Formation Evaluation & Management

Reservoir - Technical Discipline - SPE

SPE WebsiteJune, 2023

Reservoir News Missing in the Montney: Unreported Wet Gas Skews Picture of Canada's Premier Shale Play Engineering Approach Uses Underbalanced Coiled-Tubing Drilling Green Paper: Reservoir Technologies of the 21st Century To tackle the current and future challenges of reservoir technologies, the SPE Reservoir Advisory Committee (RAC) began an initiative in May 2019 to develop a comprehensive strategic plan to review, revise, and update the reservoir technical discipline. SPE Tech Director Outlook Three Trends To Shape the Future of the Reservoir Discipline Rodolfo Camacho-Velázquez identifies areas of opportunity for future reservoir engineers related to the technical challenges of increased production and recovery of complex conventional and unconventional reservoirs, the application of Fourth Industrial Revolution technologies in reservoir subdisciplines, and the energy transition. SPE Energy Stream SPE Energy Stream is your go-to for watching thought leaders, subject-matter experts, and leading companies share their perspectives and technical solutions. View more on SPE Energy Stream Online Education Join industry experts as they explore solutions to real problems and . SPE webinars are offered free to members courtesy of the SPE Foundation.

SPE Website

Country: North America > Canada (0.56)

Genre: Instructional Material > Course Syllabus & Notes (0.39)

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

Oilfield Places: North America > Canada > Saskatchewan > Williston Basin > Premier Field > Shaunavon Formation (0.98)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
Reservoir Description and Dynamics > Reservoir Characterization (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
(2 more...)

Technology: Information Technology (1.00)

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Managing High Bottom-Hole Temperature Challenges in Ultra-Slim Long Horizontal Wells

Ovwigho, Efe Mulumba (SLB)

OnePetroMay, 2023

Abstract The deep carbonate reservoir formation on this field has proven to be an extreme High-temperature (HT) environment for downhole equipment. While drilling the 5000 - 6500 ft 5-7/8" slim long laterals across this formation, very high bottom-hole circulating temperatures is encountered (310-340 degF) which exceeds the operating limitation for the downhole drilling/formation evaluation tools. This resulted in multiple temperature-related failures, unplanned trips and long non-productive-time. It became necessary to provide solution to reduce the BHCT-related failures. Performed offset-wells-analysis to identify the BHT regime across the entire-field, create a heat-map and correlate/compare actual formation-temperatures with the formation-temperature-gradient provided by the operator (1.4-1.8 degF/100-ft). Drilling reports and MWD/LWD/wireline logs were reviewed/analyzed. Reviewed tools-spec-sheets, discovered most of the tools had a maximum-temperature-rating of 300-302 degF and were run outside-technical-limits. Observed temperature-related-failures were predominant in very long slim-laterals, which indicated that some of the heat was generated by high flow rate/RPM and solids in the system. Tried drilling with low-RPM/FR, did not achieve meaningful-temperature-reduction. After detailed risk-assessment and analysis on other contributing factors in the drilling process, opted to incorporate mud-chiller into the surface circulating-system to cool-down the mud going into the well. Upon implementation of the mud chiller system, observed up to 40 degF reduction in surface temperature (i.e. temperature-difference between the mud entering/leaving mud chiller). This was achieved because the unit was set-up to process at least twice the rate that was pumped downhole. Also observed reduction in the bottom-hole circulating temperature to below 300 degF, thus ensuring the drilling environment met the tool specifications. The temperature-related tools failure got eliminated. On some of the previous wells, wireline logging tools have been damaged due to high encountered downhole temperature as circulation was not possible prior-to or during logging operation. The implementation of the mud-chiller system has made it possible for innovative logging thru-bit logging application to be implemented. This allows circulation of cool mud across the entire open hole prior to deployment of tools to perform logging operation. This has made it possible for same logging tool to be used for multiple jobs without fear of tool electronic-components failure die to exposure to extreme temperatures. The long non-productive time due to temperature-related tool failures got eliminated. The numerous stuck pipes events due to hole deterioration resulting from multiple round trips also got eliminated. Overall drilling operations became more efficient. The paper will describe the drilling challenges, the systematic approach implemented to arrive at optimized solution. It will show how good understanding of drilling challenges and tailored-solutions delivers great gains. The authors will show how this system was used to provide a true step-change in performance in this challenging environment.

OnePetro

doi: 10.2118/214623-MS

SPE

SPE-214623-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Europe > United Kingdom (0.46)
North America > United States > Texas (0.28)
Asia > Middle East > UAE > Abu Dhabi > Abu Dhabi (0.15)

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

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)

Technology: Information Technology (0.68)

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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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Enzyme-Based Cleanup Fluid for High Temperature Filtercake Removal Applications

Al-Taq, Ali A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia) | Al-Ibrahim, Hussain A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia) | Alsalem, Ali A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia) | Alrustum, Abdullah A. (Saudi Aramco, Dhahran, Eastern Province, Saudi Arabia)

OnePetroMay, 2023

Abstract Mud-induced damage is highly pronounced in horizontal wells due to the longer period of exposure to drilling mud and low draw-down pressure. Enzyme-based cleanup fluids are preferred for filtercake removal applications, especially in horizontal wells due to their several advantages compared to conventional cleanup fluids. The advantages include low reactivity, less corrosivity, more environmentally safe, polymer-specific enzyme breakers, and ultimately homogenous filtercake removal coverage. Most enzyme-based cleanup fluids are limited to low temperatures. In this study, extensive lab work was conducted to evaluate an enzyme-based/in-situ generated organic acid cleanup fluid for a water-based mud at a temperature of 250°F. The experimental work included coreflood experiments, HT/HP filter press, and see-through cell. Analytical techniques, including ICP, XRD, EDXRF, IFT, and iodine tests, were used to assess the interaction of the cleanup fluid with filtercake components. The results showed that the enzyme/in-situ organic acid generated cleanup system was effective at degrading filtercake for a water-based mu field sample, which was reflected in the obtained return permeability of nearly 83%. Iodine tests confirmed that the enzyme was able to degrade the starch present in the filtercake. The surface tension of fluid is generated due to the interaction of the enzyme-based breaker with the filtercake at 250°F and for 48 hours was 31.11 dynes/cm at 22°C, which indicates that this system can help to prevent water blockage problems, especially for gas tight formation. This paper will discuss in detail all experimental results and findings.

OnePetro

doi: 10.2118/214628-MS

SPE

SPE-214628-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

North America > United States > Texas (1.00)
Asia > Middle East > Saudi Arabia (0.68)

Genre: Research Report > New Finding (1.00)

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)
(25 more...)

SPE Disciplines:

Well Drilling > Formation Damage (1.00)
Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
(4 more...)

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Automate the Boring Stuff with Python—An Innovative Solution to Borehole Salinity Estimation

Dutta, M. (SLB, Mumbai, Maharashtra, India) | Das, A. (SLB, Mumbai, Maharashtra, India) | Hati, S. (SLB, Mumbai, Maharashtra, India) | Das, B. (SLB, Mumbai, Maharashtra, India)

OnePetroMay, 2023

Abstract Most field engineers and geoscientists find the estimation of borehole salinity using multiple mud reports to be a tedious task. The existing process involves using spreadsheets with multiple charts for conversion and requires the user to juggle from charts to reports to calculators at the same time. Depending on the mud vendor, the standard of estimation and equations change, making the process more user intensive. However, these equations can be strategically used in a programming language to automate this exhaustive and manual process of estimation. Any open-source code editor can be used to run the codes and generate borehole salinity at any depth desired. Borehole salinity is an important parameter as it influences the correction of neutron porosity and associated measurements to be used for petrophysical evaluation. In this study we first outline the current industrywide used methodology of estimating borehole salinity using mud reports supplied by vendors. The input parameters, calculation standards, and equations vary based on mud type and vendor. We also outline the increased complexity and decreased efficiency of the existing estimation process by focusing on two factors: first, equations are mostly embedded in a spreadsheet, which still requires manual interventions such as copying and editing values from large numbers of mud reports. Second, it can be time consuming, and the user needs hours-long training to comprehend the process. We then discuss the novel automated process where a suite of scripts written in open-source Python language runs via any open-source code editor. By using the popular Python library and DataFrame, tabular data from mud reports can be detected and pertinent values can be used as input for necessary calculation using the equations and charts already embedded in the scripts, which eventually generates salinity values in less than a minute. This project aims to deliver an automated solution to estimate borehole salinity. This methodology can be adopted by engineers on the rig and geoscientists in the office to calculate salinity values instantaneously without using any conversion chart or complicated equations whatsoever. In a case study using 20 samples from a typical mud vendor, we show that the new process is time saving and produces accurate borehole salinity values that are the same as values calculated using a manual technique. It is also a zero-cost process as open-source yet licensed software is used for estimation and needs little training for operation. The key innovative aspect of this project is to create a stepping-stone towards automation of day-to-day routine tasks that are being executed manually in the office and at the rig site. Existing salinity estimation has remained unchanged since early 2000 and calls for an update as the industry is taking aggressive steps towards automation. Borehole salinity automation is a first of its kind and its successful establishment will encourage more automation of similar calculation-based workflows.

OnePetro

doi: 10.2118/214534-MS

SPE

SPE-214534-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Asia > Middle East (0.28)
Asia > India (0.28)

Genre: Overview > Innovation (0.40)

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

SPE Disciplines:

Well Drilling > Drilling Fluids and Materials (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Data Science & Engineering Analytics > Information Management and Systems (1.00)

Technology: Information Technology > Software > Programming Languages (1.00)

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Forecasting Reservoir Pressure for Vertical Oil Well Using Supervised Machine Learning Model

Said, Laouedj (Sonatrach, Petroleum Engineering and Development Division, Hydra Algiers, Algeria)

OnePetroMay, 2023

Abstract Static pressure is one of the very important parameters for reservoir engineering, it gives us precious information about our reservoir, such as drive mechanisms, quantities of hydrocarbon in place, patterns, communication between wells, fluid behavior in the reservoir, as consequence, the measurement of this parameter must be conducted on periodical basis, to appropriately know the field and build a good model of reservoir. The advantage of this study can complete other studies that concentrate only on the oil production rate forecasting like Data Driven Production Forecasting Using Machine Learning [1], Production Forecasting in Conventional Oil Reservoirs Using Deep Learning [2], Machine Learning Prediction Versus Decline Curve Prediction: A Niger Delta Case Study [3], Decline Curve Analysis for Production Forecasting Based on Machine Learning [4] ……, in addition of static pressure evolution of wells. For instance, we can optimize through this study a number of conducted tests to measure static pressure which will minimize operating costs and the probability of accidents occurring the operations, also reduce the shutdown time of wells for completion purpose of such measurement, in addition to the possibility of using this model for other analogue wells that do not have enough pressure measurement, without the need for time and extensive study. Besides, multivariate polynomial regression machine learning algorithm has been developed in this study to predict the evolution of static pressure for existing oil wells.

OnePetro

doi: 10.2118/214526-MS

SPE

SPE-214526-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Asia (0.94)
North America > United States (0.94)
Africa > Middle East > Algeria (0.28)
Africa > Nigeria > Niger Delta (0.25)

Genre: Research Report (0.36)

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:

Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)

Technology: Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning > Regression (0.48)

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Abstract Removing mud from around the casing or liner and replacing it with drilling or cement fluid is fundamental to achieving zonal isolation. One significant parameter needed to achieve flow around the casing is proper casing centralization. Casing centralization is a function of many wellbore properties, such as fluid and centralizer data, which are obtained from the directional survey and caliper data. Computer simulations are used to optimize centralizer selection and placement prior to running the casing into the wellbore and the cementing operations. This paper presents the method and technology used to compare simulated vs. real centralization and the key lessons learned from a Kuwait project. To complete the continuous improvement cycle, it is important to confirm the casing standoff in a postcement operation to determine if the prejob assumptions and the simulations were accurate. Using standard cement evaluation logs, it is not possible to directly measure the casing standoff. Therefore, conclusions have to be made indirectly, based on the cement evaluation data. The new-generation ultrasonic flexural measurement tools can be used to evaluate casing centralization directly by evaluating the time between the first casing reflection (mud to casing interface) and the third reflection (cement formation interface). For a Kuwait project, a new one-piece slip-on centralizer was introduced for field operations. Prejob standoff simulations were performed to optimize the casing standoff to meet the operator and service company recommendations. All available well and fluid data were included in the simulations to accurately predict the casing standoff. The simulations used a state-of-the-art, stiff-string simulator to provide the most accurate simulations results. To evaluate the standoff simulations and centralizer performance, the third-interface echo (TIE) measurements were used to determine actual standoff. The ultrasonic measurements were run on three different cemented intervals. These intervals ranged from a vertical 16-in open hole interval to a highly deviated 8½-in openhole section. By comparing the actual measurement with the simulations results, a direct standoff evaluation was made possible regarding the centralizer selection and placement and the assumptions made during the well planning phase. It also provides better understanding on the performance of the centralizers. Using the advanced flexural ultrasonic logging tool and the TIE measurement provided the opportunity to compare actual casing standoff results vs. prejob casing centralization simulation. The results demonstrated the importance of having accurate well data available during the design phase and the impact particular assumptions have on the final casing standoff. By comparing the actual casing standoff results vs. prejob casing centralization simulation, important lessons can be learned about centralizer selection, placement, and how standoff simulations can be implemented during field development to improve casing standoff. Thus, the probability of effective mud removal and zonal isolation increases.

OnePetro

doi: 10.2118/214538-MS

SPE

SPE-214538-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: Asia > Middle East > Kuwait (1.00)

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

SPE Disciplines:

Well Drilling > Well Planning > Trajectory design (1.00)
Well Drilling > Drilling Operations (1.00)
Well Drilling > Casing and Cementing > Cement and bond evaluation (1.00)
(4 more...)

Technology: Information Technology (0.69)

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Sour Rated 10,000-psi System High Temperature Gas Development Wells: A Journey of Optimization in North Malays Basin While Sustaining the Nation Gas Demand

OnePetroMay, 2023

Abstract High temperature, high carbon dioxide coupled with hydrogen sulfide contents, and rapid PPFG pressure ramp increase gas development well tends to cause high well capex for Operator. This well type typically needs high CRA material with at least a 10,000-psi rated system to complete. Offshore peninsular Malaysia’s North Malay Basin (NMB)’s deep reservoirs also fall into the described category. This paper aims to share the optimization journey, applications, and learnings of the company’s H.T. sour-rated 10Ksi gas development wells through several phases, besides fulfilling the gas delivery need for the country. In addition, engineering and operational optimizations are identified to reduce the well’s time and cost without sacrificing the crew’s safety as the team focus. The company wells engineering team applied Lean approaches encompassing the complete Plan-Do-Check-Adjust cycle to achieve the optimization. Well data usage, lessons learned, collaboration, continuity, and striving for continuous improvements are the key factors to ensure good optimization results. Fit-for-purpose drilling and completions equipment design and application, rig offline capabilities planning, wellhead dummy hanger plug design for offline cementing, intervention-less production packer setting device, offline annulus nitrogen cushion fluids displacement and other applications will be explained in the paper. The paper explained the operational challenges, how and what optimizations applied to achieve excellent well performance compared to targets and previous campaigns. The wells team optimizations spread out from engineering to execution stages, including rolling out in-house talent of digitization and digitalization of well performance surveillance, in line with the industry's way forward. The recent campaign post optimization concluded with no safety incidents, below budgeted time and cost, low overall NPTs, and achieved first gas to meet the country's power generation demand. Open, collaborative, and proactive cross departments communications are the catalysts that contributed to the positive optimization journey's results.

OnePetro

doi: 10.2118/214653-MS

SPE

SPE-214653-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country: Asia > Malaysia > South China Sea (0.61)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Government > Regional Government > Asia Government > Malaysia Government (0.46)

SPE Disciplines:

Well Drilling > Casing and Cementing > Casing design (1.00)
Well Completion > Completion Installation and Operations > Perforating (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
(3 more...)

Technology: Information Technology (1.00)

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Dynamic Well Control Simulation to Ensure Safer Sampling and Deep Transient Testing: Case Studies from the Southeast Asia Region

OnePetroMay, 2023

Abstract The objective of this paper is to present well control challenges, and results of utilizing wellbore dynamic simulation to achieve safer formation tester (FT) sampling and deep transient tests (DTT) operations. Insight will be provided based on the first implementation in a Southeast-Asia offshore well, with focus on pre-job simulation that is validated with measured data to help improve understanding of gas/hydrocarbon interaction with wellbore mud during and after FT pump-out operations. FT involves obtaining formation pressure, pressure transients, and downhole fluid samples, and the latest DTT technology enables larger gas/hydrocarbon volumes to be pumped into the wellbore which requires a comprehensive understanding of the processes involved. Wellbore dynamics accurately predicts the interactions between downhole pumped hydrocarbon and drilling fluid using a dynamic multiphase flow simulator. For the sampling operation, a maximum allowable downhole gas volume is evaluated prior to operation and simulations are compared to surface gas observation obtained during a wiper trip (mud circulation). During DTT operations, pumped formation fluids are routed to a circulating sub, where they are mixed with circulated mud and the mixed fluids are simultaneously carried to surface. Downhole wellbore pressure measurements are sent to a real time cloud-based dashboard and compared with simulations. The ability to weigh measurements against simulations creates a comprehensive understanding of well control scenarios and provides a much safer execution of FT operations than conventional methods. For wireline FT operation, post job comparison showed that the simulation matched well with surface observations during the wiper trip. The simulator accurately predicted the surface free gas arrival compared to mud-gas logging measurements, which confirmed that gas stayed dissolved in the Synthetic Based Mud (SBM) downhole without migrating upwards. For DTT, wellbore pressure measurements were sent in real time to a cloud-based dashboard and are compared to simulations and simulations could be quickly re-run to account for changes in observed formation fluid, downhole flowrates or mud circulation rates. The FT and DTT operations were conducted successfully and safely and in both cases the measured data agreed well with the simulations. With the accurate wellbore dynamics simulator, changes in drilling fluid design, circulating rates, hydrocarbon composition, downhole pump rates, and pump duration for various FT design sequences are quantified, and the downhole well pressure, free-gas distribution along the well geometry, and gas rates on surface can be predicted. This insight provides more flexibility and understanding to plan advanced FT operations and enables larger volumes of hydrocarbon to be pumped downhole. Furthermore, adopting an advanced pressure transient testing method like DTT also aligns with the industrial effort of reducing carbon dioxide emission footprint.

OnePetro

doi: 10.2118/214600-MS

SPE

SPE-214600-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Country:

Asia (1.00)
North America > United States (0.68)

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

SPE Disciplines:

Well Drilling > Pressure Management > Well control (1.00)
Well Drilling > Drilling Fluids and Materials (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Data Science & Engineering Analytics > Information Management and Systems (1.00)

Technology:

Information Technology > Architecture > Real Time Systems (0.69)
Information Technology > Sensing and Signal Processing (0.54)

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Abstract The search for oil dates to the 1850s, and, since continuous overtime improvements and enhancements to the available technologies have been introduced. However, the quest for continuous improvements is directly related to the advantages and ease of exploitation of this nature given resource. Currently, concepts of formation evaluation, which is the analysis of subsurface formation characteristics, such as lithology, porosity, permeability, and saturation, are acquired by methods such as wireline well logging, real-time logging while drilling and core analysis. The advantage of core analysis (coring) fully leans on the ability to retrieve cores as close as possible to the actual reservoir's properties, hence porosity and permeability can be more precisely evaluated. The main aim of this project is to prove that it is possible to core and log at the same time, thus saving time and increasing the accuracy of the coring points. First phase of this trial as technological innovation is an Advanced Coring System (ACS), which cuts the core while logging, and contemplates gamma ray and resistivity sensors within the core Bottom Hole Assembly (BHA) itself, close to the core head. Due to the presence of electronic components within the coring equipment, the core diameter was limited to a 3 in. OD core. The first trial was done on a middle east onshore field during Q3 of 2022. The main objective was to ensure that reservoir information (gamma ray, inclination, vibration, temperature) was being acquired real time while using the Intelligent Coring System (ICS) to enable retrieval and interpretation of downhole data. The coring BHA was composed by a coring head, the Logging While Coring (LWC) tool, wired outer barrels, wired spacers and stabilizers, a drop ball sub, and an MWD module. The coring assembly was successful at cutting and recovering the target core interval with good performance, comparable to standard coring BHA, however, the main objective of the trial, the LWC was not achieved. The MWD experienced malfunctions, hence no real-time gamma ray data was transmitted to surface. After POOH the assembly was laid down, and preliminary investigation at the rig site showed the showed fluid invasion of the electronics components, impairing the memory data retrieval. As a last resort, the memory board was disassembled and taken to the manufacturer's laboratory to attempt data recovery. Unfortunately, the board was damaged beyond repair due to the fluid ingress and the memory data was unretrievable. The ICS is a novel technology, potentially disruptive of the way coring is done today: A coring system, which combines coring and real-time formation evaluation. A second innovative technology is under development, is the Downhole Convertible Drill Bit a system that allows downhole conversion between coring and drilling modes, thus saving several round trips. This system is to be tested in field applications.

OnePetro

doi: 10.2118/214594-MS

SPE

SPE-214594-MS

SPE/IADC Middle East Drilling Technology Conference and Exhibition

Abu Dhabi, advanced coring system, asia government, BHA, disruptive technology applied, drilling operation, field worldwide trial, gamma ray, information, international association, procedure, provide real-time logging, real time system, sensor, survey article, uae government, Upstream Oil & Gas

Country: Asia > Middle East > UAE (0.30)

Genre: Overview > Innovation (0.34)

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

SPE Disciplines:

Well Drilling > Drilling Operations > Coring, fishing (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)

Technology: Information Technology > Architecture > Real Time Systems (0.98)

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