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Inside a Beach Drainage System: A Three-Dimensional Modeling

Fischione, Piera (University of Rome “Tor Vergata” Rome) | Celli, Daniele (University of L'Aquila, L'Aquila) | Pasquali, Davide (University of L'Aquila, L'Aquila) | Barajas, Gabriel (Instituto de Hidraulica Ambiental, Universidad de Cantabria (IHCantabria) Santander) | Di Paolo, Benedetto (Instituto de Hidraulica Ambiental, Universidad de Cantabria (IHCantabria) Santander) | Lara, Javier L. (Instituto de Hidraulica Ambiental, Universidad de Cantabria (IHCantabria) Santander)

OnePetroJune, 2023

_ The capabilities of computational fluid dynamics (CFD) to investigate detailed aspects of a physical phenomenon are here used to study the drainage efficiency of a beach drainage system (BDS)—namely, a low-environmental impact tool for shoreline stabilization. One of the advantages of CFD is its capability to investigate aspects that otherwise would be more difficult to measure experimentally. In this study, a three-dimensional CFD model was used to investigate what happens inside a drain when it is buried in a simplified fine porous domain, when an oscillating groundwater table, forced by regular waves, filters into a draining pipe. The model used was the OpenFOAM® solver IHFOAM, which solves the volume-averaged Reynolds-averaged Navier-Stokes equations to simulate flow through fine porous media such as the one in a sandy beach. A parametric study was carried out with respect to the porous medium and the draining surface characteristics as well as the flow regime inside the BDS. Different solutions on the draining surface were considered—namely, different arrangements of the holes through which water flows. Introduction This paper deals with the numerical modeling of a drain inside a fine porous medium forced by means of regular waves—that is, regular periodic oscillations of the groundwater. The proposed approach in this work is to reproduce by means of three-dimensional (3D) simulations a small case numerical test of a beach drainage system (BDS) (Fischione et al., 2021). The idea of beach dewatering was developed based on the interaction between swash zone hydrodynamics and groundwater dynamics. Its functioning relies on the interaction between groundwater level and swash zone sediment transport. BDS is a low-environmental impact tool that is thought to stabilize the shoreline, at least coupled with other methods such as beach nourishment (Di Risio et al., 2010) or coupled with other structures (Saponieri et al., 2018) to guarantee economical and efficient performances. It consists of a series of buried pipes that gravitationally or by means of a pumping system aims to locally lower the groundwater table and discourage the transport of sediment particles mobilized by the waves. It is a system that has been investigated over the decades (Grant, 1948; Chappell et al., 1979; Damiani et al., 2011) by both field experiences (e.g., Curtis et al., 1997; Bain et al., 2016) all over the world (Vicinanza et al., 2010) and means of experimental installations (e.g., Oh and Dean, 1994; Contestabile et al., 2012). It has been viewed as a possible alternative soft engineering method to counteract erosion because its low visual impact. Nevertheless, different and controversial results have been obtained from its application; hence, progressively, it has not been preferred to other methods (Fischione et al., 2022), also because the field experience results showed site-dependent performances (i.e., Vicinanza et al., 2010; Bain et al., 2016). For the sake of exhaustiveness, in the study of BDS, some technical aspects have been neglected so far (e.g., the hydraulic behavior of the pipes, their hydraulic efficiency, and some aspects that are proper to the hydraulic constructions rather than the coastal field), with a consequent lack of clear guidelines for its application. To face these aspects, the use of computational fluid dynamics (CFD) is suitable to investigate a domain and phenomena that are fully three-dimensional and nonlinear.

OnePetro

doi: 10.17736/ijope.2023.hc27

ISOPE

ISOPE-23-33-2-196

International Journal of Offshore and Polar Engineering

Country:

Europe > Italy (0.29)
North America > United States (0.28)
Europe > Spain (0.28)

Genre: Research Report > New Finding (1.00)

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

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
Data Science & Engineering Analytics > Information Management and Systems (1.00)

Technology: Information Technology (1.00)

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Abstract Extended reach drilling (ERD) can facilitate the development of untapped resources, reduce greenhouse gas emissions, surface congestion, and drilling costs. This ERD project with lower completion was started with an aim to lower well cost indicators including $/ft and $/bbl. Therefore, the challenge was to drill Slimhole ERD (6-1/8″ lateral) wells with water-based mud (WBM). WBM is more cost-effective, environmentally friendly, and less damaging to the reservoir than OBM (oil-based mud). The use of WBM instead of OBM can save $2MM per well. The major challenges in drilling Slimhole (6-1/8″ size) ERD well with lateral le include higher torque and failure to deploy lower completion due to high friction factors. The first pilot well was planned with a liner-less design considering the low friction factors required to drill 15,000′ of 6-1/8″ lateral hole and run the lower completion. The second pilot well was targeting a deeper and tighter reservoir zone with higher downhole temperatures. This involved drilling 12-1/4″ intermediate hole to the landing point with larger 5-1/2″ drill pipe. It enabled a push-pipe technique for drilling the lateral hole with improved weight transfer through the curved profile. The 6-1/8″ lateral hole was drilled with 4″ high-torque drill pipe, tandem high-flow circulating subs, and specially formulated drilling fluid lubricant. A conventional OBM system provides sufficient lubricity to reduce friction factors as low as 0.10. In this application, a low cost WBM system was made feasible by introducing stable high-temperature lubricant and unique hole cleaning practices. Following this successful achievement, the 5-year business plan has been revised to include 63 similar wells with a projected total savings of ~ $250MM. The Slimhole ERD project has demonstrated substantial value with a 35% reduction in CAPEX. The delivery of these two Slimhole ERD wells overturned conventional drilling and completion practices. The implemented project resulted in saving up to 35% of the well cost and saved 20 days per well compared to a conventional ERD well with 8-1/2″ hole and OBM. These two Slimhole ERD (15,000′ lateral) wells were drilled with a challenging Directional Difficulty Index (DDI) of 7.2. The wells were both completed successfully by running the 4-1/2″ lower completion to reach the total depth.

OnePetro

doi: 10.2118/214654-MS

SPE

SPE-214654-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

accumulation, asia government, centralizer, completion, cuttings, Directional Drilling, drilling operation, entry liner, international association, lateral, liner, packer, pipe, reservoir, slim hole erd well campaign, torque, uae government, Upstream Oil & Gas, water-based mud, WBM

Country: Asia > Middle East > UAE > Abu Dhabi > Abu Dhabi (0.50)

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

SPE Disciplines: Well Drilling > Drilling Operations > Directional drilling (1.00)

Technology: Information Technology (0.47)

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Stuckpipe Prediction Model to Detect and Notify Rig Crew Based on Drilling Parameters and Physical Models Outputs

Malki, Mohammed A. (?) | Abughaban, Mahmoud F (?) | Guimaraes, Thiago T (?) | Alshawabkeh, Albara' A (?)

OnePetroMay, 2023

Abstract Effective stuckpipe prediction becomes more challenging and requires real-time advanced analysis of all available drilling data. This paper presents an innovative model to predict stuckpipe incidents. A machine-learning model based on intensive feature-engineering integrated with physical models has been developed. It automates real-time drilling data collection, analysis, and detects the patterns for the most dominating drilling parameters values to achieve the success criteria of early warning signs of stuckpipe incidents. It has been applied on two equal sets of wells either stuck or non-stuck incidents. The model triggers alarms reliably and early before the stuckpipe incidents happen and therefore corrective actions could be taken properly in advance.

OnePetro

doi: 10.2118/214604-MS

SPE

SPE-214604-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Artificial Intelligence, concentration, dataset, drilling operation, drilling parameter, Engineering, evaluation, incident, Indicator, international association, machine learning, model, notify rig crew, physical model output, pipe, stuckpipe prediction model, Technology Conference, united states government, Upstream Oil & Gas

Country: North America > United States (1.00)

Genre: Research Report > Experimental Study (0.46)

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

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)

Technology:

Information Technology > Data Science (1.00)
Information Technology > Artificial Intelligence > Representation & Reasoning (0.95)
Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning (0.94)

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First Successful Deployment of Liner While Drilling Technology in Depleted Reservoir of Western Offshore India

Bagga, Pawandeep (Baker Hughes) | Pethe, Sarang (Baker Hughes) | Gupta, Rakesh (Oil and Natural Gas Corporation) | Gupta, Arpit (Oil and Natural Gas Corporation)

OnePetroMay, 2023

Abstract The Mumbai High field in Western offshore of India presents major challenges to both drilling and liner running operations, because of reservoir being depleted and severe lost circulation conditions. Thus Liner while drilling, a new technology was deployed as a pilot Project to drill in these troublesome carbonate reservoir. The operator had previously experienced severe losses in the zone leading to big loss of rig days and damage to Reservoir due to LCM (Loss Circulation Materials) Pills. The liner while drilling service is a sustainable technology which combines 4.75in rotary steerable system BHA (Bottom Hole Assembly) with various logging tools, 8.75in hole opener/reamer, a mud motor, and a 7in liner with 8.5in reamer bit to help overcome the challenges while drilling in zones with low formation pressure and unstable formations. Running the liner while drilling helps maintain wellbore stability and reduces open hole exposure. It is also beneficial in reducing the time required by eliminating extra trips as the liner is installed at Target Depth in the first run. It is important to understand that Drilling with a mud motor and low RPM from surface is stressing the formation much less than conventional Rotary steerable BHA. Losses were contained with special mud additives. Plastering & smearing effect across the well bore added value in curing the Losses. This Technology Reduced formation damage by avoiding repeated LCM pills. Post Drilling, the inner string was Pulled out of hole leaving the liner at bottom which was later cemented with Cement Retainer. The technology proved to be Sustainable and with reduced HSE risk for the operator. The Paper will discuss in detail about the field of application, Prejob planning for Liner while Drilling Job, Onsite Execution and Successful completion of the well. This technology Successfully drilled, lowered, and Cemented 7in Liner at Target Depth saving rig time for the operator.

OnePetro

doi: 10.2118/214567-MS

SPE

SPE-214567-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: Asia > India > Maharashtra > Arabian Sea (0.67)

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

Oilfield Places:

Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-V Formation (0.99)
Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-IV Formation (0.99)
Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Mumbai High Field > L-III Formation (0.99)
(14 more...)

SPE Disciplines:

Well Drilling > Pressure Management > Well control (1.00)
Well Drilling > Drilling Operations > Running and setting casing (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
Well Drilling > Drilling Equipment > Directional drilling systems and equipment (1.00)

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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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Pipe Feeder Robot for Land Drilling Rigs

Mikalsen, Kenneth (Canrig Robotic Technologies AS, Sandnes, Norway) | Raunholt, Lars (Canrig Robotic Technologies AS, Sandnes, Norway) | Tawfik, George (Canrig Drilling Technology Ltd, Dubai, UAE)

OnePetroMay, 2023

Abstract The objective of this paper is to present a new and innovative fully automated tubular handling robot that can feed drill pipe and casing from pipe storage on ground to the well center of a land drilling rig in a fast, accurate and all-in-one operation. In recent years, experience has been gained with large electric robots for pipe handling both offshore and onshore. As reliability is confirmed, the robotic operations on rigs are expanded. The most recent development is a Pipe Feeder Robot for handling of pipe and subs all the way from pipe storage on the ground to the well center of the land rig, including spinning into the stick-up. The technology is based on qualified heavy-duty electric robots for pipe handling, but the new machine is configured in a way so that it can be transported from rig to rig without large interfacing work. The industry has great expectations with the introduction of robotics for red zone management and eliminating manual operations and human exposure to heavy machinery. Expected value would be a substantial saving in rig days due to fast, precise and consistent operations and removal of people out of harm's way. In addition to improved safety, reduced OPEX, less downtime and faster installation, the Pipe Feeder Robot lowers the noise and the carbon footprint due to higher energy efficiency and less GHG emissions. Also, the precise motion control of the robot enables digitalization of the drilling process. The paper will present performance data and results from test operations. The Pipe Feeder Robot picks up pipe (or casing), rotates from horizontal to vertical, and spins into the stick up in one operation, whereby hazardous handovers are avoided and a hands-free handling operation is created, replacing the work of four conventional operations. Reliability of robots in hostile environment will be analyzed with regards to field experience of similar technology from land rig drilling operations. Finally, the value to the users will be substantiated. The paper will provide test results and experience from the tests of a heavy-duty all-electric Pipe Feeder Robot. It will provide valuable input for decisions for the future use of industrialized robots in the oil and gas upstream industry.

OnePetro

doi: 10.2118/214588-MS

SPE

SPE-214588-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: Asia > Middle East > UAE (0.28)

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

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Well Drilling > Drilling Equipment (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (0.68)

Technology: Information Technology > Artificial Intelligence > Robots (1.00)

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Digital Implementation and Data Analytic for OCTG Running as Tool to Control Non-Expected Operational Cost and Enhance Efficiency in Drilling Operations for Operator Company in Abu Dhabi

Amorocho, A. (Drilling Technology ADNOC, Abu Dhabi, UAE) | Elkasrawi, A. (Drilling Drilling Materials ADNOC, Abu Dhabi, UAE) | Abdelazim, A. (Drilling Drilling Materials ADNOC, Abu Dhabi, UAE) | AlRashdi, A. (Drilling Drilling Materials ADNOC, Abu Dhabi, UAE) | Shamlam, A. Bin (Drilling Operations ASR/UC/ASAB ADNOC, Abu Dhabi, UAE) | Nuaimi, M. Al (Drilling Technology ADNOC, Abu Dhabi, UAE) | Nunez, Y. (Drilling Technology ADNOC, Abu Dhabi, UAE) | Blanpied, C. (Middle East Services Director – Vallourec, Abu Dhabi, UAE) | Cavanha, T. (Business Owner OCTG Digital Solutions – Vallourec, Paris, France) | Blues, S. (Vallurec ME, Vallourec, Abu Dhabi, UAE)

OnePetroMay, 2023

Abstract Responding to requirements of Operator Company in Abu Dhabi to automate and strengthen processes of running casing and tubing, a patented digital solution has been implemented, which timestamps all key phases of the tubulars’ lifecycle from rig receipt to running then to rig return, while enabling continuous improvement through post-running data analytics. The solution relies on unique individual pipe traceability, through a combination of different methods of marking such as – data matrix, RFID & barcodes. These markings are read using a variety of digital tools including – smartphones, tablets & cameras. The solution has already been deployed in North & South America, Europe, and Asia, totaling over 100 successful jobs worldwide. Operator Company in Abu Dhabi was the first operator in the Middle East to try the solution in 2022. The below section summarizes the solution results based on the feedback from the first three wells piloted by Abu Dhabi Oil Company. The value chain is broken down into three key categories as follows: –Pre-running: the solution brought an increased level of quality control paired with an automatically generated pre-tally list. Further to this, an increase in personnel is safety assisted by a reduction in tubular handling and removal of personnel from high-risk positions. –During running: the accuracy of the running sequence was ensured by the utilization of the solution ‘‘Watchdog Alerts’. These highlighted to the user any deviation from the original plan, preventing error and minimizing any downtime generated. All of this was made available in real-time in a cloud environment to anyone within the Operator Company with credentials for accessing the system. –Post-running: monitor and compare rig performances through digitally enabled data analytics In conclusion, significant cost reduction (from 15 to 45 k$ per job for a 70k$ rig day rate), mitigating risks of non-productive time by reducing human errors (from 5 to 15 hours per job), ensuring safety and integrity of the well and enabling operators to track its assets and monitor running operations in real-time.

OnePetro

doi: 10.2118/214517-MS

SPE

SPE-214517-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Abu Dhabi, asia government, barcode, control non-expected operational cost, data analytic, data mining, digital implementation, drilling operation, drilling technology adnoc, enhance efficiency, information, international association, Operator Company, pipe, real time system, receipt, tally, uae government, Upstream Oil & Gas

Country: Asia > Middle East > UAE > Abu Dhabi > Abu Dhabi (1.00)

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

SPE Disciplines:

Well Drilling > Drilling Operations (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Data mining (0.82)

Technology:

Information Technology > Data Science (0.82)
Information Technology > Architecture > Real Time Systems (0.55)
Information Technology > Communications > Networks (0.35)

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A New Mechanical Tool and Method to Accessing Casing-Casing-Annulus to Remove Compromised Cement and Injecting a New Sealant

Machocki, K. (Aramco Overseas Company) | Alshaarawi, A. (Saudi Aramco) | Alsheikh, M. (Saudi Aramco)

OnePetroMay, 2023

Abstract This work presents experimental studies on a new tool concept to address casing-casing-annulus (CCA) pressure leak challenges in the drilling industry. The new method uses an intervention-type tool that allows for exiting the casing, cleaning cement behind, and injecting any required sealant to block fluid migration on the annular side. Addressing such CCA challenges is essential for increasing the production time and maintaining wellbore pressure integrity. A combination of 3D modeling and experimental studies is used to evaluate the feasibility of the new concept for addressing CCA fluid migration challenges. This study focuses on the development and evaluation of a tool that allows accessing and sufficiently cleaning cement in multiple CCAs. We have successfully tested a scaled tool. This tool can punch a small hole in a casing at a unique angle and clean cement behind it by drilling spirals on the annular side. The new method for accessing the annular side of the casing and cleaning cement behind it has been developed and successfully tested using scaled model rigs. Studies have involved an early proof of the concept in plastic and steel. We have also simulated cement with fluid communication channels behind the casing with a successful attempt of removing it. The experimental test results are being used to further develop a robust, downhole field-deployable tool and method that captures the essential features required to access and operate in CCA areas. The current study suggests that a significant section of cement can be removed by the proposed method: One small-diameter hole is drilled in the casing, and then a cement removing assembly is run in a spiral motion on the annular side of this casing. A suitable sealant can be injected in the created void in cement to stop potential fluid migration. This experimental study suggests that the CCA can be accessed and resealed with a minimum time and equipment if required. This CCA milling-injection system (patent pending) utilizes a novel, easily-deployable tool. This tool enables milling access into the annular side of designated casings, and enables cleaning the cement behind it. The new system only mills one hole in the casing limiting its damage and providing the ability to clean a significant section of the cement at the desired depth. This helps address potential CCA leaks, saves time and cost.

OnePetro

doi: 10.2118/214620-MS

SPE

SPE-214620-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

casing and cementing, casing-casing-annulus, cement, cement slurry, coiled pipe, drilling contractor, Effectiveness, international association, migration, new mechanical tool, operation, pipe, plastic pipe, remove compromised cement, sealant, united states government, Upstream Oil & Gas, Wellbore Design, wellbore integrity

Country: North America > United States (1.00)

Genre:

Research Report > New Finding (1.00)
Research Report > Experimental Study (1.00)

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

SPE Disciplines:

Well Drilling > Casing and Cementing (1.00)
Well Completion (1.00)
Production and Well Operations (1.00)
Well Drilling > Wellbore Design > Wellbore integrity (0.88)

Technology: Information Technology (0.48)

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The Development and Application of Ultra-Short Radius Lateral Drilling Technology in Low-Permeable Reservoir of Western South China Sea

Huang, Yi (CNOOC China Limited, Zhanjiang Branch, Zhanjiang 524057, China) | Liu, Hexing (CNOOC China Limited, Zhanjiang Branch, Zhanjiang 524057, China) | Liu, Zhiqin (CNOOC China Limited, Zhanjiang Branch, Zhanjiang 524057, China)

OnePetroMay, 2023

Abstract L2 formation of X Oilfield in western South China Sea is of characteristic of low porosity, low permeability and well controlled reserves, and long well interval, drainage area and controlled reserves can be significantly increased by adopting ultra-short radial radius drilling technology. Flexible drill pipe and drill bit was used in Well WZ-X1 to perform kick-off operation with only 2.4 m footage to increase inclination from 37 °to 87 °, and hold its inclination by drilling 60-62 m alongside reservoir with trajectory control margin of ±2°. This paper highlights the trajectory control technology with research of BHA, build-up and hold drill bit, and accurate calculation. During the field operation, drilling parameters were adjusted on the basis of formation variation and outstanding trajectory effect was accomplished and ultra-short radial radius trajectory control technology was achieved. This technology can solve the problem of trajectory control and extend horizontal section of reservoir. It can increase wellbore drainage area and well control reserves, providing technical reference for future operation.

OnePetro

doi: 10.2118/214642-MS

SPE

SPE-214642-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: Asia > China (1.00)

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

Oilfield Places:

Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin > Tahe Field (0.99)
North America > Canada > Alberta > Branch Field > Altana Et Al Reagan 10-36-1-19 Well (0.98)

SPE Disciplines:

Well Drilling > Well Planning > Trajectory design (1.00)
Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Drilling > Drilling Equipment (1.00)
Well Drilling > Drill Bits (1.00)

Technology: Information Technology (0.47)

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Optimization of Lateral Length and Risk Assessment Based on Wellbore Undulations

AlGobi, Ghaleb. A. (Department of Petroleum Engineering, University of Houston, Houston, Texas, United States) | Samuel, Robello (Halliburton, Houston, Texas, United States)

OnePetroMay, 2023

Abstract The success of drilling new horizontal wells depends on connecting the well’s surface location with the targeted formation while achieving the desired lateral length. However, the choice of the surface locations can be limited due to difficulties obtaining the permits to drill on these locations. This creates more deviated wellbore designs and decreases the optimized lateral length. To avoid this, a risk matrix will be developed to evaluate the maximum lateral length for different surface locations. The first step to creating the risk matrix is to derive a geometry-focused torque and drag model. This model will utilize the wellbore’s step-out and geometrical torsion, which are resulting of both a deviated well design and a far surface location. In this paper, the step-out for any given well path design will be considered as the sum of the horizontal projections of all the deviated segments of the well trajectory above the last curve’s KOP. The calculation of the step-out will be incorporated into the model, then will be used to calculate the maximum lateral length versus the step-out. A torque and drag model with the simplicity of the soft-string model was created while taking into consideration the wellbore’s geometrical torsion to capture the effect of the well’s trajectory on the axial forces and the torque. This effect will partially simulate the deformation of the drill pipe using simplified mathematical expressions comparing to the calculations of the stiff-string model. This methodology resulted in the model to be more sensitive to the axial force than the torque. The built risk matrix uses the derived model to highlight one of two mechanisms that determine the dominant constraint that limits the drilling process: either reaching the maximum hook load or the maximum torque, based on the wellbore design. These limits depend on the rig’s capacity and the drilling company. The risk matrix summarizes multiple designs to conveniently compare between different step-out values and their respective maximum later lengths. The risk assessment is quantitative rather than qualitative and is reflected as the percentage used of the dominant constraint for the given designs and the interval of the lateral lengths at which this percentage is reached. The optimum surface location with its step-out is then chosen easily from the created risk matrix. The built model takes a middle position between the soft-string model and the stiff-string model by capturing the geometrical torsion along the wellbore trajectory. This approach enhances the geometrical optimization when calculating the axial force and the torque. The simplified mathematical derivation incorporates the step-out into the model, thus creating the risk matrix to optimize the lateral length based on the surface location.

OnePetro

doi: 10.2118/214639-MS

SPE

SPE-214639-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: North America > United States (0.29)

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

SPE Disciplines:

Well Drilling > Well Planning > Trajectory design (1.00)
Well Drilling > Drillstring Design > Torque and drag analysis (1.00)
Well Drilling > Drilling Operations > Directional drilling (1.00)
Management > Risk Management and Decision-Making > Risk, uncertainty, and risk assessment (1.00)

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Collaborating Authors

Inside a Beach Drainage System: A Three-Dimensional Modeling

Longest Slim Hole ERD Wells Campaign with Limited Entry Liner Using Water-Based Mud in Onshore Abu Dhabi

Stuckpipe Prediction Model to Detect and Notify Rig Crew Based on Drilling Parameters and Physical Models Outputs

First Successful Deployment of Liner While Drilling Technology in Depleted Reservoir of Western Offshore India

Curing Hydrodynamic Instability During Balanced Plug Cementing

Pipe Feeder Robot for Land Drilling Rigs

Digital Implementation and Data Analytic for OCTG Running as Tool to Control Non-Expected Operational Cost and Enhance Efficiency in Drilling Operations for Operator Company in Abu Dhabi

A New Mechanical Tool and Method to Accessing Casing-Casing-Annulus to Remove Compromised Cement and Injecting a New Sealant

The Development and Application of Ultra-Short Radius Lateral Drilling Technology in Low-Permeable Reservoir of Western South China Sea

Optimization of Lateral Length and Risk Assessment Based on Wellbore Undulations

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