iran > Ilam (0.24)

Geologic Time: Phanerozoic > Cenozoic (0.47)

Geophysics: Geophysics > Seismic Surveying (0.54)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > California > San Joaquin Basin > Midway-Sunset Field > Webster Formation (0.99)
North America > United States > California > San Joaquin Basin > Midway-Sunset Field > Monterey Formation (0.99)
South America > Brazil > Parnaiba Basin > Block PN-T-68 > California Field (0.97)

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
Management (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)

Technology:

Information Technology > Data Science (1.00)
Information Technology > Artificial Intelligence (1.00)

Add feedback

Conquering the Field

The Way AheadJanuary, 2021

Women on the Frontline is a new section that explores what it is like to be a woman working in the oil industry. This section will examine the issues particular to women in our industry and will strive to inspire young women by sharing the learnings of their more experienced peers. In this first article, we explore the experiences of women working in the field. The contributors to this article all worked in the field and have since moved within their company to office positions. Linda Stuberg is from Norway and spent her field days in Indonesia. She now works in Malaysia as a geophysicist.

The Way Ahead

Country: Asia > Middle East > Iran > Ilam (0.24)

Industry: Energy > Oil & Gas > Upstream (0.70)

Oilfield Places:

Oceania > Australia (0.89)
Asia > Middle East > UAE (0.89)
Asia > India (0.89)

SPE Disciplines:

Well Drilling (0.47)
Reservoir Description and Dynamics > Reservoir Characterization (0.34)

Add feedback

Structural Evolution Impact on Reservoir Quality Distribution in an Early Cretaceous Carbonate Reservoir, UAE

McGeer, Alicia (OMV) | Sellar, Christopher (ADNOC Offshore) | Verma, Ravi (ADNOC Offshore) | Al Naqbi, Dhabia (ADNOC Offshore)

OnePetroNovember, 2020

Abstract The structural evolution and timing of hydrocarbon charge potentially controls the style of diagenetic overprint and the consequent reservoir quality distribution in "Oilfield A." Tilting due to regional tectonic events may have repositioned fluid contacts and influenced the development of stylolites, cementation and microporosity development. A reconstruction of the palaeo structure of Oilfield A was undertaken in order to identify the key structural and diagenetic events, constrain their timing and tie them to seismic properties. Well picks, interpreted 3D seismic horizons and P-Impedance from the inversion of PSTM 3D seismic data were used in this study. The main reservoir from the Early Cretaceous was reconstructed by flattening on progressively shallower overburden horizons. Cross-sections dissecting the structure help to identify structural events. Published data on diagenetic events were reviewed from analogue oilfields and compared to the timing and burial depth of Reservoir 2 in Oilfield A. All key regional structural events and regional petroleum systems evolution were reconciled against the burial history of Oilfield-A. Each structural time step is compared to seismic inversion property P-impedance. Structural flattening of the Reservoir 2 seismic horizon using successively shallower overburden surfaces reveals that a structural four-way dip closure has existed in Oilfield A since the Late Cretaceous. The main closure was initially located in the north-east of the present day field with the deeper flank located to the south-west. Hydrocarbon maturity and migration, potentially from both Jurassic and Early Cretaceous sources, began in the Late Cretaceous and continued through the Tertiary. The structure was tilted towards the north during the Oligo-Miocene Zagros orogeny. At this time, the crest of the field appears to have migrated towards the north-west and the south of the field was uplifted. The palaeo free water level is likely to have been driven deeper in the north and oil may have migrated south into areas of the field previously beneath the palaeo free water level. A relationship is suggested between the position of the palaeostructural crest and low values of P-impedance from seismic inversion (P-impedance is negatively correlated to porosity). This mapping exercise supports the geological concept that oil charge was sufficiently early to have potentially prevented significant cementation on the crest of the field while flank areas became chemically compacted during burial and are consequently more heavily cemented. Structural evolution and hydrocarbon charge are rarely considered as key diagenetic inputs affecting reservoir quality distribution in carbonate reservoirs. Loosely constrained paragenetic sequences are common in reservoir characterization studies. This study uses exploration-style structural reconstruction techniques on a carbonate oilfield development. Identification of key tectonic events and detailed understanding of the timing of hydrocarbon migration into a reservoir are fundamental prior to developing a geological concept and undertaking detailed subsurface modeling of reservoir properties.

OnePetro

doi: 10.2118/202964-MS

SPE

SPE-202964-MS

Abu Dhabi International Petroleum Exhibition & Conference

Country:

Asia > Middle East > Saudi Arabia (1.00)
Asia > Middle East > Yemen (0.94)
Africa > Sudan (0.94)
(5 more...)

Geologic Time: Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous > Campanian (0.88)

Geophysics:

Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.75)
Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (0.55)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Diyab Formation (0.99)
Asia > Middle East > Saudi Arabia > Thamama Group > Kharaib Formation (0.99)
Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Abu Dhabi Field (0.98)
(3 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Sedimentology (0.97)
Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (0.94)

Add feedback

Application of Thermo-Gel Treatment Assisting Multiple Thermal Fluid Huff and Puff for Enhancing Offshore Heavy Oil Recovery

Wu, Jintao (Tianjin Branch of CNOOC Ltd) | Zhang, Lei (Tianjin Branch of CNOOC Ltd) | Huang, Jianting (Tianjin Branch of CNOOC Ltd) | Li, Hao (Tianjin Branch of CNOOC Ltd) | Li, Hongyuan (Tianjin Branch of CNOOC Ltd)

OnePetroNovember, 2020

Abstract Multiple thermal fluid huff and puff, which uses nitrogen, carbon dioxide and hot water as thermal medium, has achieved a high increase of oil production rate in BN reservoir, a heavy oilfield locating at Bohai Bay. Six wells have completed two cycles of thermal huff and puff. Comparing to initial conventional production using natural energy, the periodic well production in first cycle increased to 1.6 times and the annual production rate of the whole reservoir increased from 0.4% to 0.7%. However, due to high formation oil viscosity (413∼741mPa•s) and strong heterogeneity, the injected fluid breakthrough happened three times in the second cycle. On one hand, the well production rate didn't gain an obvious increase because of the heat loss, on the other hand, the surrounding wells which were broken into had to be shut down. Consequently, the annual reservoir production rate was only 0.5%, which was much lower than project design. There is an urgent need to find a suitable solution to the injected thermal fluid breakthrough. The most effective way to restrain the fluid breakthrough is injecting the thermal fluid into all the thermal recovery wells simultaneously, which is not realizable due to the offshore platform space limit. Combinatorial method with thermo-gel treatment have been optimized for more cycles of thermal huff-puff. Thermo-gel polymer and cross-linking agent spontaneously gel when they reach a critical temperature, which is configured between original reservoir temperature and reservoir temperature during thermal huff period. Thermo-gel was injected ahead and entered the high permeability channels mainly. With the plugging effects, the fluid breakthrough was prevented. Meanwhile, the thermal fluid permeated into low permeability zone where remaining oil concentrated, resulting to higher efficiency of injected heat. Thermo-gel treatment was carried out for the rest three wells in the second cycle. Around each of the three thermal injection wells, there were 2∼3 wells that could have fluid breakthrough and only one surrounding well happened. Compared with the first three wells in the second cycle, the periodic oil increment of the last three wells increased to 2.6 times and the average effective period extended 105 days. Field practice showed a positive synergistic effect between thermal huff-puff and thermo-gel treatment. In the help of thermo-gel treatment, incremental oil production for single well has reached 1.58×10m in the past few years. Our experiences show that such thermo-gel treatment assisting technology for thermal recovery is effective for enhancing oil recovery of heavy oil fields and meets the demand of high speed development for offshore oil fields.

OnePetro

doi: 10.4043/30193-MS

OTC

OTC-30193-MS

Offshore Technology Conference Asia

Country:

Asia > China (0.95)
Asia > Middle East > Iran > Ilam (0.24)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Asia > China > Liaoning > Bohai Basin > Liaohe Basin > Liaohe Field (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)

Add feedback

Dual Function Chemicals in Resolving Emulsion and Water Clarification for EOR and Normal Emulsion Application

Halim, Nor Hadhirah (PETRONAS) | Salleh, Intan Khalida (PETRONAS)

OnePetroNovember, 2020

Abstract Emulsion created by EOR chemical flooding is difficult to break due to the presence of alkali and surfactant tightly bound with the oil and water. Many compounds have been used as demulsifiers in breaking this tight emulsion. Dual Function Demulsifier (DFD) is a copolymer based demulsifier synthesized for demulsification of water-in-oil and oil-in-water emulsion. By providing essential functionality with strong dehydration and dewatering capabilities, it is effective to dehydrate the oil at the separation point whilst improving the water clarity. DFD formulated for normal emulsion was piloted in Field B, Malaysia with encouraging results better than incumbent chemicals during 8 days field trial. For EOR emulsion, since there is no EOR application in Malaysia as yet, the DFD chemical was tested at dynamic condition using Multi-Functional Separator Flow Test. The flow test involves a continuous fluid flow from the pipeline into the mini separator simulated Field A separator temperature of 60°C and 15 minutes retention times using 40 Liters commingled crude from Field A and 60 Liters Produced Water containing the EOR chemicals. DFD implemented for pilot in Sarawak offshore been able to resolve the normal emulsion within Field B separator temperature of 40°C and 4 hours of separator and flow lines retention times until crude oil terminal. At 25 ppm DFD 0815, the chemical was able to treat the emulsion to less than 1% and reduced the Basic sediment & Water (BS&W) to 0.43%. This certainly meet the BS&W specification of the saleable crude to be less than 0.5%. DFD also reduced the Oil in Water (OIW) to 155 ppm from 900 ppm which the reduction is about 82%. For EOR induced emulsion study, 50 ppm of DFD A13 has proved to work successfully in the dynamic condition testing using Mini Separator Flow Test. The emulsion has been resolved from 30% to 1% and the Oil in Water was reduced from 239 ppm to 49 ppm. These two cases have proven the dual function capability of this chemical which is unique from the commercial demulsifier.

OnePetro

doi: 10.4043/30256-MS

OTC

OTC-30256-MS

Offshore Technology Conference Asia

application, demulsifier, dfd 0815, dual function demulsifier, emulsion, injection, normal emulsion, normal emulsion application, Offshore Technology Conference, oil in water, PPM, produced water discharge, reduction, resin alkoxylate, retention time, separation and treating, surfactant, Upstream Oil & Gas, water phase

Country:

Asia > Malaysia (0.69)
Asia > Middle East > Iran > Ilam (0.24)

Industry:

Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Production and Well Operations (1.00)
Health, Safety, Environment & Sustainability > Environment > Water use, produced water discharge and disposal (1.00)
Facilities Design, Construction and Operation > Processing Systems and Design > Separation and treating (1.00)

Add feedback

Application of the Integrated Model for Increased Efficiency of the Operations of the High Sulphur Oil Fields

Zhigalov, Denis Nikolaevich (KogalymNIPIneft, LUKOIL Engineering LLC Branch in Tyumen) | Beslik, Artyom Vladimirovich (KogalymNIPIneft, LUKOIL Engineering LLC Branch in Tyumen) | Mitroshin, Alexander Valentinovich (PermNIPIneft, LUKOIL Engineering LLC Branch in Perm) | Volkov, Vladimir Arkadyevich (PermNIPIneft, LUKOIL Engineering LLC Branch in Perm) | Rychkov, Andrey Fyodorovich (Lukoil Engineering LLC) | Lapin, Kirill Sergeevich (LUKOIL Komi LLC)

OnePetroOctober, 2020

Summary At present, in the oil community due to active implementation of information systems, modern well survey technologies, systems of registration of various data coming from oil fields, interest in the tasks of building mathematical models of oil and gas production processes has increased. The «Smart Field» concept is a set of organizational, technological and information solutions for managing oil fields and oil production facilities, based on formalized models of business processes, enterprise operating model, asset integrated model ensuring optimal management of the asset, while meeting targets and existing limitations. It is based on a mandatory procedure of complex analysis and decision-making based on integration of information, technology and personnel. An integral part of the «Smart Field» project is an Integrated Oil Field Model (IM), which includes the following components: formation model, well model, gathering and transportation system (G&TS) model, formation pressure maintenance system (FPM) model. The integrated model is a tool for calculating potential capacity and limitations, production optimization and performance indicators planning, taking into account mutual influence of the integrated model components. Vostochno-Lambeishorskoye field is located in Usinsk District of the Republic of Komi in the Russian Federation. The average oil flow rate for this field is about 100-150 tons per day, field watercut - 15.5%, the field is under the first stage of development. Taking into account the asset development prospects the integrated model construction and its further application will make it possible to increase the economic efficiency of this field development. In view of existing problems associated with the specifics of operation of electrical submersible pump (ESP) units at fields with high content of hydrogen sulfide, it is proposed to introduce a gas-lift operation method. In order to assess the technological feasibility of converting the well to gas-lift operation method and the project profitability, this article provides equipment selection and simulation with the use of a specialized software product. The aim of the article is to solve the problem of low efficiency of high-sulfur field operation by designing a gas-lift method using integrated simulation tools. The following tasks have been considered and solved as part of this work: Gaslift calculation for the entire production well stock in well simulation models; Sensitivity analysis of the obtained layouts for changes in formation parameters; Creation of a simulation model of a ground gas injection system; Conducting a series of calculations using an integrated field simulation model, where Visual basic for applications (VBA) script acts as a control element; Economic assessment of the proposed options. The integrated model is updated for the field operation parameters as of 10.01.2020. The data are provided by the Customer and are assessed as reliable.

OnePetro

doi: 10.2118/201961-MS

SPE

SPE-201961-MS

SPE Russian Petroleum Technology Conference

Country:

Europe > Russia (0.89)
North America > United States > Arkansas (0.45)
North America > United States > Louisiana (0.40)
Asia > Middle East > Iran > Ilam (0.24)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Europe > Russia > Volga Federal District > Orenburg Oblast > Precaspian Basin > Orenburg Field (0.99)
North America > United States > Louisiana > Sulphur Field (0.98)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Simulation (1.00)
Production and Well Operations > Artificial Lift Systems > Gas lift (1.00)
Management > Asset and Portfolio Management > Integrated asset modeling (1.00)
Data Science & Engineering Analytics > Information Management and Systems (1.00)

Technology: Information Technology > Modeling & Simulation (1.00)

Add feedback

Wavefield recovery with limited-subspace weighted matrix factorizations

Zhang, Yijun (Georgia Institute of Technology) | Sharan, Shashin (Georgia Institute of Technology) | Lopez, Oscar (Sandia National Laboratories) | Herrmann, Felix J. (Georgia Institute of Technology)

OnePetroOctober, 2020

Modern-day seismic imaging and monitoring technology increasingly rely on dense full-azimuth sampling. Unfortunately, the costs of acquiring densely sampled data rapidly become prohibitive and we need to look for ways to sparsely collect data, e.g., from sparsely distributed ocean bottom nodes, from which we then derive densely sampled surveys through the method of wavefield reconstruction. Because of their relatively cheap and simple calculations, wavefield reconstruction via matrix factorizations has proven to be a viable and scalable alternative to the more generally used transform-based methods. While this method is capable of processing all full azimuth data frequency by frequency slice, its performance degrades at higher frequencies because monochromatic data at these frequencies is not as well approximated by low-rank factorizations. We address this problem by proposing a recursive recovery technique, which involves weighted matrix factorizations where recovered wavefields at the lower frequencies serve as prior information for the recovery of the higher frequencies. To limit the adverse effects of potential overfitting, we propose a limited-subspace recursively weighted matrix factorization approach where the size of the row and column subspaces to construct the weight matrices is constrained. We apply our method to data collected from the Gulf of Suez, and our results show that our limited subspace weighted recovery method significantly improves the recovery quality. Presentation Date: Tuesday, October 13, 2020 Session Start Time: 9:20 AM Presentation Time: 11:25 AM Location: Poster Station 11 Presentation Type: Poster

OnePetro

doi: 10.1190/segam2020-3428365.1

SEG

SEG-2020-3428365

SEG International Exposition and Annual Meeting

Country:

Asia > Middle East > Saudi Arabia (0.25)
Africa > Middle East > Egypt (0.25)
Asia > Middle East > Iran > Ilam (0.24)

Genre:

Research Report > New Finding (0.54)
Overview (0.46)

Geophysics: Geophysics > Seismic Surveying > Surface Seismic Acquisition > Marine Seismic Acquisition (0.54)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Data Science & Engineering Analytics (1.00)

Technology: Information Technology > Artificial Intelligence > Machine Learning (1.00)

Add feedback

Filters

Collaborating Authors

Karachaganak Unified Action Team – KUAT Journey to Cross-Functional Collaboration

The Benefits of an Integrated Approach (Development, Completion, Production Operation, and Integrity) for Gas-Lift Design on an UAE Offshore Field

Effective Neural Networks Models for Inferred Production Prediction in ESP Equipped Wells

Data Science Use Case for Brownfield Optimization - A Case Study

Conquering the Field

Structural Evolution Impact on Reservoir Quality Distribution in an Early Cretaceous Carbonate Reservoir, UAE

Application of Thermo-Gel Treatment Assisting Multiple Thermal Fluid Huff and Puff for Enhancing Offshore Heavy Oil Recovery

Dual Function Chemicals in Resolving Emulsion and Water Clarification for EOR and Normal Emulsion Application

Application of the Integrated Model for Increased Efficiency of the Operations of the High Sulphur Oil Fields

Wavefield recovery with limited-subspace weighted matrix factorizations

Site News

Collaborating Authors

Ilam