recovery

Abstract The successful recovery of pressurized core samples from an unconventional HPHT reservoir is presented. Optimized methods and technologies such as implementation of Managed Pressure Drilling (MPD) technique as well as coring technology customization and adaptation are discussed. Results from offset wells are compared and a best practice method is described how to recover pressurized cores from the organic rich Najmah Kerogen in West Kuwait. A coring BHA was configured using a modified version of the LPC Core Barrel hence allowing for the first time to consider recovering pressurized core samples from a well with a very challenging operating envelope. Furthermore, the provided methodology ensures that well conditions are maintained to allow for a pressurized core recovery in most stable wellbore environment avoiding any unwanted subsurface problems. With three consecutive runs planned on for the pressurized coring using MPD each 10 ft., the results obtained showed a successful coring operation of which typical wellbore downhole issues were avoided with no loss time due to well ballooning, mud losses and well kicks. The successful coring operations as well as all subsequent on-site analysis procedures showed possibility to recover pressurized core samples from unconventional formations with high formation pressure in a safe and effective manner. Avoiding core damage due to petal-centerline fractures and disking is fundamental in quantifying natural fractures in this unconventional reservoir. This novelty approach of core barrel system modification and using MPD technique in acquiring the pressurized cores has made it possible to obtain representative near in-situ data to better reservoir interpretation and quantification of natural fractures. The method has a great potential to ensure high core recovery in high angle wells while delivering superior reservoir fluid and rock information which is not obtainable by other means.

OnePetro

doi: 10.2118/214638-MS

SPE

SPE-214638-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America (1.00)
Asia > Middle East > Kuwait (1.00)

Genre: Overview > Innovation (0.40)

Geologic Time: Phanerozoic > Mesozoic (0.46)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Government > Regional Government > Asia Government > Middle East Government > Kuwait Government (0.46)

Oilfield Places:

Asia > Middle East > Kuwait > Jafra Governorate > Arabian Basin > Widyan Basin > Kra' Almru Field (0.99)
Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Fields > Burgan Field > Wara Formation (0.99)
Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Fields > Burgan Field > Tayarat Formation (0.99)
(10 more...)

SPE Disciplines:

Well Drilling > Pressure Management > Managed pressure drilling (1.00)
Well Drilling > Drilling Operations > Coring, fishing (1.00)
Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
(2 more...)

Technology: Information Technology (0.68)

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Advance Milling and Cutting Structure Development and Implementation to Reduce Well Abandonment Cost for Major Operators

Khan, Muhammad Zafar (Wellbore Integrity Solutions, Houston, TX, USA) | Swadi, Shantanu (Wellbore Integrity Solutions, Houston, TX, USA) | Solorzano, Efrain (Wellbore Integrity Solutions, Houston, TX, USA)

OnePetroMay, 2023

Abstract Decommissioning of end-of-life wells is an essential operation in the lifecycle of a well and requires thorough planning and execution. The plug and abandonment of the wells contribute over 45% of the overall decommission costs and hence there is a clear mandate from the operators and service companies to offer new technologies and solutions to reduce the overall decommissioning costs. The service company has been working with several operators to provide casing cutting and casing milling operations. The aim is to provide the most efficient and cost-effective method to perform the plug and abandon operations for a given well especially in the casing removal and recovery operations which in turn provides rig time savings. Some of the major operations are involved in section milling the casing, removal of large casing conductors or triple casing cuts by the pipe cutter, and subsea wellhead removals. The service company has designed an advanced cutting structure technology to facilitate the milling and casing cutting operations and provide a reliable, durable, and efficient milling solution for well abandonment. The new cutting structure provides reduced cut times and/or a longer useful cutting life to cut large dual casing conductors such as 20″x30″ or 22″x36″ during the conductor recovery phase or the wellhead recovery phase. Similarly, the advanced cutting structure is designed to efficiently mill extended casing sections, especially for high grade casings with higher ROP and lower downtime (rate of penetration) during the milling operation. The development efforts started with an evaluation of the current cutter designs and shortcomings. After an assessment of the field performance and dull characteristics, it was evident that high shock and vibration loading during the downhole operation results in excessive and premature impact damage leading to sub-optimal cutter geometry for cutting steel. Likewise, bird-nesting of swarf was also a common source of NPT due to the interruptions in operations for breaking up and clearing the swarf periodically, before milling commenced again. Several competing concepts for insert shapes were considered and analyzed. Improving the edge strength was considered as a key attribute. As well as the ability to break-up swarf into smaller segments for efficient transportation. Modelling and simulation, and physical testing helped narrow down to a few concepts for full scale lab tests, and eventually to select the most promising concept for field tests. The new advanced cutting structure has been 100% successful in multiple challenging applications of casing cutting and milling operations in the North Sea and is being implemented in Middle East and Asia. Improvements in the conductor cutting time has resulted in record recovery of the subsea well heads. Likewise, for section milling applications – record ROPs and longer intervals have been achieved for high grade casing such as P110. The technology demonstrates how the material behaves in downhole cutting operation and what further development can be made to further enhanced the efficiency, reduce rig time and wells decommissioning cost.

OnePetro

doi: 10.2118/214584-MS

SPE

SPE-214584-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Europe > Netherlands > North Sea (0.35)
Europe > United Kingdom > North Sea (0.25)
Europe > Norway > North Sea (0.25)
Europe > Denmark > North Sea (0.25)

Genre: Overview > Innovation (0.34)

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

Oilfield Places:

Europe > United Kingdom > North Sea (0.89)
Europe > Norway > North Sea (0.89)
Europe > Netherlands > North Sea (0.89)
Europe > Denmark > North Sea (0.89)

SPE Disciplines:

Production and Well Operations > Well Decommissioning (1.00)
Well Drilling > Casing and Cementing > Casing design (0.69)
Well Drilling > Wellhead Design > Subsea wellheads (0.55)

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Contribution of Wettability Alteration to Imbibition Oil Recovery in Low and High Permeability Conditions

Deng, Xiao (Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Kamal, Muhammad Shahzad (Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Patil, Shirish (Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Shakil, Syed Muhammad (Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Al Shehri, Dhafer (Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Zhou, Xianmin (Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Mahmoud, Mohamed (Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran, Saudi Arabia) | Al Shalabi, Emad Walid (Petroleum Engineering Department, Khalifa University, Abu Dhabi, United Arab Emirates)

OnePetroMay, 2023

Abstract Low permeability rock usually holds a large amount of residual oil after flooding. The two most important mechanisms for residual oil recovery are interfacial tension (IFT) reduction and wettability alteration (WA). There is confusion around the coupled effect between the two mechanisms. Permeability is found to be a critical factor on the coupled effect. In this study, the spontaneous imbibition oil recovery results from core plugs of different permeability by using two surfactants were compared. The comparison helps understand the impact of permeability on the coupled effect of IFT reduction and WA. Filtered crude oil (density 0.87 g/mL, viscosity 12.492 cP), Indiana limestone cores of different permeabilities, two locally synthesized cationic gemini surfactants, GS3 and GS6, were used in this study. The spinning drop method and static contact angle method were used to measure the oil/water IFT and the wettability. Spontaneous imbibition experiments using Amott cells were conducted at the ambient condition to relate IFT reduction and WA performance to the oil recovery contribution. Results showed that although the selected surfactants had comparable IFT reduction performance, GS3 is much stronger than GS6 in altering oil-wet carbonate rock to water-wet conditions. In core plugs with the same dimensions and comparable low permeabilities, the oil recovery values accorded with the WA performance. GS3 obtained faster and higher oil recovery (24%) than and GS6 (14%), indicating that enhancing WA alone contributes to oil recovery. The main difference between the selected surfactants was the spacer structure. It appeared that introducing unsaturation into the spacer group harmed the WA performance. Comparing different permeability conditions, GS6 obtained much higher oil recovery in a high permeability condition (922 mD) than in a low permeability condition (7.56 mD). Though permeability significantly impacted the whole imbibition process, it was more auspicious when IFT reduction became the main driving force. This study studied the WA mechanism alone by adopting surfactants with comparable oil/water IFT values. It also features the impact of permeability by comparing the recovery curve by the same surfactant under different permeability, showing that IFT reduction contributes more to oil recovery in high permeability rock.

OnePetro

doi: 10.2118/213045-MS

SPE

SPE-213045-MS

SPE Western Regional Meeting

asia government, carbonate reservoir, contribution, enhanced recovery, flow in porous media, Fluid Dynamics, gs3, gs6, IFT reduction, King Fahd University, Oil Recovery, permeability, recovery, recovery contribution, Saudi Arabia government, surfactant, united states government, Upstream Oil & Gas, wettability alteration

Country:

North America > United States > Indiana (0.24)
Asia > Middle East > Saudi Arabia (0.17)

Genre: Research Report > New Finding (1.00)

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

Oilfield Places:

North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
North America > United States > North Dakota > Williston Basin > Bakken Shale Formation (0.99)
North America > United States > Montana > Williston Basin > Bakken Shale Formation (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)

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The Impacts of Gas Adsorption on the Productivity of Marcellus Shale Horizontal Well

Bulule, Valcia (West Virginia University) | Sattari, Arya (West Virginia University) | Aminian, Kashy (West Virginia University) | El Sgher, Mohamed (West Virginia University) | Samuel, Ameri (West Virginia University)

OnePetroMay, 2023

Abstract The shale formations, in addition to the gas present in the pores of the rock, contain gas in the adsorbed state in the organic matter within the rock. As the pressure depletes in the reservoir the adsorbed gas is released and augments the gas production. In addition, gas desorption can potentially lead to permeability enhancement due to shale matrix shrinkage. At the same time, the pressure depletion increases the effective stress causing shale permeability and hydraulic fracture conductivity impairments. The purpose of this study was to investigate the impact of the gas desorption on the productivity of Marcellus shale horizontal well with multiple hydraulic fracture stages. The impacts of hydraulic fracture properties including half-length, conductivity, and stage spacing on gas desorption were also investigated. To investigate the impact of the gas desorption on gas production from Marcellus shale, a reservoir model for a horizontal well completed with multiple hydraulic fracture stages was used. The model has been developed based on the available information from several existing Marcellus shale horizontal wells in West Virginia. The laboratory and published data relative to adsorbed gas and the geomechanical factors were analyzed and geomechanical multipliers were generated and incorporated in the model. The geomechanical multipliers account for the impairments in hydraulic fracture conductivity and the reduction in the formation (matrix and fissure) permeability as well as the shale shrinkage caused by the reservoir depletion. The model was then utilized to investigate the impact of different parameters including Langmuir pressure and volume, fracture half-lengths, fracture spacings, and fracture conductivity on gas desorption and gas production. The inclusion of geomechanical multipliers provided more realistic production predictions and better understanding of the desorbed gas impact. The gas desorption was found to have a significant impact on the productivity during later stages of the production. This is contributed to pressure depletion required for desorption to become significant. The contribution of the desorbed gas to production increases as the fracture half-length increases and the fracture spacing decreases. Therefore, it can be concluded that desorption of gas depends on the stimulated reservoir volume.

OnePetro

doi: 10.2118/212999-MS

SPE

SPE-212999-MS

SPE Western Regional Meeting

Country:

North America > United States > West Virginia (1.00)
North America > United States > Virginia (1.00)
North America > United States > Pennsylvania (1.00)
(3 more...)

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

Oilfield Places:

North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
North America > United States > Tennessee > Appalachian Basin (0.99)
(14 more...)

SPE Disciplines:

Well Completion > Hydraulic Fracturing (1.00)
Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)

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Nanoparticles for the Transport of Fluids in Porous Media

OnePetroMay, 2023

Abstract Fluid transport can be improved by nanoparticles when they help stimulate a reservoir's rheological properties, which involve flow, viscosity, and permeability, among other parameters. First, this work reviews the literature regarding nanotechnology in the oil and gas sector. Then, it examines a few potential nanoparticle applications that have shown varying degrees of potential to improve colloid transport mechanisms in porous media. This list includes, but is not limited to, magnesium oxide, zinc oxide, silver, silicon dioxide, pyroelectric nanoparticles, and carbon nanotubes, all of which help stimulate a reservoir, which in turn leads to better fluid transport and an enhanced rate of recovery. The authors find that, compared to a baseline scenario that applies no nanotechnology, silicon dioxide, also known as silica, offers interesting advantages when used in laboratory settings. For example, in the case of low permeability limestones, silica helped transport fluids through the fractured rock at a better rate than without nanoparticles. Similarly, aluminum oxide shows the potential to improve rheological and filtration features inside a reservoir, stabilizing the flow of material from a well. Despite the high promise, however, it is still an early stage for field applications, where only a few trials for the use of nanoparticles have been experimented with, especially in porous media. Nanotechnology has become a favorite topic of research across many disciplines. This work is one of the first to offer a comprehensive look at the literature on nanoparticles in the oil and gas industry while also reviewing the applications of different ultrafine elements and their potential for future research endeavors in reservoir optimization and fluid transport in porous media.

OnePetro

doi: 10.2118/212996-MS

SPE

SPE-212996-MS

SPE Western Regional Meeting

Country:

North America > United States (0.28)
Asia > Middle East > Saudi Arabia (0.28)

Genre: Overview (0.46)

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

SPE Disciplines: Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)

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

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Comparative Machine Learning Frameworks for Forecasting CO2/CH4 Competitive Adsorption Ratios in Shale

Ma, Haoming (University of Calgary) | Yang, Yun (University of Calgary) | Xue, Zhenqian (University of Calgary) | Chen, Zhangxin (University of Calgary)

OnePetroMay, 2023

Abstract Accurate modeling of CO2/CH4 competitive adsorption behavior is a critical aspect of enhanced gas recovery associated with CO2 sequestration in organic-rich shales (CO2-ESGR). It not only improves the ultimate recovery of shale gas reservoirs that satisfies the increasing energy demand but also provides permanent geologic storage of atmospheric CO2 that contributes to the net-zero energy future. Determining a CO2/CH4 adsorption ratio is essential for the performance prediction of shale gas reservoirs and the evaluation of CO2 storage potential. However, experimental adsorption measurements are expensive and time-consuming that may not always be available for shale reservoirs of interest or at the investigated geologic conditions, and as a result, a sorption ratio cannot be assessed appropriately. Traditional models such as a Langmuir model are highly dependent on extensive experiments and cannot be widely applied. Therefore, a unified adsorption model must be developed to predict the CO2/CH4 competitive adsorption ratios, which is essential for CO2 sequestration and exploitation of natural gas from shale reservoirs. In recent years, the development of machine learning algorithms has significantly improved the accuracy and computational speed of prediction. In this work, we conducted a comparative machine learning algorithm study to effectively forecast the maximum CO2 adsorption capacity and CO2/CH4 competitive adsorption ratios. Four sensitive input parameters (i.e., temperature, total organic carbon, moisture content, and maximum adsorption capacity of CH4) were selected, along with their 50 data points collected from the existing literature. The artificial neural network (ANN), XGBoost, and Random Forest (RF) algorithms were investigated. By comparing the mean absolute errors (MAE) and coefficients of determination (R), it was found that the ANN models can successfully forecast the required outputs within a 10% accuracy level. Furthermore, the descriptive statistics demonstrated that the CO2/CH4 competitive adsorption ratios were generally from 1.7 to 5.6. The proposed machine learning algorithm framework will provide insights beyond the isothermal conditions of classical adsorption models and the solid support to CO2-ESGR processes into which competitive adsorption can be a driven mechanism.

OnePetro

doi: 10.2118/212994-MS

SPE

SPE-212994-MS

SPE Western Regional Meeting

Country: North America > United States (1.00)

Genre: Research Report > New Finding (0.48)

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

Oilfield Places:

North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
South America > Brazil > Brazil > South Atlantic Ocean (0.91)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)

Technology:

Information Technology > Artificial Intelligence > Machine Learning > Neural Networks (1.00)
Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning (0.91)
Information Technology > Artificial Intelligence > Machine Learning > Ensemble Learning (0.90)

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Petrobras Starts Up New FPSO in Campos Basin

Journal of Petroleum TechnologyMay, 2023

Petrobras started production from the floating production, storage, and offloading (FPSO) vessel Anna Nery on 7 May in the Campos Basin offshore Brazil. The Brazilian oil giant said on Monday that the unit is one of two FPSOs set to revitalize production of the Marlim, Voador, and Brava fields. Production from the Marlim and Voador fields is from post-salt reservoirs, while production from the Brava field is from the reservoir located in the pre-salt of the two fields, according to Petrobras. The FPSO Anna Nery can produce up to 70,000 B/D of oil and 4 million m3 of gas per day. The unit, chartered by Petrobras in 2019, was built in Cosco Changxing, China.

Journal of Petroleum Technology

anna nery, brazil government, Campos Basin, floating production storage & offloading, floating production storage and offloading, floating production system, FPSO, fpso anna nery, new fpso, Petrobras, petrobras start, recovery, reservoir, south america government, sub-sea system, Upstream Oil & Gas

Country: South America > Brazil > Rio de Janeiro > South Atlantic Ocean (0.27)

Industry:

Government > Regional Government > South America Government > Brazil Government (1.00)
Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

South America > Brazil > Campos Basin (0.99)
South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Marlim Field > Macae Formation (0.94)
South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Marlim Field > Lago Feia Formation (0.94)
South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Marlim Complex > Voador Field (0.94)

SPE Disciplines: Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Floating production systems (1.00)

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Vito Project: Vito Field Development

Sorgard, Eirik (Shell Exploration & Production Company) | Oko, Elizabeth Anne (Shell International Exploration & Production Inc) | Baird, John Isaac (Shell Exploration & Production Company) | Greenaway, Jason Alexander (Shell Exploration & Production Company) | Rabei, Rob Ibrahim (Shell Exploration & Production Company) | Pillai, Pradeep (Shell Exploration & Production Company) | Fresquez, Stacy Marie (Shell International Exploration & Production Inc)

OnePetroMay, 2023

Abstract The Vito field is located in 4,100 feet of water producing from reservoirs nearly 30,000 feet below sea level. Vito was discovered in 2009 approximately 135 miles southwest of New Orleans, Louisiana. The project underwent major field development strategy change to remain competitive in 2015 oil price environment and price resiliency going forward. The Vito project was seen as a strategic fit to the operator's existing Mars Corridor. The original Vito development strategy was to build a clone of the mega-project of Appomattox to maximize Net Present Value and Ultimate Recovery. However, as the market changed vastly in 2015, the project team refreshed the design concept to focus on capital efficiency. This paper provides an overview of the overall revised Field Development Concept of Vito. Vito has best in class resource density when compared to other Gulf of Mexico fields, which allows for a compact field development of 8 subsea wells at a single drill center. This allowed the project to not include a drilling rig on the host platform and instead deploy a new generation Deepwater rig for drilling and completions. There is severe depletion drilling risk on Vito which led the project to drill and complete all 8 wells prior to first oil. To improve ultimate recovery with low capital efficiency in well bore gas lift was included in the design. In addition, the Mars Corridor export system was looked at and required debottlenecking on both the oil and gas side. This paper is part of a Vito Project series at OTC 2023, and the other papers are listed in the references.

OnePetro

doi: 10.4043/32319-MS

OTC

OTC-32319-MS

Offshore Technology Conference

Country:

North America > United States > Gulf of Mexico > Central GOM (0.89)
North America > United States > Louisiana > Orleans Parish > New Orleans (0.24)

Genre: Overview (0.34)

Geophysics: Geophysics > Seismic Surveying (1.00)

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

Oilfield Places:

North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 984 > Vito Field (0.99)
North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 939 > Vito Field (0.99)
North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 943 > Power Nap Field (0.98)
(8 more...)

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Well Completion > Completion Selection and Design (1.00)
Well Completion > Completion Installation and Operations (1.00)
(5 more...)

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Influence of Hydrogen Sulfide on Adsorption Behavior of CO2/CH4 Mixtures in Calcite Nanopores with the Implications for CO2 Sequestration

Qian, Cheng (China University of Petroleum, Beijing) | Rui, Zhenhua (China University of Petroleum, Beijing) | Liu, Yueliang (China University of Petroleum, Beijing) | Zhao, Yang (China University of Petroleum, Beijing) | Li, Huazhou Andy (University of Alberta) | Ma, An (Moscow State University) | Afanasyev, Andrey (Moscow State University) | Torabi, Farshid (University of Regina)

OnePetroMay, 2023

Abstract Injecting CO2 into reservoirs for storage and enhanced oil recovery (EOR) is a practical and cost-effective strategy for achieving carbon neutrality. Commonly, CO2-rich industrial waste gas is employed as the CO2 source, whereas contaminants such as H2S may severely impact carbon storage and EOR via competitive adsorption. Hence, the adsorption behavior of CH4, CO2, and H2S in calcite (CaCO3) micropores and the impact of H2S on CO2 sequestration and methane recovery are specifically investigated using molecular simulation. The Grand Canonical Monte Carlo (GCMC) simulations were applied to study the adsorption characteristics of pure CO2, CH4, and H2S, and their multi-component mixtures are also investigated in calcite nanopores to reveal the impact of H2S on CO2 storage. The effect of pressure (0-20 MPa), temperature (293.15-383.15 K), pore width, buried depth and gas mole fraction on the adsorption behaviors are simulated. Molecular dynamics simulations (MD) were performed to explore the diffusion characteristics of the three gases and their mixes. The amount of adsorbed CH4, CO2, and H2S enhances with rising pressure and declines with rising temperature. The order of adsorption quantity in calcite nanopores is H2S>CO2>CH4, whereas the order of adsorption strength between the three gases and calcite is CO2>H2S>CH4 based on the interaction energy analysis. At 10 MPa and 3215 K, the interaction energies of calcite with CO2, H2S, and CH4 are -2166.40, -2076.93, and -174.57 kcal/mol, respectively. The CH4-calcite and H2S-calcite interaction energies are dominated by van der Waals energy, whereas electrostatic energy predominates in the CO2-calcite system. The adsorption loading of CH4 and CO2 are lowered by approximately 59.47% and 24.82% when the mole fraction of H2S is 20% at 323.15 K, reflecting the weakening of CH4 and CO2 adsorption by H2S due to competitive adsorption. The diffusivities of three pure gases in calcite nanopore are listed in the following order: CO2 > H2S > CH4. The presence of H2S in the ternary mixtures will limit diffusion and outflow of the system and each component gas, with CH4 being the gas most affected by H2S. The CO2/CH4 mixture can be buried in formations as shallow as 1000-1500 m, but the ternary mixture should be stored in deeper formations. The effects of H2S on CO2 sequestration and CH4 recovery in calcite nanopores are clarified, which provides theoretical assistance for CO2 storage and EOR projects in carbonate formation.

OnePetro

doi: 10.4043/32604-MS

OTC

OTC-32604-MS

Offshore Technology Conference

Country:

Asia > China (0.29)
North America > United States (0.28)

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

Oilfield Places: Asia > China > Sichuan > Sichuan Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics (1.00)
Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
Health, Safety, Environment & Sustainability > Health > Noise, chemicals, and other workplace hazards (1.00)

Technology: Information Technology (0.34)

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Building the Assurance Case for Recovery of Autonomous Underwater Vehicles from Offshore Platforms

Deeb, Amy (Lloyd's Register) | Garner, Toby (Lloyd's Register) | Kuchekar, Dipali (Lloyd's Register)

OnePetroMay, 2023

Abstract Digitalization was identified by the International Regulators’ Forum (IRF) as one of three key problems in 2021 due to the petroleum industry becoming increasingly reliant on automated systems. Autonomous underwater vehicles (AUVs) are of particular interest for inspection and maintenance of offshore platform infrastructure; however, the integration of such a complex system requires careful mitigation of safety health and environment risks associated with its operation. Analysis of human factors, including ergonomics, job organization, and cognitive considerations, has been recommended by the IRF to increase confidence that the interaction of the operators and the equipment (manually controlled, automated, or autonomous) permits safe delivery of the system capability in a safe working environment. The established CRitical Intervention and OPerability (CRIOP) analysis methodology is chosen as the basis for constructing an assurance case for an AUV control station on an offshore platform. CRIOP's goal is to show that the control center is able to safely manage all modes of operation. This paper proposes a CRIOP Assurance Case Template for a control station on an offshore platform. The proposed template uses goal structuring notation (GSN) with arguments, assumptions, and solutions, following the strategy of the CRIOP methodology. This template supports a critique of CRIOP's completeness arguments, goal-based structure, and solution acceptance criteria. Next, an assurance case for an AUV recovery operation is instantiated from the template for three cases with different autonomy levels: manual, automated with a human-in-the-loop, and autonomous. The increasing level of autonomy was shown to result in both technical and methodological variances to the assurance case including: layout changes as the control station moves from the open deck of a boat to a control room; changes in the acceptance criteria for the expertise of analysis team members; and the recommendation for additional scenarios that address situations in which the level of autonomy must be decreased due to safety concerns. Interviews with experienced AUV operators and developers revealed the value in including operators in the CRIOP analysis team to increase operator confidence in being able to maintain meaningful human control in all modes of operation. It is only with this confidence that autonomous systems will be used for the ambitious missions they can perform.

OnePetro

doi: 10.4043/32185-MS

OTC

OTC-32185-MS

Offshore Technology Conference

Country:

North America > United States (0.46)
North America > Canada > Ontario > Hamilton (0.28)

Genre: Instructional Material (0.46)

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

SPE Disciplines:

Health, Safety, Environment & Sustainability > Safety (1.00)
Data Science & Engineering Analytics > Information Management and Systems (1.00)
Health, Safety, Environment & Sustainability > Health > Ergonomics (0.71)
(2 more...)

Technology: Information Technology > Artificial Intelligence > Robots > Autonomous Vehicles (0.70)

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Collaborating Authors

New Methods for Cutting Pressure Retained Cores from Deep Unconventional Reservoirs in West Kuwait - First Ever Successful Pressure Coring Operation in the Najmah Kerogen

Advance Milling and Cutting Structure Development and Implementation to Reduce Well Abandonment Cost for Major Operators

Contribution of Wettability Alteration to Imbibition Oil Recovery in Low and High Permeability Conditions

The Impacts of Gas Adsorption on the Productivity of Marcellus Shale Horizontal Well

Nanoparticles for the Transport of Fluids in Porous Media

Comparative Machine Learning Frameworks for Forecasting CO2/CH4 Competitive Adsorption Ratios in Shale

Petrobras Starts Up New FPSO in Campos Basin

Vito Project: Vito Field Development

Influence of Hydrogen Sulfide on Adsorption Behavior of CO2/CH4 Mixtures in Calcite Nanopores with the Implications for CO2 Sequestration

Building the Assurance Case for Recovery of Autonomous Underwater Vehicles from Offshore Platforms

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