Sharjah

Capitalizing on untapped potential and quantifying risk is the key to success in a turbulent commodity industry. Mature fields have seen it all. Periods of high oil price have invited increased investment and pushed boundaries, while low-oil-price periods have had a severe effect on the fields’ sustainability and development. Mature fields have existed through a time of great technological change and stand on the cusp of their ultimate fate—either to maximize recovery with the lowest possible expenditures amid tightening environmental regulations or to close the taps and prepare for painful abandonments. In a capital-intensive industry, mistakes often are unforgiving and the costs of uncertainty and error are great. Fluctuating technological, political, and business influences add to the volatility and risk in selecting the next big idea for mature fields. The framework and success of future opportunities is reliant on the data used to quantify them, and this is something of which all mature fields have plenty. As they have delivered value throughout their life, the uncertainty associated with them reduces, and the new ideas discussed here come to light. Alternative use of wells for geothermal energy generation, carbon sequestration in depleted reservoirs, and the use of machine learning to maximize recovery are solutions that provide insight into how diverse the scope of mature field rejuvenation ideas can be. These solutions have something in common, however; they aim to capitalize on data, modularize problems, and structure a sustainable solution. These solutions are scalable, upgradable, and, most importantly, cost-effective for large and small operators. The upstream sector has long valued efficiency and accuracy. Small improvements in mature fields can make a significant economic difference with an established infrastructure in place. Value in large mature fields still exists, but one has to know where to look and what lenses to use. Recommended additional reading at OnePetro: www.onepetro.org. IPTC 21436 Permeability Prediction Using Rock Typing, Flow-Zone Indicator, and Machine-Learning Techniques in a Brownfield Offshore Malaysia by Budi Priyatna Kantaatmadja, Petronas, et al. SPE 208204 Generating Value From Mature Gas Fields by Quantifying Well-Integrity Assurance With a Critical Analysis of Multiple Logs and Retrieved Tubular Surface Inspection by Christna Golaco, Sharjah National Oil Corporation, et al. SPE 209988 Successful Reservoir Management and Optimization of Mature Steamflood Projects Using Artificial Intelligence by Andrei Popa, Chevron, et al.

OnePetro

doi: 10.2118/0123-0062-JPT

SPE

SPE-0123-0062-JPT

Journal of Petroleum Technology

Artificial Intelligence, asia government, enhanced recovery, iran government, JAIN, machine learning, mature fields, sharjah national oil corporation, SPE, Technology Focus, uae government, Upstream Oil & Gas, value, Well Revitalization

Country:

Asia > Middle East > Iran (0.42)
Asia > Middle East > UAE > Sharjah > Sharjah (0.31)

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

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)

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

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Siddharth Jain

Journal of Petroleum TechnologyDecember, 2022

Siddharth Jain, SPE, is field development team leader at Sharjah National Oil Corporation. He holds a bachelor’s degree in petroleum engineering, an MBA degree in oil and gas management, and an executive master’s degree in energy management. Jain has worked on field development, integrated reservoir management, production enhancement, and upstream data-hub projects. He has served as the young professional chair for the SPE Northern Emirates section since 2019 and is a technical committee member in various industry forums. Jain has been awarded the SPE 2021 MENA Regional Young Member Outstanding Service Award and was recognized as a 2021 Energy Influencer by SPE’s The Way Ahead in June 2021. Most recently, he has been awarded the Young Energy Professional of the Year 2022 at the Middle East Energy Awards in Dubai.

Journal of Petroleum Technology

asset and portfolio management, siddharth jain, Upstream Oil & Gas

Country:

Asia > Middle East > Iran (0.68)
Asia > Middle East > UAE > Sharjah > Sharjah (0.31)
Asia > Middle East > UAE > Dubai > Dubai (0.31)

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

SPE Disciplines: Management > Asset and Portfolio Management > Field development optimization and planning (0.96)

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JPT Editorial Review Board

Journal of Petroleum TechnologyDecember, 2022

Journal of Petroleum Technology

asia government, china government, India government, jpt editorial review board, uae government, united states government, Upstream Oil & Gas

Country:

North America > United States > Colorado (0.16)
Asia > Middle East > UAE > Sharjah > Sharjah (0.16)
Asia > India (0.16)
Asia > China (0.16)

Industry: Energy > Oil & Gas > Upstream (0.63)

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Multi-Field Integrated Rock Type Framework Optimisation in Thrusted Carbonates of The Thamama Group to Reduce Modelling Uncertainty and Improve Reservoir Characterisation

Robert, Matthew James (Sharjah National Oil Corporation) | Saradva, Harshil (Sharjah National Oil Corporation) | Obaid, Shams (Sharjah National Oil Corporation) | Jain, Siddharth (Sharjah National Oil Corporation) | Jha, Bhawesh Chandra (Baker Hughes) | Salter, Tim (Baker Hughes)

OnePetroOctober, 2022

Abstract Objectives/Scope This study aims to use modern techniques to re-characterise the diagenetically altered Thamama Group reservoir units of multiple gas-condensate fields in Sharjah, UAE and determine robust rock-typing framework from the full dataset and recent core analysis program. This would be used to reduce mismatches observed in static and dynamic properties and demonstrate that a matched-outcome can be achieved with less model manipulation by focusing on textural variances within the units. Methods, Procedures, Process Samples were petrographically reviewed using microscopic and SEM data, geologically typed and compared to the petrophysical groupings Petrophysical rock types were predicted using pore size distribution information from MICP Thomeer Parameters, divided via K-mean clustering and then applied to the complete core porosity-permeability dataset. Rock types were defined using a hybrid Winland (r35) and Lucia classification. A Random Forrest Regressor-based model for permeability prediction was trained using wireline and core-derived permeability. Permeability was then predicted in uncored wells. Pc-Sw curves were computed (Brookes-Corey) Properties were distributed within the static model The saturation property distribution was compared with well log saturations Dynamic simulation was conducted and the results compared to previous model version Results, Observations, Conclusions Four petrophysical rock types were identified and found good equivalence to the identified petrographical rock types; the algorithm separated mono-modal micritic packstones from highly diagenetically altered grainstone-wackestone rudstone facies, with the rock-type clusters also being defined by Winland-r35 and Lucia poro-perm threshold lines. A single rock-typing framework, suitable for all studied fields with observed differences being explained by variability in the rock type proportions. When compared to the previous rock typing framework and reservoir models, better matches were achieved between predicted properties and core data in QC wells. Static model property distributions were more realistic in achieving a volumetric match with produced gas. Better saturation distribution with realistic Swcr and Socr were observed by using the new Rock Typing Sw equations. Rel-perm modification for increasing water production to match the observed data was negligible due to presence of more water saturation in the crest of the reservoir. Multipliers for permeability and porosity were significantly reduced to match the well productivities and tubing head pressure estimations were improved due to less mismatch with liquid production rates. Novel/Additive Information This work represents the first time petrophysical and petrological rock typing was conducted for several gas-condensate fields in Sharjah, UAE. Newly acquired core data, petrographical information and core descriptions were integrated in the study. The previous workflow, established in 1993, was updated using modern machine-learning techniques incorporating new data and a wider range of data than the previous rock typing model that was based solely on porosity measurements, remaining consistent to pore-scale and textural changes.

OnePetro

doi: 10.2118/211648-MS

SPE

SPE-211648-MS

ADIPEC

Country: Asia > Middle East > UAE > Sharjah > Sharjah (0.46)

Genre: Research Report (0.47)

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

Oilfield Places:

Asia > Middle East > UAE > Thamama Group > Shu'aiba Formation (0.99)
Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Habshan Field > Thamama Group > Habshan Formation (0.98)
Asia > Middle East > UAE > Sharjah > Arabian Gulf > Ras al Khaimah Basin > Sharjah Field (0.97)
(2 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
Reservoir Description and Dynamics > Reservoir Characterization (1.00)
(3 more...)

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

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Enhancing Employee Morale by Providing Felxible Workweek Options: A Success Story in Sharjah

Shafique, Fatima Muhammad (Sharjah National Oil Corporation) | Al Haddi, Mohammed (Sharjah National Oil Corporation)

OnePetroOctober, 2022

Abstract Since UAE has adopted a shorter workweek since the new year -2022, to align with global markets, many organizations have had to implement measures to adhere to this change. Sharjah National Oil Corporation has decided to provide their employees with multiples flexible weekend options to choose based on their convenience. A survey was conducted on the options provided to employees, for their feedback and effectiveness of this new change. The employees had been provided with 3 flexible weekend options containing all details regarding working hours, work schedule, effect on leave entitlement etc. These options were circulated to all employees, and a meeting was conducted to address any questions on the options provided. Employees adopted the new options and a survey was conducted to evaluate the Effectiveness of the new weekend policy and its impact on business and team performance after the 3-month mark. The survey questions were categorized based on employees personal, team and business perspectives. Employees were sent a link to complete the survey online regarding their feedback and evaluation A total of 86.5% of SNOC employees have participated in the survey, 13.5% of employees did not participate due to non-interest or absence from work. The results showed that 87.16% of employees are willing to stick with their current weekend selection for the remainder of 2022, 12.84% of employees wanted to change their option due to personal convenience and productivity levels. Majority of employees have agreed that employee morale has increased and work-life balance has improved based on the new weekend policy change. 87% of employees have agreed that there has been no negative impact on their "personal" work productivity and 74% of employees have agreed there is no negative impact on "team" productivity due to the weekend change. Only 7% of employees agreed that the new weekend policy caused disruptions in day-to-day communications with colleagues and 6% agreed there was a negative effect on communication with vendors and other business entities. Overall majority of employees have been positively impacted with the changes and agreed that the flexible options have provided them with more work life balance and has not impacted their work productivity. However, employees have remained neutral on the increase of employee engagement since the policy update. This paper helps to give better insight on how flexible weekend options can improve employees work life balance and productivity by giving them the flexibility to choose their own work schedule based on their convenience.

OnePetro

doi: 10.2118/210876-MS

SPE

SPE-210876-MS

ADIPEC

Country: Asia > Middle East > UAE > Sharjah > Sharjah (0.63)

Genre:

Questionnaire & Opinion Survey (1.00)
Research Report > New Finding (0.34)

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

Oilfield Places: Asia > Middle East > UAE > Sharjah > Arabian Gulf > Ras al Khaimah Basin > Sharjah Field (0.89)

SPE Disciplines: Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility (0.78)

Technology: Information Technology > Communications (0.49)

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Impact of Diagenesis on the Reservoir Properties of the Cretaceous Kharaib Formation, Sajaa Field, Sharjah, United Arab Emirates

Phukan, Madhujya L (Schlumberger) | Siddiqi, Saad A (Schlumberger) | Almunaifi, Asma (Schlumberger) | Robert, Matthew J (Sharjah National Oil Corporation)

OnePetroOctober, 2022

Abstract The Early Cretaceous Kharaib Formation is one of the most prolific hydrocarbon bearing reservoirs in the Middle East. Based on sedimentary characteristics, the Kharaib Formation is divided into three main intervals/zones: the lower, middle and upper Kharaib. Interpretation of the depositional fabrics and prediction of reservoir parameters is often difficult due to the Kharaib Formation's diverse array of sedimentary characteristics. To address the considerable heterogeneity of the Kharaib Formation, this study investigates depositional characteristics and the diagenetic impact on reservoir quality within the Sajaa Field. The Kharaib Formation sediments were characterized using a Dunham/Embry & Klovan (1971) defined classification scheme. Analytical techniques via thin section analysis, scanning electron microscopy (SEM) and capillary pressure data were used to qualitatively and semi-quantitatively assess porosity and the diagenetic processes involved in its evolution. Key reservoir quality parameters for Kharaib intervals were defined by combining petrographic analysis and conventional core methods. The sedimentological characterization of the Kharaib sediments in the Sajaa Field showed a range of Orbitolina-bearing carbonate textures, which were interpreted as inner-ramp deposits. The stacking pattern of the depositional facies showed intermediate-order trends. The conventional core analysis measurements showed poor to good reservoir properties with porosity values of 0.7 – 23.2% and permeability values from negligible to 2 – 3 md. The pore system is dominated by grains and matrix-hosted micropores, which are primarily generated via diagenesis. Qualitative thin section analysis identified grain-hosted micropores as the most significant microporosity type, highlighting that grain-rich textures are relatively more porous compared to mud-rich textures. Diagenesis transformed both the matrix and various grain types (e.g., micritized grains, foraminifera etc.), generating considerable micropore volume. High resolution SEM imaging, along with semi-quantitative assessment, highlighted that diagenetic modification of the micritic sediments led to an abundance of sub-rounded to polyhedral crystals exhibiting primarily sub-punctic to punctic intercrystalline contacts that generated a porous fabric. Mercury injected capillary pressure (MICP) data, confirmed the abundance of micropores within the pore size distributions of studied samples. This study demonstrates the importance of considering textural variation within the Kharaib Formation when assessing the reservoir coupled with the fractured nature of the unit. The established microporosity-depositional relationships when combined with the updated core descriptions now allow for the integration of textural trend information in the field that can be applied to refine reservoir property and abundance distributions.

OnePetro

doi: 10.2118/211282-MS

SPE

SPE-211282-MS

ADIPEC

Country:

Asia > Middle East > Saudi Arabia (1.00)
Asia > Middle East > UAE > Sharjah > Sharjah (0.42)
Asia > Middle East > UAE > Sharjah > Arabian Gulf (0.41)

Genre:

Research Report > Experimental Study (0.87)
Research Report > New Finding (0.68)

Geologic Time: Phanerozoic > Mesozoic > Cretaceous > Lower Cretaceous (0.90)

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

Oilfield Places:

Asia > Middle East > UAE > Sharjah > Oman Mountains Foldbelt Basin > Sajaa Field > Thamama Group Formation (0.99)
Asia > Middle East > Saudi Arabia > Thamama Group > Kharaib Formation (0.99)
Asia > Middle East > Bahrain > Awali Field (0.99)
Asia > Middle East > Saudi Arabia > Thamama Group > Shu'aiba Formation (0.94)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Sedimentology (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)

Technology:

Information Technology > Information Management (0.88)
Information Technology > Artificial Intelligence > Machine Learning (0.88)

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Generation of a Regional Fluid Database for Gas Condensate Assets in a Thrusted Carbonate Environment of the Northern Emirates

Saradva, Harshil (Sharjah National Oil Corporation) | Golaco, Christna (Sharjah National Oil Corporation) | Robert, Matthew (Sharjah National Oil Corporation) | Jain, Siddharth (Sharjah National Oil Corporation) | Callum, Thurley (Sharjah National Oil Corporation) | Bentaher, Abdulhafid (Sharjah National Oil Corporation) | Al Hamadi, Masoud (Sharjah National Oil Corporation)

OnePetroOctober, 2022

Abstract Sharjah National Oil Corporation (SNOC) operates 4 onshore fields, the largest of which has been in production since the 1980's, in addition to over 50 years of exploration activity in the region. The producing fields exhibit a wide range of condensate-gas ratio (CGR) productivity and other properties. The scope of this paper is to discuss how the data from these exploration and development wells was combined to develop a trend of the fluid properties within the Northern Emirates to assist in the Future SNOC activities. A detailed data scouting and processing workflow was undertaken and all available legacy pressure-volume-temperature (PVT) reports were digitized. All available separator recombined samples reports and bottomhole sample reports were compiled into a master database. The well test reports were thoroughly examined to understand the field operations and determine the reliability of the PVT reports while the fluid samples were collected during the well tests. An equation of state was generated for each field using all available information taking into account their production history over 30+ years and the results were then used for the regional PVT study. A distinct trend of CGRs, specific gravity and other reservoir fluid properties were observed which co-related with the formations. These prospects which are spread out all over the Emirate of Sharjah were compared on the same parameters to develop a regional guideline. A regional trend of changing fluid properties was also observed which helps define the fluid properties expected in the Thamama Group formations in the Northern Emirates from any exploration well. The results will assist in determining the valuation of any exploration prospect if it is deemed successful and also plan ahead for the value of the prize. These trends also helped fill in missing data and perform quality control (QC) on older fields where comprehensive lab data was unavailable. In some cases, gas condensate fluid properties were unattainable at the mature stage of the field and this study provided the necessary information to plan enhanced recovery opportunities. This paper aims to be a leading reference for the PVT fluid properties in the complex Thamama Group of the Northern Emirates to support future exploration and development activities. The regional data provides a strong correlation and this information is novel in terms of utilizing legacy data for potential opportunities. The new database also helps QC the dataset of existing PVT reports along with aiding in identifying the sources of hydrocarbon origin in this region.

OnePetro

doi: 10.2118/211363-MS

SPE

SPE-211363-MS

ADIPEC

Country: Asia > Middle East > UAE > Sharjah > Sharjah (0.46)

Geologic Time: Phanerozoic > Mesozoic > Cretaceous (0.69)

Geophysics: Geophysics > Seismic Surveying (0.68)

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

Oilfield Places:

Asia > Middle East > Saudi Arabia > Thamama Group Formation (0.99)
Asia > Middle East > Oman > Central Oman > South Oman Salt Basin > Nahr Umr Formation (0.98)
Asia > Middle East > UAE > Thamama Group > Shu'aiba Formation (0.94)
(8 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)

Technology:

Information Technology > Databases (0.34)
Information Technology > Data Science > Data Quality (0.34)

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Mature Field Revitalization: Extending Late Life of Mature Gas Condensate Wells by Modelling Complex Multilateral Wellbore Flow Dynamics and Validating Results With a Field Pilot

Saradva, Harshil (Sharjah National Oil Corporation SNOC) | Jain, Siddharth (Sharjah National Oil Corporation SNOC) | Golaco, Christna (Sharjah National Oil Corporation SNOC) | Guillen, Armando (Sharjah National Oil Corporation SNOC) | Thakur, Kapil Kumar (Schlumberger)

OnePetroNovember, 2021

Abstract Sharjah National Oil Corporation (SNOC) operates 4 onshore fields the largest of which has been in production since the 1980's. The majority of wells in the biggest field have a complex network of multilaterals drilled using an underbalanced coiled tubing technique for production enhancement in early 2000s. The scope of this project was to maximize the productivity from these wells in the late life by modelling the dynamic flow behaviour in a simulator and putting that theory to the test by recompleting the wells. A comprehensive multilateral wellbore flow study was undertaken using dynamic multiphase flow simulator to predict the expected improvement in well deliverability of these mature wells, each having 4-6 laterals (Saradva et al. 2019). The well laterals have openhole fishbone completions with one parent lateral having subsequent numerous sub-laterals reaching further into the reservoir with each lateral between 500-2000ft drilled to maximize the intersection with fractures. Complexity in simulation further increased due to complex geology, compositional simulation, condensate banking and liquid loading with the reservoir pressure less than 10% of original. The theory that increasing wellbore diameter by removing the tubing reduces frictional pressure loss was put to test on 2 pilot wells in the 2020-21 workover campaign. The results obtained from the simulator and the actual production increment in the well aligned within 10% accuracy. A production gain of 20-30% was observed on both the wells and results are part of a dynamic simulation predicting well performance over their remaining life. Given the uncertainties in the current PVT, lateral contribution and the fluid production ratios, a broad range sensitivity was performed to ensure a wide range of applicability of the study. This instils confidence in the multiphase transient simulator for subsurface modelling and the workflow will now be used to expand the applicability to other well candidates on a field level. This will result in the opportunity to maximize the production and net revenues from these gas wells by reducing the impact of liquid loading. This paper discusses the detailed comparison of the actual well behaviour with the simulation outcomes which are counterproductive to the conventional gas well development theory of utilizing velocity strings to reduce liquid loading. Two key outcomes from the project are observed, the first is that liquid loading in multilaterals is successfully modelled in a dynamic multiphase transient simulator instead of a typical nodal analysis package, all validated from a field pilot. The second is the alternative to the conventional theory of using smaller tubing sizes to alleviate gas wells liquid loading, that high velocity achieved through wellhead compression would allow higher productivity than a velocity string in low pressure late life gas condensate wells.

OnePetro

doi: 10.2118/207501-MS

SPE

SPE-207501-MS

Abu Dhabi International Petroleum Exhibition & Conference

abu dhabi international petroleum exhibition, artificial lift system, complex multilateral wellbore flow dynamic, complex reservoir, Directional Drilling, drilling operation, gas Well Deliquification, international petroleum exhibition & conference, lateral, liquid loading, mature field revitalization, mature gas condensate well, Modeling & Simulation, Petroleum Engineer, production history, recompletion, transient simulator, Upstream Oil & Gas, wellhead temperature

Country:

Europe > United Kingdom > North Sea > Central North Sea (0.61)
Asia > Middle East > UAE > Sharjah > Sharjah (0.26)

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

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Completion > Completion Installation and Operations (1.00)
Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
Production and Well Operations > Artificial Lift Systems > Gas well deliquification (1.00)

Technology: Information Technology > Modeling & Simulation (0.67)

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Generating Value from Mature Gas Fields by Quantifying Well Integrity Assurance with a Critical Analysis of Multiple Logs & Retrieved Tubular Surface Inspection

Golaco, Christna (Sharjah National Oil Corporation) | Jain, Siddharth (Sharjah National Oil Corporation) | Obaid, Shams (Sharjah National Oil Corporation) | Al Nakeeb, Faisal (Sharjah National Oil Corporation)

OnePetroNovember, 2021

Abstract Sharjah National Oil Corporation (SNOC) operates 4 onshore gas condensate reservoirs of which 3 are very mature consisting of 50+ wells producing corrosive hydrocarbons for over 30 years. The integrity of these legacy wells is frequently questioned before any development is conceptualized, thus making it critical to evaluate the well integrity. The cost associated with pulling completions for their evaluation and running logs in all wells is significant and the availability of various emerging technologies for corrosion analysis in the market makes it challenging to choose the most reliable one. This paper focuses on the detailed analysis and comparison of electromagnetic thickness logs run in 10% of the well stock from 2016 to post-workover surface inspection of the downhole recovered tubing's in 2020/21. It also quantifies how correlating different logging technologies for well integrity increases the reliability of the electromagnetic technology applied on offset wells. The paper also showcases a comparison between mechanical and electromagnetic thickness evaluation of the production casing in-situ. Data from all the available logs from past 5 years was compiled for 6 wells. On recovery of the downhole completion tubings via a hydraulic workover, an ultrasonic (UT) inspection was performed on them at surface. Both sets of results (logs and surface inspection) were analyzed on the same logging track to give a comprehensive comparison of actual observation on surface vs the measurement by in-situ logging. Another multi-barrier corrosion and caliper log were run in the production casing to analyze their outcomes alongside older results. The final step was a comparison of all available data to create a broad well integrity profile. It was observed that the remaining production tubing metal thickness detected by electromagnetic tool (logs) and surface ultrasonic measurements were in good conformance (+/-10%). In the corrosion evaluation of the production casing, the electromagnetic tool matched extremely well with the caliper log results. This shows a large reliability of this technology to quantify corrosion in offset wells. The correlation of logs with surface inspection results across wells in the same reservoir did not indicate a strong presence of external corrosion. The study enables the management to make critical business decisions on utilizing the well stock for the future. This work is the first time a comprehensive and critical analysis on the electromagnetic thickness logging technology has been done, comparing their results of remaining wall thickness to various technologies in-situ and on surface. The analysis not only compares technology from various providers, but also mechanical vs electromagnetic measurements along with their respective advantages in quantifying well integrity assurance. The paper also gives an idea on the condition of L-80 tubulars under service for 30+ years.

OnePetro

doi: 10.2118/208204-MS

SPE

SPE-208204-MS

Abu Dhabi International Petroleum Exhibition & Conference

Country: Asia > Middle East > UAE > Sharjah > Sharjah (0.25)

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

Oilfield Places: Asia > Middle East > Saudi Arabia > Thamama Group Formation (0.98)

SPE Disciplines:

Well Drilling > Casing and Cementing > Casing design (1.00)
Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
(3 more...)

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Microporosity of the Shuaiba Formation: The Link Between Depositional Character and Diagenesis in Sharjah, United Arab Emirates

Phukan, Madhujya L (Schlumberger) | Siddiqi, Saad A (Schlumberger) | Robert, Matthew J (Sharjah National Oil Corporation)

OnePetroNovember, 2021

Abstract Objectives/Scope This study focuses on assessing the uncertainties related to sedimentological heterogeneity and the diagenetic variability within the gas-condensate reservoirs of the Shuaiba Formation, Sharjah, United Arab Emirates. Methods, Procedures, Process For characterizing the sedimentology of the Shuaiba Formation, a lithofacies scheme has been developed on the basis of Dunham's (1962) and Embry & Klovan classification (1971). The lithofacies are grouped on the basis of their genetic relationships which also correspond to their depositional environment, and are designated as lithofacies associations. A pore-scale fabric/textural investigation was completed using conventional thin-section microscopy and Scanning Electron Microscopy (SEM). Results, Observations, Conclusions The Shuaiba sediments are characterized by skeletal-rich wackestone/packstones to floatstones deposited in an inner ramp setting. The stacking pattern of the inner ramp deposits define broad third order trends observed across the studied field.These trends are relatable to the regional sequence stratigraphic framework of Sharland et al. (2001). In higher order sequences, lateral variations in lithology occur, defining the reservoir heterogeneity, which are most likely forced by topographic/hydrodynamic variation as well as sea level changes. Reservoir quality distribution is controlled by various factors, including the depositional texture and allochem assemblage (abundance, type, and size). Diagenetic alteration of the textures played an important role in determining overall reservoir quality. The pore enhancing phases are defined by dissolution events, where later stage dissolution was the dominant phase to enhance micropores and also to create meso- to macropores which partially to completely negated the effect of previous cementing phases. In these Shuaiba deposits, the porosity comprises common matrix-hosted as well as grain-hosted micropores along with variably distributed intraparticle and rare mouldic meso- to macropores. The measured porosity ranges from very poor to moderate (0.5-17%) while permeability is very low to low (<0.001-1.49 mD). The detailed petrographic analysis highlighted that changes in micritic fabric shows a variation in the reservoir properties. From SEM observations, it was noted that microcrystalline calcite crystals of polyhedral to sub-rounded morphologies with intercrystalline contacts ranging from facial to sub-punctic, which display relatively a good microporosity developement, whereas crystals that show anhedral compact character with coalescent/fused intercrystalline contacts are rarely associated with any microporosity. Novel/Additive Information In addition to SEM characterization, porosity data and elastic properties (e.g., Young's moduli) generated from the interpretation of the well-log data, were used to investigate the prospective relationship between the microporous carbonates and elastic properties. The comparisons highlight that an increase in porosity values results in a decrease of Young's moduli values, thereby reflecting a decrease in the stiffness of the rock. On the other hand, the increase in porosity maybe linked to the evolution of anhedral, compact, micritic fabric to polyhedral/sub-rounded micritic fabric. The understanding of this relationship provides a powerful tool to be utilized in reservoir architecture prediction based on integrating the sedimentological framework and diagenetic overprint.

OnePetro

doi: 10.2118/207786-MS

SPE

SPE-207786-MS

Abu Dhabi International Petroleum Exhibition & Conference

Country: Asia > Middle East > UAE > Sharjah > Sharjah (0.62)

Genre: Research Report (0.48)

Geologic Time: Phanerozoic > Mesozoic > Cretaceous > Lower Cretaceous (0.95)

Geophysics: Geophysics > Seismic Surveying (0.46)

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

Oilfield Places:

Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5604/29 > South Arne Field (0.99)
Asia > Middle East > UAE > Thamama Group > Shu'aiba Formation (0.99)
Asia > Middle East > UAE > Sharjah > Oman Mountains Foldbelt Basin > Sajaa Field > Thamama Group Formation (0.99)
(3 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Characterization > Sedimentology (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)

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Technology Focus: Mature Fields and Well Revitalization (January 2023)

Siddharth Jain

JPT Editorial Review Board

Multi-Field Integrated Rock Type Framework Optimisation in Thrusted Carbonates of The Thamama Group to Reduce Modelling Uncertainty and Improve Reservoir Characterisation

Enhancing Employee Morale by Providing Felxible Workweek Options: A Success Story in Sharjah

Impact of Diagenesis on the Reservoir Properties of the Cretaceous Kharaib Formation, Sajaa Field, Sharjah, United Arab Emirates

Generation of a Regional Fluid Database for Gas Condensate Assets in a Thrusted Carbonate Environment of the Northern Emirates

Mature Field Revitalization: Extending Late Life of Mature Gas Condensate Wells by Modelling Complex Multilateral Wellbore Flow Dynamics and Validating Results With a Field Pilot

Generating Value from Mature Gas Fields by Quantifying Well Integrity Assurance with a Critical Analysis of Multiple Logs & Retrieved Tubular Surface Inspection

Microporosity of the Shuaiba Formation: The Link Between Depositional Character and Diagenesis in Sharjah, United Arab Emirates

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Sharjah