North Sea

Flow-Through Experiments of Reactive Ba-Sr-Mg Brines in Mons Chalk at North Sea Reservoir Temperature at Different Injection Rates

Andersen, Pål Østebø (Department of Energy Resources, University of Stavanger, Norway) | Herlofsen, Sander Sunde (Department of Energy Resources, University of Stavanger, Norway) | Korsnes, Reidar Inge (Department of Energy and Petroleum Engineering, University of Stavanger, Stavanger, Norway) | Minde, Mona Wetrhus (Department of Mechanical and Structural Engineering and Materials Science, University of Stavanger, Stavanger, Norway)

OnePetroJune, 2023

Abstract Chalk reservoirs in the North Sea of Norway contain significant amounts remaining oil and gas, and are potential candidates for enhanced recovery by modifying the injected brine composition. This work investigates how brines with divalent cations Ba, Sr and Mg interact when injected into chalk (CaCO3). Ba and Sr are often associated with mineral precipitation and occur in formation water while Mg is present in seawater, commonly injected in chalk. Relatively clean (>99% calcite) outcrop chalk cores from Mons, Belgium, were flooded at 130 °C in triaxial cells with four brines containing 0.12 mol/L divalent cations: either 0.06 mol/L Sr and Ba, 0.06 mol/L Sr and Mg, or 0.12 mol/L Ba or Sr. Each brine was injected in a separate core, with 100 to 150 pore volumes. The injection rate was varied between 0.5 and 8 pore volumes per day. Produced brine was analyzed continuously and compared with the injected brine composition. After flooding, the cores flooded with only Ba or only Sr were cut into slices and analyzed locally in terms of Scanning Electron Microscopy (SEM), matrix density, specific surface area and X-Ray diffraction. In all experiments, the produced divalent cation concentration was reduced compared to the injected value. The total reduction of injected cation concentration closely equaled the produced Ca concentration (from calcite dissolution). When flooding 0.12 mol/L Sr, the Sr concentration depleted 50%, while when flooding 0.12 mol/L Ba, 10% Ba depleted. When injecting equal concentrations of Ba and Sr, 40% Sr and 7% Ba depleted, while with equal concentrations of Mg and Sr injected, ~50% Sr was retained and almost no Mg depleted. Sr appeared to dominate and suppress other reactions. There was little sensitivity in steady state concentrations with variation in injection rate. The similar modification of the brine regardless of residence time suggests the reactions reached equilibrium. Cutting the cores revealed a visually clear front a few cm from the inlet. The material past the front was indistinguishable from unflooded chalk in terms of density, specific surface area, micro scale structure, porosity and composition (XRD and SEM-EDS). The material near the inlet was clearly altered. Images, XRD, SEM-EDS and geochemical simulations indicated that BaCO3 and SrCO3 formed during BaCl2- and SrCl2-flooding, respectively. The simulations also predicted equal exchange of cations to occur. The matrix densities, porosities and the distance traveled by the front corresponded with these minerals and suggested that the chalk was completely converted to these minerals behind the front. It was demonstrated that Ba-, Sr-, Mg-brines and their mixtures can be highly reactive in chalk without clogging the core after tens of pore volumes. This is because precipitation of minerals bearing these ions associates with simultaneous dissolution of calcite. The Ca-, Ba-, Sr-mineral reactions are effectively in equilibrium. Previous investigations with MgCl2 show rate dependent results and smoother alterations, indicating that Mg-mineral reactions at same conditions have longer time scale.

OnePetro

doi: 10.2118/214367-MS

SPE

SPE-214367-MS

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

Country:

Europe > Norway > North Sea (0.70)
Europe > United Kingdom > North Sea (0.60)
Europe > Netherlands > North Sea (0.60)
Europe > Denmark > North Sea (0.60)

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

Oilfield Places:

Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Block 2/4 > Greater Ekofisk Field > Ekofisk Field > Tor Formation (0.99)
Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Block 2/4 > Greater Ekofisk Field > Ekofisk Field > Ekofisk Formation (0.99)
Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Block 2/7 > Greater Ekofisk Field > Eldfisk Field > Tor Formation (0.98)
(2 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)

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Viscoplastic Deformation During CO2 Storage in Danish Chalk Reservoirs: Role of Petrophysical Heterogeneity and Mechanical Alteration

Amour, Frédéric (DTU Offshore) | Hosseinzadehsadati, Seyedbehzad (DTU Offshore) | Nick, Hamidreza M. (DTU Offshore)

OnePetroJune, 2023

Abstract Denmark aims at a 70% reduction in greenhouse gas emissions by 2030 compared to levels measured in 1990, with a long-term target of becoming carbon-neutral by 2050. As part of this national effort, the Bifrost project, aims at repurposing two depleted gas fields in the Danish North Sea for CO2 storage, namely the Harald West sandstone field as the primary target and the neighboring Harald East chalk field as a potential upside. The Harald East chalk is the focus of this study. The storage potential and infrastructures available within the multiple chalk fields located in the Danish North Sea represent valuable assets to fulfill the national objectives enabling a time- and cost-efficient implementation of carbon storage activities. One of the main challenges for carbon storage in chalk is the contradictory experimental results reported in literature that indicate both a strengthening and a softening effect of supercritical CO2 on the plastic and elastic properties of chalk. Such uncertainty hampers accurate prediction of the deformation response of storage sites. In this context, the study aims at assessing the impacts of two levels of uncertainty; the type of mechanical alteration induced by supercritical CO2 and the petrophysical heterogeneity on the long-term deformation behaviour of chalk reservoirs. An in-house hydro-mechanical-chemical model calibrated against experimental data on chalk is applied in a reservoir model of the Harald East field. A 16 year-long injection period is simulated assuming two scenarios. In scenario 1, supercritical CO2 has no impact on the mechanical properties of the rock, whereas in scenario 2, a 30% and 25% lowering of the pore collapse stress and elastic modulus of chalk is assumed. A systematic comparison of the flow and mechanical behaviour of low and high porosity cells located in the vicinity of an injection well indicates that the impact of CO2 on the mechanical properties of chalk, the distance of the cells from the injector, the local stress redistribution taking place in the reservoir between mechanically soft and strong cells, and the presence of natural gas in pore space before CO2 injection are key factors controlling the amount and distribution of plastic deformation occurring in the storage site. The outcome of this work enables quantifying the main risks associated with rock compaction close to and further away from injectors during and after carbon storage in chalk fields.

OnePetro

doi: 10.2118/214399-MS

SPE

SPE-214399-MS

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

Country: Europe > Denmark > North Sea (1.00)

Genre: Research Report (0.69)

Geophysics: Geophysics > Seismic Surveying (0.46)

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

Oilfield Places:

Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Tor Formation (0.99)
Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Hod Formation (0.99)
Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/11 > Valhall Field > Tor Formation (0.99)
(15 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)

Technology: Information Technology (0.68)

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2H Launches Second Phase of Measurement-Based Wellhead Fatigue JIP

Journal of Petroleum TechnologyMay, 2023

Advanced systems engineering firm 2H has launched the second phase of its Measurement-Based Wellhead Fatigue joint industry project (JIP), which aims to improve riser, wellhead, and conductor fatigue estimates and make drilling operations more reliable and efficient. In Phase 1 of the project, 2H collaborated with nine major operators to gather and analyze field measurements from 10 drilling campaigns in the Gulf of Mexico and the North Sea. The data covered a range of environments, water depths, soil characteristics, riser and wellhead configurations, and vessel types. Findings from the analysis verified that industry assumptions for wave and vortex-induced vibration (VIV) fatigue assessments are conservative and remaining fatigue life tends to be higher than that determined by typical design methods. A more accurate prediction of remaining fatigue life can eliminate the need for costly mitigation methods or unnecessary upgrades and downtime during severe events.

Journal of Petroleum Technology

accuracy, Completion Installation and Operations, denmark government, drilling operation management, europe government, measurement-based wellhead fatigue jip, mexico government, netherlands government, norway government, operator, phase 1, riser, united kingdom government, united states government, Upstream Oil & Gas

Country:

North America > United States (0.27)
North America > Mexico (0.27)
Europe > United Kingdom > North Sea (0.27)
(4 more...)

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:

Well Completion > Completion Installation and Operations (1.00)
Well Drilling > Drilling Operations > Drilling operation management (0.39)

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A Holistic Approach to Consider for Slot Recovery Based on a Failure Incident in North Sea Operations

Ioan, T. (D&I, SLB, AL Khobar, Saudi Arabia) | Bull, R. L. (D&I, SLB, Rio de Janeiro, Brazil)

OnePetroMay, 2023

Abstract An oilfield service company was awarded the scope by an operator in the North Sea to recover three slots from an existing offshore platform and redrill the HPHT wells to tap into unreached reservoir resources on a gas field. This paper covers the holistic approach of analysing the slot recovery operations strategy, plug and abandon the original wellbore, and how to avoid tunnel vision in the decision-making process to achieve the goals. Cut and pull operations have one of the highest financial impacts on slot recovery and can lead to loss of the well in unfortunate circumstances. After slot recovery operations, including the cutting and milling of the 10-3/4″ × 10″ casing, the 13-3/8″ casing failed the pressure test. The incident triggered a Cause Analysis Tree Diagram of the well conditions that led to the discovery of a hole in the 13-3/8″ casing. The investigation highlighted the tunnel vision of the decision-making process where ‘stop points’ were bypassed or not efficiently identified, contributing to operational delays and potential loss of the wellbore. The investigation concluded that insufficient information on the well was obtained during the planning phase and the financial decision tree analysis was incorrectly defined to proceed with the preparation of the contingency plans. In this process, all existing logs were re-evaluated to identify the solids behind casing, ovality, centralization, and casing-on-casing contact points. The original plan was to cut and pull the casing and then mill ~374ft of casing, with a shallow sidetrack option as contingency. However, during the execution, due to height of the top of solids encountered behind the casing, it was required to start milling from a shallower depth, with a total of ~ 1,500 ft of casing to be milled. At this stage in the operations, a fishbone diagram should have been created to perform a detailed analysis of the technical risks and cost impacts and to decide whether to continue milling or to proceed with the contingency option to sidetrack from a shallower depth. However due to peer pressure, tunnel vision goal seeking (Gasaway, n.d.), and phycological safety the multi-factor decision ‘stop points’ were not considered leading to an expensive, lengthy, and unsuccessful operations. This paper summarizes the decisions and ‘stop points’ in the process of slot recovery operations and highlights the potential outcomes of incorrect technical risks and cost analysis. Further reviewing the utilization of the engineering analysis, and economical aspects through preparation of a fishbone diagram to manage stakeholders’ expectation on upfront commitment to continue with challenging slot recovery operations on a major decision-making point. The example and process provided in this paper will benefit the industry by helping to recognize a ‘stop points’ in the operations, highlighting the risks of having catastrophic event.

OnePetro

doi: 10.2118/214595-MS

SPE

SPE-214595-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Europe > United Kingdom > North Sea (0.61)
Europe > Norway > North Sea (0.61)
Europe > North Sea (0.61)
(3 more...)

Genre: Overview (0.48)

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

SPE Disciplines:

Well Drilling > Casing and Cementing > Casing design (1.00)
Management > Risk Management and Decision-Making > Decision-making processes (1.00)

Technology: Information Technology > Artificial Intelligence > Representation & Reasoning (0.34)

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Abstract During well construction, it is important to know when a bit is damaged to the point where it must be tripped out and replaced with a new bit. Continuing to drill with a damaged bit or pulling out a bit prematurely are both bad decisions leading to increased drilling costs. A bit pull advisory system was therefore developed and deployed in the field to help the rig crew make better informed bit pull decisions. A bit degradation metric was first developed to estimate the wear on the drill bit as it is drilling. This bit degradation metric utilized a physics-based model to be generalizable both for vertical as well as horizontal wells. Next this metric along with other trends in data were combined using a Bayesian network to arrive at a bit effectiveness belief. This was then further combined with calculations of the time to trip out a damaged bit and replace it with a new bit, to arrive at bit pull beliefs for various scenarios of expected future ROP and distance to total depth (TD). The bit degradation metric was first applied offline on 80 historical wells that consisted of wells drilled in Egypt, North Sea and the US land, and verified to a high degree of accuracy. It was then integrated into a drilling data aggregator and deployed in the field. The physics-based model utilized in the calculation of the bit degradation metric required contextual data, which was automatically routed to the data aggregator from various data sources. The bit pull beliefs for a range of expected ROPs and distance to TD were made available both as channels that can be visualized in vertical charts as well as a heat map. When a bit pull belief suggested a trip out, the driller was first asked to monitor for drilling dysfunctions such as stick slip, bit balling, whirl, etc., and attempt to correct it. Failing that, the bit was to be pulled out. This system is now operational on rigs in Egypt, North Sea and the US, and the response from the field personnel has been positive to date. This is the first drill bit damage tracking advisory that has been deployed on a rig site data aggregator. Using the bit degradation metric and the bit pull beliefs, the rig site team is always able to determine the extent of damage to the bit and whether the bit must be pulled out or not. The system thus helps in reducing ILT and NPT costs by reducing the time drilled with damaged bits and eliminating premature trips out.

OnePetro

doi: 10.2118/214608-MS

SPE

SPE-214608-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > United States > Texas (0.48)
Europe > United Kingdom > North Sea (0.46)
Europe > Norway > North Sea (0.46)
(4 more...)

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

SPE Disciplines:

Well Drilling > Drill Bits (1.00)
Well Drilling > Drillstring Design > Torque and drag analysis (0.67)
Well Drilling > Drilling Operations > Directional drilling (0.66)

Technology: Information Technology > Artificial Intelligence > Representation & Reasoning (0.75)

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Curing Hydrodynamic Instability During Balanced Plug Cementing

Harestad, K. (Perigon, Randaberg, Norway) | Karimfazli, I. (Concordia University, Montreal, Quebec, Canada) | Ghazal, A. (Concordia University, Montreal, Quebec, Canada) | Harestad, M. (Perigon, Randaberg, Norway) | Saasen, A. (University of Stavanger, Stavanger, Norway)

OnePetroMay, 2023

Abstract It is shown how the flow from pumping cement through an open-ended pipe very quickly turns direction and the cement flows upwards. This rapid change in flow direction indicates that a diverter tool, which leads the cement slurry perpendicular out of a closed ended pipe does not have any function. The placement of a balanced plug is feasible. However, a high-density fluid above a lighter fluid is not stable. The phenomenon is known as Rayleigh-Taylor instability. In principle, to be reasonably stable, the interface must be horizontal. The longer the interface is, the more unstable is this case. Thus, it is difficult, or sometimes impossible, to create a stable situation in a deviated well section; especially if the well section diameter is large. Observations show that it is possible to modify density differences, thickening time and viscosity differences such that the success rate can be between 40 and 60%. Using a floatable cement foundation tool, this success rate will increase to more than 95% as shown by North Sea success values. The use of such a tool is described and its performance is justified by numerical analysis of cement flow.

OnePetro

doi: 10.2118/214577-MS

SPE

SPE-214577-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > Canada (0.47)
North America > United States > Texas (0.28)
Europe > United Kingdom > North Sea (0.25)
(3 more...)

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

SPE Disciplines:

Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
Well Completion > Well Integrity > Zonal isolation (0.72)
Well Completion > Completion Selection and Design > Completion equipment (0.72)
Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (0.69)

Technology: Information Technology > Mathematics of Computing (0.35)

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Rising to the Challenge of Drilling Through Depleted Reservoirs

Pedersen, Roar (Archer) | Zapata Bermudez, Fernando (Archer)

OnePetroMay, 2023

Abstract To overcome the challenges of drilling depleted reservoirs, a new technology was needed as part of a cost-effective solution. An innovation campaign was facilitated by a major oil company R&T (research and technology) department in the North Sea to identify concepts enabling high depletion in drilling through reservoirs. Several concepts were evaluated, and a packer in the drillstring was defined as a necessity by the major oil company. Drilling through depleted reservoirs has become more and more common in operations run by both oil operators and drilling companies, in fields that have matured. Drilling these wells introduces an increased risk for crossflow and losses and a series of mitigating actions have been put in place to obtain an acceptable risk level. This paper will focus on describing the steps taken to develop a packer that provides a seal between the drillpipe and the production casing, being part of the drilling BHA and spaced out to stay inside the casing. It's large bore through allows high flow rates and deployment of intervention tools through it. By setting the packer, it becomes a qualified V3-barrier, validated as per ISO14310 and/or API11D1, enabling the operator to cement and sidetrack efficiently, saving additional trips and rig time. This successful technology cooperation will help oil operators and drilling companies to expand its capabilities for drilling depleted and complex reservoirs and further increase the overall recovery factor for its mature fields. Rising to the challenge, means to improve the confidence in drilling with limited drilling window and avoid uncontrolled risks by using a Drillstring Annulus Sealing Packer that when set, provides a seal between the drillpipe and the casing, the packer activation is meant to be the last option in a series of mitigating measures as the wellbore will be abandoned if activated.

OnePetro

doi: 10.2118/214587-MS

SPE

SPE-214587-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Europe > United Kingdom > North Sea (0.24)
Europe > Norway > North Sea (0.24)
Europe > Netherlands > North Sea (0.24)
Europe > Denmark > North Sea (0.24)

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

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Reservoir Description and Dynamics (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.69)
(2 more...)

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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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Abstract Well simulator technologies have become an ever more important part of Well Construction design and Drilling Operations follow-up worldwide. Adopted initially by Company to support personnel training through virtual environment applications, they were then used for planning, real time support and post job analysis for drilling operations, being integrated in all engineering processes. This paper presents an overview of its current use and procedures, highlights current and potential benefits and suggestions for future developments. Selected wells are configured inside the well simulator which is then latched to mud log data streams. Dynamic models calibration is performed by adjusting dedicated coefficients to reach an overlap between simulated and measured drilling parameters. The degree of drift between curves allows to identify well operations-related issues. Outputs are mostly time-based, in mud log and driller-cabin-like layouts fashion. Depth-based plots, such as roadmaps for axial and torsional friction factors are also available and can be used as input for advanced analyses for both planning and post job phases. Systematic application of the well simulator was started early 2021 with real time monitoring for North Sea and Africa offshore/subsea operations. Deployment along 2022 spread out across several other business units in various operated countries, for onshore, offshore and subsea drilling operations. Experience gained in a number of relevant case histories, dedicated to both real time support and what-if post-analyses, allowed to provide earlier feedbacks on drilling operations good practice but also to predict, avoid and mitigate consequences of wellbore problems and equipment malfunctions, boosting interest for further developments. Nowadays, well simulator technologies constitute a fundamental step towards drilling automation, since their dynamic modelling approach allows the definition of drilling parameter envelopes inside which robotic tools can operate and generate alerts if envelopes are overridden. Anomalous behavior of the drilling parameters can be recognized and governed. Automatic configuration and calibration of real time driven models are key enablers of real time optimization of operational drilling parameters and contactless operations, reducing back-office support to minimum. Well simulator solutions that have been tested and deployed in our operations allow adaptability to a variety of existing platforms from both the operators and service companies side. The new upgrades, for data input and results visualization, are prone for user-friendly application, reducing the amount of training required for operative personnel to familiarize themselves with the tool and apply it during drilling operations.

OnePetro

doi: 10.2118/214624-MS

SPE

SPE-214624-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > United States > Texas (0.29)
Europe > United Kingdom > North Sea (0.25)
Europe > Norway > North Sea (0.25)
(2 more...)

Genre: Overview (0.84)

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

SPE Disciplines:

Well Drilling > Pressure Management > Well control (1.00)
Well Drilling > Drilling Operations (1.00)
Management > Professionalism, Training, and Education > Communities of practice (0.87)
(2 more...)

Technology: Information Technology > Architecture > Real Time Systems (1.00)

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A Gathering of Three Legends

The Way AheadMay, 2023

SPE goes back in time to 1978 in this throwback photo of Curtis Hays Whitson, Øistein Glasø, and Stein Børre Torp. Whitson is the author of the SPE Phase Behavior Monograph, founder of Whitson and Petrostreamz, a petroleum engineering software company, and a pioneer in fieldwide/multisample EOS (equations of state) modeling. Glasø is known for the Glasø PVT correlations, which contain equations for estimating bubblepoint pressure, solution gas/oil ratio (Rs), and oil formation volume factor (Bo) for North Sea oils. Torp and Whitson wrote the go-to paper on the constant volume depletion) experiment.

The Way Ahead

denmark government, equation, europe government, gathering, legend, netherlands government, norway government, PVT measurement, united kingdom government, Upstream Oil & Gas, Whitson

Country:

Europe > United Kingdom > North Sea (0.34)
Europe > Norway > North Sea (0.34)
Europe > North Sea (0.34)
(2 more...)

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

SPE Disciplines: Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)

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Collaborating Authors

North Sea

Flow-Through Experiments of Reactive Ba-Sr-Mg Brines in Mons Chalk at North Sea Reservoir Temperature at Different Injection Rates

Viscoplastic Deformation During CO2 Storage in Danish Chalk Reservoirs: Role of Petrophysical Heterogeneity and Mechanical Alteration

2H Launches Second Phase of Measurement-Based Wellhead Fatigue JIP

A Holistic Approach to Consider for Slot Recovery Based on a Failure Incident in North Sea Operations

Field Deployment of a Real-Time Bit Pull Advisory System

Curing Hydrodynamic Instability During Balanced Plug Cementing

Rising to the Challenge of Drilling Through Depleted Reservoirs

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

Well Simulator Technology Overview and Results for Onshore, Offshore and Subsea Drilling Operations

A Gathering of Three Legends

Site News

Collaborating Authors

North Sea