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Effect of Liquid-Liquid Subsea Separation on Production Forecast Considering Integration of a Deepwater Reservoir and Surface Facility Models

Bigdeli, Alireza (Universidade Estadual De Campinas) | von Hohendorff Filho, João Carlos (Universidade Estadual De Campinas) | Schiozer, Denis José (Universidade Estadual De Campinas)

OnePetroJune, 2023

Abstract In this work, we present a case study of the integration of surface facility models and a deepwater reservoir, as well as an engineering evaluation of the implications of liquid-liquid subsea separation (LLSS) on the integration process. For this, a heavy oil sandstone reservoir and several surface facility layouts were computationally integrated using a commercial simulator. A gathering unit, subsea separator, and water disposal unit were added to the surface facility model layouts to support the LLSS system. The term "merge scenario" was used to refer to the quantity of production streams that were gathered and delivered to the subsea separator. To allow the production from the reservoir model, the minimum bottom-hole pressure (BHP) for the producing wells were defined for all the simulations. Our investigation includes fluids produced at platforms, produced water at disposal unit, the pressure drop in the riser in terms of hydrostatic and friction terms, and economic analyses of these investigations. This case study shows that, depending on the merging situation, the reservoir needs 2 to 5 times more injection water than the separated water. Despite efforts to reduce the pressure restriction in the surface facility by increasing the riser diameter, the oil recovery did not change significantly when the number of merging wells was adjusted. This happened because the wellhead was not affected by the production system's pressure disturbance and the surface facility models’ boundary conditions remained unchanged. The economic calculations also indicated that the value of the technology (the highest acceptable price for the technology) for eleven merge scenario was 130 MMUSD and the OPEX and CAPEX can be lowered by 95 and 35 MMUSD (3% and 5% on average), respectively. This economic benefit was due to the lower cost of platform water handling from the produced water separation. In later stages of simulations, when the water cut surpasses 90%, hydrostatic pressure loss overtakes friction pressure loss as the primary contributor to overall pressure losses in the riser for 11 merge scenarios. These tests demonstrated that adding LLSS increases the complexity of the integration process and engineers can apply the engineering ideas of this study to other field designs in development. This work is the first case study of its kind that examines the relationship between the impact of LLS and the integration of a deep-water reservoir and surface facility model. This article's production forecast problem description can be utilized as a starting point to develop a general methodology for simulating complicated offshore production systems using LLSS operations.

OnePetro

doi: 10.2118/214455-MS

SPE

SPE-214455-MS

SPE EuropEC - Europe Energy Conference featured at the 84th EAGE Annual Conference & Exhibition

Country:

South America > Brazil (0.28)
Europe > Austria (0.28)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.49)

SPE Disciplines:

Reservoir Description and Dynamics > Fluid Characterization > Fluid modeling, equations of state (1.00)
Facilities Design, Construction and Operation > Processing Systems and Design > Process simulation (1.00)

Technology: Information Technology > Modeling & Simulation (1.00)

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Reservoir Fluid Typing from Standard Mud Gas - A Machine Learning Approach

Cely, Alexandra (Equinor ASA) | Siedlecki, Artur (SparkBeyond) | Liashenko, Artur (SparkBeyond) | Yang, Tao (Equinor ASA) | Donnadieu, Sandrine (Equinor ASA)

OnePetroJune, 2023

Abstract Standard mud gas data is part of the basic mudlogging service and is used mainly for safety monitoring. Although the data is available for all wells, it is not used for reservoir fluid typing due to poor prediction accuracy. We recently developed a new manual method and significantly improved the reservoir fluid typing accuracy from standard mud gas data. However, there is a strong business for an automatic method to enable reservoir fluid interpretation while drilling. A machine learning method has been developed based on a well-established standard mud gas database. The standard mud gas compositions contain methane, ethane, and propane components with reasonable quality measurements. The butane and pentane compositions in the standard mud gas are low and sometimes close to the detection limit. Therefore, we only use methane to propane compositions in the machine learning algorithm. It is particularly challenging to predict reservoir fluid type accurately based on only three gas components. Therefore, we introduce additional data sources to increase the prediction accuracy: a large in-house reservoir fluid database and petrophysical logs. The machine learning algorithm extracts critical reservoir fluid information specifically for a known field by utilizing the geospatial location and the existing reservoir fluid database. When combined with the standard mud gas database, the reservoir fluid typing accuracy increased from 50-60% to nearly 80%. Petrophysical logs are the main tool in the industry to identify the reservoir fluid type. When combining the petrophysical logs with the machine learning model already with satisfactory performance, the final reservoir fluid type prediction accuracy is about 80%. Given the difficulties of distinguishing oil or gas for near-critical fluids or volatile oil, the current prediction accuracy is sufficient for industry applications. The innovation created significant business opportunities based on the standard mud gas, which has been regarded as not applicable data for accurate reservoir fluid typing for many decades. The new method makes accurate reservoir fluid typing possible for real-time well decisions like well placement, completion, and sidetracking. In addition, the new method can add lots of value for well integrity, maturating production targets, and cost-efficient Plug and Abandonment (P&A) in the overburden.

OnePetro

doi: 10.2118/214341-MS

SPE

SPE-214341-MS

SPE EuropEC - Europe Energy Conference featured at the 84th EAGE Annual Conference & Exhibition

Country:

North America > United States (0.94)
North America > Canada > Alberta (0.28)

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

Oilfield Places:

North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 205 > Genesis Field > Neb Formation (0.99)
Africa > Angola > South Atlantic Ocean > Congo Basin (0.99)

SPE Disciplines:

Reservoir Description and Dynamics > Fluid Characterization > Fluid modeling, equations of state (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)

Technology: Information Technology > Artificial Intelligence > Machine Learning > Performance Analysis > Accuracy (1.00)

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Director's Blog

SPE WebsiteJune, 2023

They say, "Time slips through our hands like sand, reminding us to seize each moment and make it grand." Dear Industry Colleagues, as we stand at the midpoint of this remarkable year, let us take a moment to reflect on the incredible journey we have embarked on in the MENA region. The first half has been filled with noteworthy achievements that highlight our unwavering dedication, ingenuity, and collaborative spirit. These accomplishments have laid the foundation for an even more extraordinary second act. I take this opportunity to extend a warm welcome to Mr. Simon Seaton, the newly appointed SPE CEO.

SPE Website

Abu Dhabi, accomplishment, Adipec, asia government, blog, Director, hosted, innovation, oman government, platform, Saudi Arabia government, seaton, social responsibility, SPE, sustainability, sustainable development, Technology Conference, transformation, uae government, Upstream Oil & Gas

Country:

Asia > Middle East > UAE (0.75)
Asia > Middle East > Oman (0.55)
Asia > Middle East > Saudi Arabia (0.54)

Industry: Energy > Oil & Gas > Upstream (0.85)

SPE Disciplines: Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (0.50)

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Utilizing Remote Sensing and Data Analytics Techniques to Detect Methane Emissions from the Oil and Gas Industry and Assist with Sustainability Metrics

Esparza, Á. E. (GHGSat Inc. (Corresponding author)) | Ebbs, M. (GHGSat Inc.) | De Toro Eadie, N. (GHGSat Inc.) | Roffo, R. (GHGSat Inc.) | Monnington, L. (GHGSat Inc.)

OnePetroJune, 2023

Summary The purpose of this paper is to provide additional information and insights gained on manuscript SPE-209980-MS, accepted for presentation at the 2022 Society of Petroleum Engineers Annual Technical Conference and Exhibition (Esparza et al. 2022). The energy sector has been identified as one of the main contributors to emissions of anthropogenic greenhouse gases. Therefore, sustainability in the sector is mainly associated with the advancement in environmental and social performance across multiple industries. Individual firms, particularly those belonging to the oil and gas (O&G) industry, are now assessed for their environmental, social, and governance (ESG) performance and their impact on climate change. To meet the different key performance indicators (KPIs) for corporate social responsibility (CSR) and ESG, the planning, development, and operation of O&G infrastructure must be conducted in an environmentally responsible way. Today, operators calculate their own emissions, which are typically self-reported annually, usually relying on emission factors to complement the lack of emission measurement data. This paper discusses how methane detection of O&G infrastructure using remote sensing technologies enables operators to detect, quantify, and minimize methane emissions while gaining insights and understanding of their operations via data analytics products. The remote sensing technologies accounted for in this paper are satellite and aerial platforms operating in tandem with data analytics, providing a scheme to support sustainability initiatives through the quantification of some ESG metrics associated with methane emissions. This paper presents examples of measurements at O&G sites taken with satellites and aircraft platforms, providing evidence of methane emissions at the facility level. A discussion of each platform and how they work together is also presented. Additionally, this paper discusses how these data insights can be used to achieve sustainability goals, functioning as a tool for ESG initiatives through the incorporation of analytical models.

OnePetro

doi: 10.2118/215818-PA

SPE

SPE-215818-PA

SPE Production & Operations

Country: North America > United States > Texas (0.47)

Genre:

Research Report (1.00)
Public Relations > Community Relations (0.66)

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

Oilfield Places:

North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
North America > United States > Texas > Permian Basin > Yates Formation (0.99)
North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
(22 more...)

SPE Disciplines:

Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Social responsibility and development (1.00)
Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
Health, Safety, Environment & Sustainability > Environment > Air emissions (1.00)

Technology: Information Technology > Data Science (1.00)

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Hydraulic Fracturing Unlocks Potential of Europe's Largest Reservoir

Journal of Petroleum TechnologyJune, 2023

The Clair field is 75 km west of the Shetland Islands on the UK Continental Shelf within the extensional Faroe-Shetland Basin. The Old Red Sandstone reservoir is divided into two lithostratigraphic units, the Upper and LCG. The LCG contains the bulk of the oil in place and underpins the Clair development. The reservoir is characterized by large variations in facies and permeabilities. The LCG is subdivided into six units, I through VI, based on variations in sedimentary facies and heavy mineral assemblages. Development drilling preferentially targets the highest quality reservoirs in Units V and III. The LCG is defined as a dual-permeability system with a variable fracture distribution.

Journal of Petroleum Technology

complex reservoir, europe government, hydraulic fracturing unlock potential, largest reservoir, lcg, phase 1, platform, united kingdom government, Upstream Oil & Gas, variation

Country: Europe > United Kingdom > Scotland > Shetland (0.29)

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

Oilfield Places:

Europe > United Kingdom > Atlantic Margin > West of Shetland > Faroe-Shetland Basin > Rona Ridge > Block 206/9 > Clair Field (0.99)
Europe > United Kingdom > Atlantic Margin > West of Shetland > Faroe-Shetland Basin > Rona Ridge > Block 206/8 > Clair Field (0.99)
Europe > United Kingdom > Atlantic Margin > West of Shetland > Faroe-Shetland Basin > Rona Ridge > Block 206/7 > Clair Field (0.99)
(2 more...)

SPE Disciplines:

Well Completion > Hydraulic Fracturing (1.00)
Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (0.44)

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Offshore Decommissioning: Planning for the End at the Beginning

Journal of Petroleum TechnologyJune, 2023

It is the 100 billion elephant in the room. It is the last item on a never-ending list of things to do that gets delayed until it can no longer be deferred. It is the decommissioning of mature offshore oil and gas fields, and--like death and taxes--it is an unavoidable certainty. Decommissioning, the safe and environmentally sound removal, disposal, and repurposing of obsolete infrastructure, marks the end of a field's operational life cycle. A critical part of the process is the plugging and abandonment (P&A) of wells to ensure that hydrocarbons, other fluids, and gases do not escape the wellbore.

Journal of Petroleum Technology

Country: North America > United States (1.00)

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

SPE Disciplines:

Production and Well Operations (0.90)
Facilities Design, Construction and Operation > Facilities Decommissioning and Site Remediation > Offshore facility decommissioning (0.66)

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Producing Shale Oil Through Rod Free Artificial Lift, A Case Study

Chen, Qiang (RIPED, PetroChina Co. Ltd, Beijing, China) | Hao, Zhongxian (RIPED, PetroChina Co. Ltd, Beijing, China) | Huang, Shouzhi (RIPED, PetroChina Co. Ltd, Beijing, China) | Gao, Yang (RIPED, PetroChina Co. Ltd, Beijing, China) | Wei, Songbo (RIPED, PetroChina Co. Ltd, Beijing, China)

OnePetroMay, 2023

Shale oil had attracted worldwide attention due to its vast volume, according to statistics, technical recovery of shale oil worldwide exceeded 250billion ton, mostly located in America, Africa and north Asia. However shale oil was characterized by its high viscosity, deep reservoir location, posing threats to the operator, traditional rod-pump artificial lift was not a good choice due to the friction issue, How to walk out of those challenges were worth thinking, while rod free artificial lift methods had been field proven in the oilfield, its progress would give us some inspirations. In this paper, rod free artificial lift methods including downhole motivated reciprocating pump, centrifugal pump and progressing cavity pump were discussed, some technological highlights such as pulling and running electric cables, host SCADA system and production control algorism had been introduced in detail. Finally the efficacy of rodless artificial lift was analyzed from the perspective of investment

OnePetro

doi: 10.2118/214564-MS

SPE

SPE-214564-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > United States (0.69)
Asia > China (0.48)

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

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
Production and Well Operations > Artificial Lift Systems > Progressing cavity pumps (1.00)
Production and Well Operations > Artificial Lift Systems > Beam and related pumping techniques (1.00)

Technology:

Information Technology > Sensing and Signal Processing (0.88)
Information Technology > Communications > Networks > Sensor Networks (0.70)

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Cost-Effective Development Mode for Marginal Oil fields – Best Practice of CNPC

Wu, Bohong (Research Institute of Petroleum Exploration & Development, PetroChina) | Nie, Zhen (Research Institute of Petroleum Exploration & Development, PetroChina) | Li, Yong (Research Institute of Petroleum Exploration & Development, PetroChina) | Deng, Xili (Research Institute of Petroleum Exploration & Development, PetroChina) | Ma, Ruicheng (Research Institute of Petroleum Exploration & Development, PetroChina) | Xu, Jiacheng (Research Institute of Petroleum Exploration & Development, PetroChina)

OnePetroMay, 2023

Abstract Marginal reserves are an important play in future energy development. Based on the statistics of China National Petroleum Corporation (CNPC), the low permeability and unconventional reservoirs occupied 92% of newly found proven reserves in China. To overcome challenges such as poor reservoir conditions, weak natural energy, low displacement efficiency, and insufficient single well production, CNPC has conducted years of research and operation to cost-effectively develop China's marginal reserves. To develop the marginal fields economically, it is required to maximize single well production, recovery and reservoir sweep with minimum CAPEX and OPEX reasonably. The production enhancement is realized by 3 key technologies, namely, sweet spot identification, multi-layered 3D short spacing horizontal well pattern, and volumetric fracturing techniques. The cost reduction is achieved by the full life cycle practice of utilizing "large cluster, factory" well design and field operation, drilling prognosis optimization, integrated intelligent surface system, and unmanned operation. CNPC cost-effective development mode is practical and successful, marginal fields characterized with heterogeneous, multi-layered oil-bearing intervals with poor continuity are being economically developed in China. By comprehensive geological study, fit-for-purpose technologies application, and geoscience-to-engineering integration, the fracture control degree of horizontal wells increased from 60% to more than 90% based on micro-seismic events, stimulated reservoir volume (SRV) increased by 46.8%, average cumulative oil production per well is more than 100 times than original production in the field. Fast and early cash flow is realized by minimum production facilities. The average drilling cycle is shortened by 61%, the surface facility construction time is reduced by 65%, and the average single well investment is reduced by 42%.

OnePetro

doi: 10.2118/214643-MS

SPE

SPE-214643-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Asia > China (1.00)
North America > United States > Texas (0.47)

Geophysics: Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.87)

Industry:

Government > Regional Government > Asia Government > China Government (1.00)
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)
(2 more...)

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Completion > Hydraulic Fracturing (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
(4 more...)

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Cloud-Based Data Integration Between Geology & Drilling Software Using Python Tools

Mwansa, P. (ADNOC Onshore, Abu Dhabi, United Arab Emirates) | Hernandez, B. C. H. R. (CEGAL, Stavanger, Norway) | Grebe, S. (CEGAL, Stavanger, Norway) | Hassan, M. A. (OLIASOFT AS, Oslo, Norway) | Torsæter, A. (OLIASOFT AS, Oslo, Norway) | Jenssen, F. (OLIASOFT AS, Oslo, Norway)

OnePetroMay, 2023

Abstract The oil and gas industry generates vast amounts of data throughout its operations, from exploration to production. Collecting, connecting, and optimally utilizing this data is key to maximizing efficiency, accuracy, and access to new disruptive technologies. In a typical well-planning cycle, an engineer will spend significant amount of time looking for the data they require to do their jobs efficiently. The data are typically locked away in silos - trajectories in one data platform, Pore Pressure Gradient, Fracture Gradient or Targets in another, and so on. A major Middle Eastern NOC and Two Norwegian software service companies teamed up to develop Proof of Concept (PoC) for a new workflow that integrates subsurface and drilling data between on-premises Geology E&P software and Drilling software through a proprietary Python Tool plug-in and Python library. This integration enables a streamlined connection to a cloud-based drilling and well planning software, facilitating collaboration among teams involved in well planning. The project's key challenges are the lack of a standardized communication, integration, and automation of data flows between subsurface and drilling teams, as well as the inability of engineers to access necessary data due to scattered information and access restrictions. The project utilizes a proprietary data science suite, named Cegal's Prizm, which allows easy configuration to integrate data from various applications, sources, and platforms. A proprietary Python Tool is used to merge data from various application silos and data sources, enabling enriched investigation. The process involves connecting to the Geology E&P software retrieving domain objects using the proprietary Python Tool, and converting these domain data objects into common Python data structures. The project aims to develop an innovative workflow that provides easier access to data for experts throughout the organization, leading to better decision-making during the well-planning cycle. This not only makes it easier, but it also ensures collaboration between the G&G and Drilling teams involved in new well planning

OnePetro

doi: 10.2118/214593-MS

SPE

SPE-214593-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Europe > Norway (0.47)
Asia > Middle East > UAE (0.47)

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

SPE Disciplines:

Health, Safety, Environment & Sustainability > Security > Data and communications security (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Data security (0.95)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (0.88)
(2 more...)

Technology:

Information Technology > Software > Programming Languages (1.00)
Information Technology > Security & Privacy (1.00)
Information Technology > Data Science (1.00)
(3 more...)

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How to Comply Ai Generated Data with Wells Hse Performance Procedures and Requirement in Practice

Shirkhorshidi, R. (Rhyton, Frankfurt, Germany) | Norazman, N. (Petronas, Kuala Lumpur, Malaysia) | Rosli, M. B. (Petronas, Kuala Lumpur, Malaysia) | Arriffin, M. (Petronas, Kuala Lumpur, Malaysia) | Karbasian, M. (Rhyton, Frankfurt, Germany)

OnePetroMay, 2023

In recent years, many companies have deployed AI-based monitoring systems to detect unsafe act and conditions on industrial setups in real time. Although such technology has proven its capability, the industry hasn't shown a rush toward its usage as what we experienced on (e.g., ChatGPT). This fact shows that using AI integration into closed circuit television (CCTV) cameras alone is not enough to maximize such technologies in industrial setups and processes despite their huge development. An offshore drilling rig has an extremely harsh working environment, which involves people of a wide variety of professions and cultures. Therefore, any solutions that aim to mitigate risks there must engage all sectors and stockholders, be based on existing culture and comply with current procedures on rigs. This is neither an easy nor an impossible mission. 2 SPE/IADC-214598-MS A key objective of this practice was to build an AI-based platform that would not only benefit end users in various levels and prove the technology capability, but also deliver values. Therefore, to create the most efficient AI-based platform for everyone, cutting-edge noise reduction technology, risk assessments, and technology capabilities were aligned with existing safety procedures, reporting systems, and management cultures. Together with the openness and trust of the rig crew, particularly the HSE department and management, a unique intelligent platform was created that can improve safety teamwork, empower decision-makers, and increase efficiency.

OnePetro

doi: 10.2118/214598-MS

SPE

SPE-214598-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition