Thailand
PTT Exploration and Production (PTTEP) has announced plans to conduct a study on carbon storage potential in the Northern Gulf of Thailand together with Japanese counterpart INPEX. The two companies will be working under a collaboration between the Thai Department of Mineral Fuels and the Japan Organization for Metals and Energy Security. The study aims to lay a foundation for development of a carbon capture and storage (CCS) hub in the Eastern Economic Corridor (EEC) of Thailand. Montri Rawanchaikul, CEO of PTT Exploration and Production (PTTEP), said that, under the Northern Gulf of Thailand CCS Exploration project, PTTEP is ready to join INPEX to conduct a study on carbon storage potential within the northern area of the Gulf of Thailand. "PTTEP is pleased to work alongside INPEX in this study," he said.
- Government > Regional Government > Asia Government > Thailand Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Shallow-water carbonate structures are characterized by different shapes, sizes and identifying features, which depend, among other factors, on the age of deposition and on the carbonate factory associated with a specific geologic period. These variations have a significant impact on the imaging of these structures in reflection seismic data. This study aims at providing an overall, albeit incomplete, picture of how the seismic expression of shallow-water carbonate structures has evolved through deep time. 297 shallow-water carbonate systems of different ages, spanning from Precambrian to present, with a worldwide distribution of 159 sedimentary basins, have been studied. For each epoch, representative seismic examples of shallow-water carbonate structures were described through the assessment of a selection of discriminating seismic criteria, or parameters. The thinnest structures, commonly represented by ramp systems, usually occurred after mass extinction events, and are mainly recognizable in seismic data through prograding clinoform reflectors. The main diagnostic seismic features of most of the thickest structures, which were found to be Precambrian, Late Devonian, Middle-Late Triassic, Middle-Late Jurassic, some Early Cretaceous pre-salt systems, #8220;middle#8221; and Late Cretaceous, Middle-Late Miocene and Plio-Pleistocene, are steep slopes, and reefal facies. Slope-basinal, resedimented seismic facies, were mostly observed in thick, steep-slope platforms, and they are more common, except for megabreccias, in post-Triassic structures. Seismic-scale, early karst-related dissolution features were mostly observed in icehouse, platform deposits. Pinnacle structures and the thickest margin rims are concentrated in a few epochs, such as Middle-Late Silurian, Middle-Late Devonian, earliest Permian, Late Triassic, Late Jurassic, Late Paleocene, Middle-Upper Miocene, and Plio-Pleistocene, which are all characterized by high-efficiency reef builders.
- South America (1.00)
- North America > United States > Texas (1.00)
- North America > Canada (1.00)
- (5 more...)
- Phanerozoic > Paleozoic > Devonian (1.00)
- Phanerozoic > Mesozoic > Triassic (1.00)
- Phanerozoic > Mesozoic > Jurassic (1.00)
- (5 more...)
- Geology > Structural Geology > Tectonics (1.00)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Reef Environment (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- (3 more...)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (0.93)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.67)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.45)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.45)
- South America > Venezuela > Caribbean Sea > Gulf of Venezuela > Gulf of Venezuela Basin > Cardon IV Block > Perla Field (0.99)
- Oceania > Australia > Western Australia > Western Australia > Timor Sea > Browse Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Timor Sea > Browse Basin (0.99)
- (82 more...)
The impermeable caprock within a geothermal system serves the purpose of effectively sealing the reservoir, resulting in the elevation of both pressure and temperature. This sealing mechanism plays a crucial role in the long-term preservation of the system, while also contributing to its overall sustainability. Caprock failure subsequent to seismic activity near a geothermal site can lead to the permeation of the caprock structure, resulting in diminished sealing capabilities and a decline in the reservoir temperature. Additionally, this process alters the geochemical composition of the water by creating a hydrothermal mixture zone that disrupts the resistivity structure of the caprock, which is typically characterized by low resistivity values due to its substantial clay content and mineral alteration. This study focuses on investigating the integrity of the caprock at ฦกnakkale-Tuzla geothermal field in Turkey, where the water temperature and conductivity were reported to have decreased after a moderate magnitude earthquake and subsequent aftershocks. For this purpose, we performed magnetotelluric (MT) measurements, a method known for its sensitivity to geochemical reactions. These measurements were conducted along two parallel profiles that encompassed a total of 32 stations. Particle swarm optimization (PSO) technique was employed to overcome subtle difficulties associated with conventional inversion methods when modeling the MT data of complex formations. This is the first study that overcomes the difficulties emanating from the caprock failure by modeling MT data using PSO. Our modeling approach produced resistivity images that we interpreted as the signature of the failed caprock following the earthquake at the study site. Our results appear to confirm the documented geochemical changes or hydrothermal mixture zone about caprock structure.
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East > Turkey > Canakkale Province > Canakkale (0.41)
- Phanerozoic > Cenozoic > Paleogene (0.67)
- Phanerozoic > Cenozoic > Neogene > Miocene (0.47)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (1.00)
- Geology > Petroleum Play Type (1.00)
- Geology > Geological Subdiscipline (1.00)
- Europe > Bosnia and Herzegovina > Tuzla Canton > Tuzla Basin > Tuzla Field (0.99)
- Asia > Thailand > Gulf of Thailand > Western Basin (0.91)
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...)
Drill-In Fluid Optimization for Formation Damage Control Considering Salt Dissolution in Saline-Lacustrine Reservoirs
Tan, Qigui (School of Petroleum and Natural Gas Engineering, Changzhou University (Corresponding author)) | Yang, Bin (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Chengdu University of Technology (Corresponding author)) | You, Lijun (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Kang, Yili (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Peng, Haoping (School of Petroleum and Natural Gas Engineering, Changzhou University) | Song, Fuquan (School of Petroleum and Natural Gas Engineering, Changzhou University) | Lin, Chong (CCDC Drilling & Production Technology Research Institute)
Summary Salt dissolution induced by drill-in fluid loss is a frequent occurrence in saline-lacustrine reservoirs, which can potentially result in serious formation damage. In light of this, an experimental study was conducted to investigate the salt mineral dissolution and dynamic damage in the rock samples collected from a saline-lacustrine carbonate reservoir and the response of pore-fracture structures using the in-situ drill-in fluids. The study further involved analyzing the formation-damage-control (FDC) ability of the in-situ drill-in fluids. The results indicated that although salt dissolution significantly increased the pore size of the tight matrix and the width of natural fractures, improving the conductivity of seepage channels, the increase in pore-fracture size may have greatly aggravated the drill-in fluid loss during the process. The continuous serious filtrate loss, lower pressure-bearing capacity of the plugging zone, and lower permeability recovery rate (PRR) of rock indicated poor FDC performance of in-situ brine drilling fluids for the salt-dissolved core samples. The FDC performance of drill-in fluids for saline-lacustrine carbonate reservoirs was optimized based on the response of reservoir pore-fracture structure to salt dissolution and the theory of slightly underbalanced activity. The experimental results showed that the optimized drill-in fluids had better FDC ability, with an average PRR increase of 14.04%. Field application indicated that the optimized drill-in fluids reduced the drill-in fluid loss by 76.48%, shortened the drilling cycle by 45.20%, and increased the initial production capacity per well by 7.70%. This study can provide insightful guidance to optimize the FDC performance of drill-in fluids for saline-lacustrine hydrocarbon reservoirs during drilling.
- Asia > China (1.00)
- Asia > Middle East > Iraq (0.28)
- North America > United States > Texas (0.28)
- Research Report > New Finding (0.86)
- Research Report > Experimental Study (0.66)
- Geology > Sedimentary Geology > Depositional Environment > Continental Environment > Lacustrine Environment (1.00)
- Geology > Mineral > Halide > Halite (1.00)
- Asia > Pakistan > Missan Field (0.99)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin (0.99)
- Asia > China > Qinghai > Qaidam Basin (0.99)
- (8 more...)
Application of Proxy Model and Reservoir Simulation for CO2 Injection Optimization in Multi-Layer Depleted Reservoirs: A Case Study of CCS Project in Gulf of Thailand
Tripoppoom, Sutthaporn (PTTEP) | Doungprasertsuk, Chonlada (PTTEP) | Pongthunya, Potcharaporn (PTTEP) | Prasertbordeekul, Taweewat (PTTEP)
Abstract PTTEP has committed to achieve net zero greenhouse gas emission in 2050 and the CCS project in the gulf of Thailand is the first CCS planned by PTTEP to achieve this goal. To evaluate the feasibility of the project, the reservoir simulation study was extensively performed from the geological, petrophysical, seismic inversion and reservoir engineering input. One of the keys in CCS project is the CO2 injection strategy and CO2 storage volume. Therefore, the objective of the study is to determine the optimized injection strategy and storage volume for CO2. Normally, the CO2 injector locations were targeted at the high permeability-thickness (KH) location based on reservoir simulation model. However, the optimization of injection with many layers in depleted reservoirs is cumbersome and required up to millions of simulation runs which is not possible to be performed. Therefore, this study proposes the new workflow to optimize the injection strategy by integrating reservoir simulation and proxy model or surrogate model simplified from actual simulation model results as pre-screening. First, we identify well location candidates based on KH map, pressure and shale thickness. Then, we construct the creaming curves scenario from reservoir simulation model and input them to train proxy model. With this workflow, instead of evaluating millions of injection scenarios by reservoir simulation, consisting of which well location and which reservoirs to be injected as separate target or commingle, we instead optimized the time required to obtain the injection strategy firstly from proxy model as pre-screening. Then, we run these possible optimized scenarios from proxy model to be run with reservoir simulation model. Finally, we obtain the most optimized injection strategy from simulation model including selected injector locations, number of injectors and sand targets for each injector. This can be obtained by evaluating the cumulative CO2 injection volume per number of injectors. To conclude, the optimized scenario of CO2 injection strategy and volume were determined and ready to be coupled with the integrated model including geomechanics, geochemistry and thermal simulation. With the proposed workflow, the study is the first CCS project in Thailand that adopts the injection strategy optimization based on the integration of dynamic reservoir simulation and proxy model. The proposed workflow can be used as the practical and robust injection optimization workflow used in any future CCS project in depleted reservoirs with multi-layers.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.49)
- Geology > Geological Subdiscipline > Geomechanics (0.49)
- Geology > Geological Subdiscipline > Geochemistry (0.49)
Characterization of Reservoir Properties Calibrating with Production Data for Carbon Capture and Storage in the Depleted Gas Reservoirs - An Integrated Assisted History Matching Approach for Reservoir Simulation
Tripoppoom, Sutthaporn (PTTEP) | Doungprasertsuk, Chonlada (PTTEP) | Pongthunya, Potcharaporn (PTTEP) | Prasertbordeekul, Taweewat (PTTEP)
Abstract One of a key responsibility for oil and gas industry is to ensure the balance between energy sustainability and minimizing the net carbon footprint to the environment. PTTEP, Thai national oil and gas company, has aligned this goal to achieve net zero greenhouse gas emission in 2050. Therefore, the scope of this project is to utilize carbon capture and storage (CCS) technology by injecting CO2 into the depleted reservoirs in the Gulf of Thailand. To evaluate the feasibility of the project, the simulation model was required to mimic the physics behaviors, including free gas structural storage, residual trapping, soluble gas in water and mineralization, when the CO2 was injected into many layers of depleted reservoirs. This is to obtain the optimized scenario for CO2 injection. However, the key step for reservoir simulation is the history matching by calibrating the model with production data. First, the static model was built by integrating geological understanding, well data, logging data and petrophysical interpretation, core data, and quantitative interpretation (QI) from seismic data. Then, the subsurface uncertainties were captured and transferred to dynamic model for history matching step. The sensitivity analysis was performed to understand causes and effects and determine the significant uncertain parameters. Then, the assisted history matching was performed to explore the possible solutions using evolutionary algorithm. Lastly, multiple realizations of history matching solutions were obtained. From sensitivity analysis, the key parameters to be calibrated with production data and routine shut-in bottomhole surveys are gas-water contacts, porosity and permeability correlation and relative permeability endpoint parameters. From history matching solutions, we narrowed down the range of uncertainty of uncertain parameters during history matching. The pressure, gas and water production could be matched. Obtaining the calibrated model from history matching is the critical step because this will determine the feasibility of the project in terms of injection strategy and CO2 storage volume. This study was the first history matching task performed for Thailand CCS project. The practical and robust history matching workflow used in this CCS project could be set as a milestone and provides the guideline how to implement assisted history matching technique for any future CCS projects.
- Geophysics > Borehole Geophysics (0.69)
- Geophysics > Seismic Surveying (0.54)
Streamlining Information Retrieval Using a Chatbot Application
Sittipolkul, N. (PTT Exploration and Production Company Limited, Bangkok, Thailand) | Wanwilairat, S. (PTT Exploration and Production Company Limited, Bangkok, Thailand) | Sujijintararat, K. (PTT Exploration and Production Company Limited, Bangkok, Thailand)
Abstract Objective Wellhead Platform Department has engineered and installed more than 100 remote wellhead platforms (WHP) and pipelines for the past decades. Information of each different design WHP is kept in shared folder in case later generations have to modify/maintenance WHP. However, with hundreds of documents per each WHP, sometimes it takes more than hours to find all the required information. Thus, our team developed Chatbot to help find information to respond to repetitive and time-consuming questions. Method and Procedure Utilization of chatbot has garnered popularity over the recent year. With that opportunity, information finding could be easier by adopting this technology to develop in-house chatbot application. The database scope covers offshore WHP and intra-field pipelines. Google Dialogflow was used as a natural language processor from queries made via Microsoft Teams. As for backend service, python scripts and BigQuery were used to convert data to an appropriate database format and gather information from pre-populated Excel files to respond to fulfilment requests from Dialogflow. The conversation history and users tracking were available in web base for the purpose of training chatbot. Results, Observation and Conclusions By employing the in-house chatbot application, the results from web-based historical conversation data showed that this chatbot application effectively cut down the time wellhead platforms engineers spent on looking up for information and respond to routine questions, which in turn allows the engineers to focus on more critical tasks. Moreover, instead of having to ask for information from wellhead platform team, users can reach out to information and document through chatbot application 24/7. However, current problems mostly lie with the engineers still having to manually creating a data set in a format that backend services can recognize and make use of. Nevertheless, using the chatbot is an efficient mean to handle tedious inquiries which improves inquiry workflow and eventually saves valuable time and resources. Novel This paper presents a novel information by demonstrating the use of a chatbot in oil and gas industry which can be extended to any other field, given that the database is readily available in a format acceptable to the programs. The application was developed by Engineering team of Wellhead Platform Department (EWP) together with Data Scientist and Data Architecture of Digital Solution Development Section.
- Asia > Thailand (0.69)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean (0.25)
Abstract The American Petroleum Institute (API) and the U.S. oil and natural gas industry prioritize protecting the health and safety of workers, contractors, and the communities in which we operate. For more the 100 years, API has led the development of industry standards, sharing lessons learned as well as the establishment of training and certification programs, all available worldwide. The Process Site Assessment Program (PSSAPยฎ) is a not-for-profit industry assessment program managed by API, focused on sites that refine or process hydrocarbons, that has conducted assessments around the world to help mature process safety programs for over a decade. In the past few years, several sites have been returning to API to have repeated assessments conducted at their sites, presenting a unique opportunity to benchmark their progress toward implementation of the 600+ General PSSAP requirements. In PSSAP Assessments, independent expert assessors review a siteโs process safety management system and implementation in the field. The assessors score each of 600+ requirements contained in the assessment protocols, creating benchmarking scores for that site. Upon completion, the site receives a benchmarking report that compares their PSSAP scores with other sites who have participated in the program. Benchmarking provides a unique opportunity to quantify the maturity of process safety programs and to compare them, in addition to measuring improvement since a siteโs previous assessment. Scores on a section-by-section basis as well as overall performance have been analyzed to determine the amount of improvement as well as the likelihood of improvement, taking these eleven (11) sites as a representative sample. Of the eleven (11) sites who have repeated a PSSAP General Assessment (of 175+ assessments total), the average time between assessments is 4.8 years, with an average improvement in scoring of 2.1%. Of those sites, only one (1) site saw a scoring decrease, and this was after nine (9) years between assessments. Removing this site, the statistics shift to the average time between assessments being 4.4 years, with an average improvement in scoring of 3.7%. In context, this may not seem like a large increase, but considering the time necessary to implement these programs, this is no small feat. API is encouraged by these results and is setting up more repeat assessments. API has also discussed these findings with industry to determine the largest factors in whether a site is likely to improve in scoring on a repeated assessment. Critically, a site must have support from senior leadership that the assessmentโs results should be acted upon. Additionally, a siteโs culture and embracing of continuous improvement is the other most important aspect in determining if a site stands to benefit from a repeated assessment. PSSAP also supports the API Energy Excellenceยฎ Program, a program that helps operators implement overarching management systems through thirteen (13) elements in support of operational excellence across all segments of operations. There are few, if any, published guidance documents on a management system framework that can be applied to all segments.
- Europe (0.94)
- North America > United States (0.66)
- Asia > Middle East (0.47)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)
- Europe > Netherlands (0.89)
- Asia > Thailand (0.89)
- Asia > South Korea (0.89)
Abstract Brownfield Cost Excellence is one of PTTEP digital transformation project; to resolve pain points of project cost estimation process for engineers. This project contains 2 development phases, 1 Phase (in 2022) is to provide the calculative features of cost estimator using autonomous parametrical techniques modelled by cost estimation relationships (CERs) of data with dependent variables by plotting the relationships of data on TIBCO Spotfire and using Natural Language Processing (NLP) such as IronPython and R-script to build up calculative features and shaping up Parametric equations of Major Equipment and key bulk material cost curves with prediction of residual. In 2023, 2 Phase project is focusing on development of cost estimation web-based application which have 6 modules to deliver Major Equipment cost, Bulk Material cost, Construction cost, Tariff cost, Allocation cost including Contingency cost. The calculative of Tariff cost (PTTEP engineer man-hour) is delivered by Machine Learning algorithms which developed by Multiple Regression Equations by joining of 3 different data sources (PTTEP TimeWrite, Project Tracking Information and historical transactions of project expense from SAP). The calculative of allocation cost (builds from historical transaction data of Helicopter/Vessel transportation gathering from legacy logistic system of PTTEP) is also delivered by Machine Learning algorithm developed by connecting of several data sources as similar as the development of Tariff algorithm. Lastly, the contingency cost is aiming to be developed further by collecting gaps between estimated project cost versus actual spending cost of project to diversify its distribution prior to statistically construct contingency algorithm based on each type of project. Ending results given from the cost estimation web-based application are readiness for budget preparation of engineering and construction project which is compiled to AACE estimate class III (Typical purpose of Brownfield cost excellence project is for preparing budget of engineering and construction project in the accuracy range of +30%/-20% in a proper manner).
- Government > Regional Government > Asia Government > Thailand Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Construction & Engineering (1.00)