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Collaborating Authors
Matar, Saad
A Success Story of Detecting the Source of Gas Leak in Annulus-B Using Total Well Integrity Tools and the Remedial Action in an Oil Well of Kuwait Oil Company
Matar, Saad (Kuwait Oil Company) | Jalan, Shiv (Kuwait Oil Company) | Ali, Yousef (Kuwait Oil Company) | Alshammari, Ahmad (Kuwait Oil Company) | Al-Ajmi, Eiman (Kuwait Oil Company) | Aparicio, Ciro (BP - British Petroleum) | Gobran, Mahmoud (Senergy Oilfield Solutions) | Saleh, Arafat (Senergy Oilfield Solutions) | Prosvirkin, Sergey (TGT Diagnostics) | Vishnu, Raveen (TGT Diagnostics)
Abstract Objectives/Scope Well integrity monitoring is one of the critical processes in oil and gas wells to prevent unintended fluid movement or loss of containment to the environment. In this case study, there was continuous gas leakage to surface at high pressure through annulus "B" of an oil well in East Kuwait area. The detection and securing of the gas leak in this well was essential not only for securing the well and restoring production, but also for environmental considerations due to the sensitive geographical location. This paper presents an innovative logging combination for total well integrity assessment, including spectral noise, high-resolution temperature, multi-barrier corrosion evaluation, and fluid type identification for downhole gas leak detection. The paper also presents remedial actions taken to secure well integrity after assessing and evaluating diagnostic logs at each stage with a workover rig. Methods, Procedures, Process Innovative combination of different measurements for total well integrity assessment including spectral noise, high-resolution temperature, multi-barrier corrosion evaluation, and fluid type identification logs have been used to detect the downhole source(s) of this gas leak. Multiple cement squeezing across single and multiple casings were designed and performed based on the logging results to stop the leak and secure the well. After completing each cement squeezing job, surface pressure in annulus "B" was being monitored and downhole logging surveys were being performed to check if there was still downhole gas flow. Results, Observations, Conclusions The different logging results showed strong indications for multiple sources of this gas flow in annulus "B" across different formations around the well. The poor primary cementing job allowed formation fluids (e.g. gas, oil and water) to migrate to shallow reservoirs and surface. The remedial cement squeezing jobs have been successfully performed and achieved a solid hydraulic vertical barrier to stop the gas flow activity. The gas flow stopped, surface pressure in annulus "B" disappeared and restored production of 700 bopd from the well. It is a case story of a successful well integrity workover in a very challenging well that ended by fixing the gas leak, restoring the well production, protecting the surrounding wells and environment, and saving the cost of either sidetracking the well or P&A (plug and abandonment). Novel/Additive Information The innovative well integrity logs in combination with conventional cementing remedial jobs, allowed us to achieve complete well integrity. The use of advanced well integrity logs (e.g. spectral noise, high-resolution temperature, multi-barrier corrosion evaluation, and fluid type identification) were beneficial to determine the exact depths of the leak points and determine the exact location of the remedial jobs (e.g. remedial cement jobs) to stop the migration of gas from the formation to shallow reservoirs and surface.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Kuwait Government (0.41)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (0.92)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (0.89)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.78)
- Well Drilling > Wellbore Design > Wellbore integrity (0.69)
Data Analytics into Hydraulic Modelling for Better Understanding of Well/Surface Network Limits, Proactively Identify Challenges and, Provide Solutions for Improved System Performance in the Greater Burgan Field
Dashti, Qasem (Kuwait Oil Company) | Matar, Saad (Kuwait Oil Company) | Abdulrazzaq, Hanan (Kuwait Oil Company) | Al-Shammari, Nouf (Kuwait Oil Company) | Franco, Francy (Schlumberger) | Haryanto, Elin (Schlumberger) | Zhang, Michael Q. (Schlumberger) | Prakash, Roshan (Schlumberger) | Bolanos, Nelson (Schlumberger) | Ibrahim, Muhammad (Schlumberger) | Afifi, Mostafa (Schlumberger)
A network modeling campaign for 15 surface gathering centers involving more than 1800 completion strings has helped to lay out different risks on the existing surface pipeline network facility and improved the screening of different business and action plans for the South East Kuwait (SEK) asset of Kuwait Oil Company. Well and network hydraulic models were created and calibrated to support engineers from field development, planning, and operations teams in evaluating the hydraulics of the production system for the identification of flow assurance problems and system optimization opportunities. Steady-state hydraulic models allowed the analysis of the integrated wells and surface network under multiple operational scenarios, providing an important input to improve the planning and decision-making process. The focus of this study was not only in obtaining an accurate representation of the physical dimension of well and surface network elements, but also in creating a tool that includes standard analytical workflows able to evaluate wells and surface network behavior, thus useful to provide insightful predictive capability and answering the business needs on maintaining oil production and controlling unwanted fluids such as water and gas. For this reason, the model needs to be flexible enough in covering different network operating conditions. With the hydraulic models, the evaluation and diagnosis of the asset for operational problems at well and network level will be faster and more effective, providing reliable solutions in the short-and long-terms. The hydraulic models enable engineers to investigate multiple scenarios to identify constraints and improve the operations performance and the planning process in SEK, with a focus on optimal operational parameters to establish effective wells drawdown, evaluation of artificial lifting requirements, optimal well segregation on gathering centers headers, identification of flow assurance problems and supporting production forecasts to ensure effective production management. 2 SPE-207512-MS
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Wara Formation (0.99)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Field > Wara Formation (0.99)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Field > Ratawi Formation (0.99)
- (14 more...)
Application of Multistage Acid Fracturing to Stimulate Mishref Carbonate Formation: Case Study, Minagish Field, West Kuwait
Mofti, Mohamed (Halliburton) | Sierra, Leopoldo (Halliburton) | Alboueshi, Alaeldin Saad (Halliburton) | Hadi Al-Azmi, Nasser (Kuwait Oil Company) | Matar, Saad (Kuwait Oil Company) | Abu-Eida, Abdullah (Kuwait Oil Company) | Patra, Milan (Kuwait Oil Company)
Abstract In recent years, field development strategies have begun to prioritize horizontal well technology over vertical and deviated wells because of the advantages of maximized reservoir contact, higher production rates, and better access to available hydrocarbon reserves. Some of the horizontal wells completed with openhole wellbores in carbonate formations are actually stable and good producers when the reservoir permeability is sufficiently high to not require a large or complicated stimulation treatment. If the permeability is low (i.e., less than 10 mD), as in most cases, this type of completion challenges any type of acid stimulation because of the well architecture and resulting poor distribution of the stimulation fluid over the entire lateral section. The Mishref reservoir of the Minagish field, located in western Kuwait, is a tight carbonate formation with poor reservoir quality and relatively low reservoir pressure; it was completed conventionally with openhole wellbores. The acid stimulation treatments performed in this area that showed positive results led to the selection of a multistage acid fracture stimulation of shorter horizontal wells. To enhance production in this field, the lateral length of the horizontal wells has been increased; the increased length, however, has also increased the challenges associated with proper stimulations if these issues are not considered during the completion stages of the wells. To maximize and sustain hydrocarbon production in long horizontal open holes, a multistage acid fracturing stimulation is still required if selective tools are used to complete the openhole section. The selective completion tools enable the mechanical segmentation of the annular space of the wellbore by dividing it into the required small isolated intervals based on petrophysical and reservoir properties. The isolated sections can be selectively stimulated to maximize the productivity in one continuous intervention. This paper summarizes the design processes, stimulation challenges, production response, and lessons learned from one multistage acid fracturing stimulation performed on a well drilled and completed in the Mishref reservoir of the Minagish field. In this well, the entire 1,800-ft length of the openhole lateral was divided into seven isolated stages by using swell packers and sliding sleeves. Because of the architecture and nature of the wellbore and the requirement to generate long fractures to properly drain the reservoir, the isolated compartment length (distance from the swell packers isolating the stage) was reduced to an average of 106 ft, and a sliding sleeve was placed in the middle of isolated sections. The paper documents the pilot multistage acid fracturing treatment on this type of completion; it also demonstrates the success of the stimulation in that the outcome exceeds the expected production increase, resulting in a more sustained production, as compared with the offset wells.
- North America > United States (1.00)
- Asia > Middle East > Kuwait > Jahra Governorate (0.81)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Alberta Basin > Sierra Field (0.93)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Sargelu Formation (0.93)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Najmah Formation (0.93)
- (11 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Acidizing (1.00)
First Implementation of High-Rate Pinpoint Technology in an Extremely Challenging Multilateral Well: Successful Lessons Learned From Tight Carbonate - Minagish Field, West Kuwait
Mofti, Mohamed (Halliburton) | Sierra, Leopoldo (Halliburton) | Alboueshi, Alaeldin Saad (Halliburton) | Patra, Milan (Kuwait Oil Company) | Ali, Sulaiman (Kuwait Oil Company) | Abu-Eida, Abdullah (Kuwait Oil Company) | Matar, Saad (Kuwait Oil Company) | Al-Shemali, Nasser (Kuwait Oil Company) | Al-Azmi, Nasser (Kuwait Oil Company)
Abstract A significant challenge in the tight Mishrif oil reservoir of the Minagish field is ensuring hydrocarbon flow through the complex and highly damage-susceptible carbonate intervals. In recent years, field development strategies have begun to prioritize multilateral well technology over vertical and deviated wells because of the advantages of maximized reservoir contact, higher production rates, and improved access to reserves (hydrocarbon in place). The downside of most unconventional multilateral wells is that laterals are open hole, completed with much complexity, and pose challenges for effective acid stimulation because of poor acid distribution over the long interval. The Mishrif formation in the Minagish field in west Kuwait is a challenging tight carbonate with poor reservoir quality, relatively low pressure, and no external pressure support. The stimulation methodology was highly modified as fit-for-purpose to address the unique challenges of multilateral well operations, formation technical difficulties, high-stakes economics, and untapped potential from these formations. Furthermore, to enhance production, the lateral lengths of the well were designed as an optimum solution. To maximize and sustain hydrocarbon flow and production, a multiple stage acid pinpoint treatment was performed by dividing the wellbore into small intervals, based on petrophysical and reservoir properties evaluations; a high-rate pinpoint technique was used for both laterals individually. The selected sections were individually acid stimulated, and the inflow contribution from the entire productive sections of both laterals was maximized with a highly reliable and effective multistage continuous operation. The post-operation well test and production data show a significant production increase; long-term production data show a sustained production increase, stable pump intake pressure, and low water cut, demonstrating the success of the pinpoint technique as an optimized solution for the first multilateral well. The success of this well stimulation method has enabled the use of this pinpoint-squeeze as the best technique for all horizontal wells in this field. This paper summarizes the design processes, challenges encountered, production response, and lessons learned from applying this pinpoint acidizing technique. It can be considered as a potential approach for addressing stimulation challenges in similar tight carbonate reservoir conditions in other fields.
- North America > United States > Texas (1.00)
- Asia > Middle East > Kuwait > Jahra Governorate (0.81)
- Asia > Middle East > Qatar > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > Block 6 > Al Khalij Field > Mishrif Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Najmah Formation (0.99)
- (10 more...)
Multidisciplinary Data Integration for Predicting Tarmat and Heavy Oil in Minagish Field, Kuwait
El Gezeery, Taher (KOC) | Halawa, Youssef (KOC) | Al Rashidi, Mohamed (KOC) | El Jeaan, Mounirah (KOC) | Matar, Saad (KOC) | Padhy, Girija Shankar (KOC) | Kasaraneni, Pruthviraj (KOC) | Al-Rashidi, Tahani (KOC)
Abstract This paper presents a multidisciplinary data integration in order to predict tarmat and heavy oil in Minagish Field. Techniques to detect tarmat are divided into those using logs and those which analyse the composition of oils such as Iatroscan geochemical technique; the later is very useful in detecting tarmat because of the remarkable difference in composition of oils in tarmat compared with the overlying reservoir. The second technique used is the pyrolysis method which detects mobile (Sr+S2a+S2b) and immobile (residual carbon RC) hydrocarbons along with TOC. It aids in identifying the nature of hydrocarbons within the pore structure defined by petrographic studies using polarized microscope and SEM. The samples were screened and analyzed using Rock Eval-reservoir methods in order to identify heavy and light hydrocarbon zones. The pyrolysis results show that there are many intervals of heavier oil intercalated with lighter oil ones. The previous studies of Minagish oil showed that this reservoir is richest in heavy polar compounds (26%) compared to other cretaceous reservoirs in Kuwait. Using the above methods, a new model is conceived with a clear variation in oil homogeneity vertically as well as laterally within the reservoir. In addition to that, faults and biodegradation near the water zone played their role in increasing density of oil and forming heavy oil in the reservoir. Application of magnetic resonance image and chemostratigraphic data are found effective in identifying heavier oil, light hydrocarbons and tarmat in real time mode. The chemostratigraphic interpretation draws certain depositional and/or diagenetic facies with definite elemental signatures. High P and P/Mn ratios are associated with oolite grainstones lithology that have high initial porosities and higher tar content. Also, tarmat is recognized by highly elevated values of Ni, V and S. This study led successfully to explain the production of an incremental volume of heavy oil trapped behind the injector in northeast area of the field.
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.94)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Najmah Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Minagish Field > Marrat Formation > Upper Marrat Formation > Marrat "C" Formation (0.99)
- (33 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- (4 more...)
Role of Geochemistry and Real-Time Advanced Gas Interpretation in Development Strategies of Depleted Reservoirs
El Gezeery, Taher Mohamed (Kuwait Oil Company) | Halawa, Youssef Ahmed (Kuwait Oil Company) | AL Shemali, Nasser (Kuwait Oil Company) | Al Rashidi, Mohamed (Kuwait Oil Company) | Matar, Saad (Kuwait Oil Company) | Ismael, Aziz (Kuwait Oil Company) | Silambuchlvan, Jeevan (Kuwait Oil Company) | Al-Rashidi, Tahani (Kuwait Oil Company)
Abstract The Minagish Oolite is one of the main reservoirs in the Minagish Field, Southwest Kuwait. The field is a large 4-way dip closure anticline structure, covering an area of about 90 square kilometers and with around 900feet of carbonates of the Minagish formation. The Middle Minagish member is the main reservoir, consisting of oolitic limestone with high permeability in the range of 10 to 1000 mD. The Lower Minagish member contains dense fine grained wackestones to packstones with low permeability. The Middle Minagish and Lower Minagish oil reservoirs contain highly undersaturated oil with API gravities of 28-34 ยฐAPI and share a common FWL at 9950feet TVDSS. The dynamic model built along with time lapsed historical (production/injection) and well surveillance (PLT, TDT, well test) data are used for tracking the movement of injected water and gas, monitoring fluid contacts and changes in saturation with time, optimizing production and planning of new wells. Nonetheless, due high density of producers existing around the field causes mutual interference amongst the neighboring wells and surprises arise while drilling new wells. Real-time Geochemical analysis on elemental and mineral concentrations within drill cuttings/core chips, integrated with advanced mud gas data, can provide an additional analytical dataset to assess reservoir depletion and water encroachment. This advanced surface logging technology can give a better indication on water bearing zones and water encroachment when MWD/WL logs have resolution issues. When geochemical and mud gas proxies are integrated with other data sets (viz. logs, and dynamic data), they provide a better control on lithological changes and water bearing zones, throughout the entire reservoir. Integrated geochemical and advance mud gas analysis in depleted Minagish reservoir has helped to confirm zones of interest and to determine leading edge of water aquifer. Ultimately this enabled for a unique completion design. The well MN-X, object of the study, represents a valuable case where it has been possible to identify water encroachment through geochemical proxies, aiding the completion strategy.
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.56)
- Asia > Middle East > Saudi Arabia > Saudi Arabia - Kuwait Neutral Zone ("Partitioned Zone") > Arabian Basin > Widyan Basin > Wafra Joint Operations Block > Wafra Field (0.99)
- Asia > Middle East > Kuwait > Saudi Arabia - Kuwait Neutral Zone ("Partitioned Zone") > Arabian Basin > Widyan Basin > Wafra Joint Operations Block > Wafra Field (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Upper Burgan Formation (0.99)
- (16 more...)
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Mud logging / surface measurements (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (2 more...)
Integrating Seismic Elastic Properties with Geological Data to Explore New Opportunities to Maximize Production of Wara Sand Reservoir in Minagish Field, WK
Ebaid, Adel (Kuwait Oil Company) | Gezeeri, Taher (Kuwait Oil Company) | Al-Haddad, Mohammed (Kuwait Oil Company) | Halawa, Youssif (Kuwait Oil Company) | Matar, Saad (Kuwait Oil Company)
Abstract The Middle cretaceous Wara sandstone reservoir in Minagish Field is considered as highly heterogenetic sandstone which implying lateral facies extensive variations, stacked sand bodies with varying petrophysical properties. Several horizontal wells has been successfully drilled in lower part of Wara 6 sand channel, best thicker clean sand channel with very good oil production rate. Recently some wells have shown depleting of oil and increase water production. To develop such a challenging reservoir to maximize the oil production, a new plan has been developed to explore for new opportunities in Wara reservoir. The objective is to target different good stacked sand bodies in different Wara layers by drilling deviated wells. Some of old depleted Minagsih Oolite reservoir wells have shown good opportunities to sidetrack the wells into good Wara sand layers. This paper presents the integration between geostatistical models, well logs, well test results and different seismic elastic properties maps to identify best subsurface locations for drilling new deviated wells which combine the best quality sand bodies in different Wara layers. A few years ago geostatistical reservoir model along with core data and well log data were utilized to drill successful horizontal wells in W6 sand channels. However due to low resolution seismic data, Wara highly heterogonous lithology and uncertainty in geo-statistical model, it was challenging to continue identify good quality stacked sand bodies in different Wara layers without drilling unwanted silty sand or shale layers. Seismic inversion related elastic impedance data could discriminate between the good quality oil-bearing sand, shaly, and silty sandstones. Several old vertical wells that include good stacked sand bodies in different Wara layers; have been selected to validate the accuracy of elastic impedance maps along Wara layers.
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous > Cenomanian (0.48)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous > Turonian (0.34)
- Phanerozoic > Mesozoic > Cretaceous > Lower Cretaceous > Albian (0.34)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.87)
- Asia > Middle East > Saudi Arabia > Saudi Arabia - Kuwait Neutral Zone ("Partitioned Zone") > Arabian Basin > Widyan Basin > Wafra Joint Operations Block > Wafra Field (0.99)
- Asia > Middle East > Kuwait > Saudi Arabia - Kuwait Neutral Zone ("Partitioned Zone") > Arabian Basin > Widyan Basin > Wafra Joint Operations Block > Wafra Field (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > South Minagish Field (0.99)
- (25 more...)
A Multi-disciplinary Integrated Approach To Understand The Potential Of The Najmah-Sargelu Reservoirs Of The Dharif and Abduliyah Fields (West Kuwait)
Matar, Saad (KOC) | Ray, Dipak Singha (KOC) | Abdulmalik, Ameena (KOC) | Mukherjee, Pritish (KOC) | Perfetti, Erwan (Beicip-Franlab) | Maux, Thierry Le (Beicip-Franlab)
Abstract The Najmah and Sargelu, two tight carbonate reservoirs of Jurassic age, are oil bearing in the West Kuwait fields Dharif and Abduliyah. Due to their complexity, presence of numerous natural fractures and low matrix porosity and permeability, these reservoirs have been underdeveloped in both fields. A multi-disciplinary integrated study has been performed to thoroughly investigate their potential and design the appropriate future development plans. This paper shows how the use of the 3D seismic data and the rock typing exercise has been maximized to constrain the derived models and reduce the uncertainties. The main reservoir horizons (top Najmah, top Sargelu and top Dharuma) have first been interpreted using the 3D seismic cube and major faults were picked on vertical seismic section and time slices. A seismic characterization work aimed at enhancing seismic data and better describing both matrix and fractures in between wells was also performed. The seismic fracture characterization study led to a set of seismic fracture index maps detailing the fault/fracture corridor network. The matrix characterization study provided an average shale proportion map in Najmah to guide the shaly facies proportions in the geological model. From the available well data, mainly core description and classical logs, a detailed sequence stratigraphy and petrophysical interpretations were performed. Electrofacies were then computed at wells before being propagated in 3D in a detailed geological model combining both fields. Finally analysis of the natural fracture network was made using multiple sources of data: core description for fractures, image logs interpretation, seismic maps, transient well tests, production data โฆ A Discreet Fracture Network (DFN) model was derived and then dynamically calibrated. The equivalent fracture properties (porosity, permeability and fracture spacing) were computed and imported into a dual porosity โ single permeability simulation model. Using the limited production and pressure data in both Dharif and Abduliayh fields, the dynamic models were adjusted to fit the production history: uncertain oil-water contacts depth were modified and small modifications of fractures properties in around one of the well was performed. The calibrated dynamic models were then used to test several development scenarios. Dharif potential, due to the presence of a thin oil column, was shown to be limited. Abduliyah potential, on the other hand, is likely to be greater if the fracture network is proved to be as permeable as in Dharif. If this is confirmed, a development with horizontal producers located at the crest of the structure is likely to be the most suited method.
- Geology > Structural Geology (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Geological Subdiscipline > Geomechanics (0.89)
- (2 more...)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Dharif Field > Marrat Formation > Upper Marrat Formation (0.94)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Dharif Field > Marrat Formation > Sargelu Formation (0.94)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Dharif Field > Marrat Formation > Najmah Formation (0.94)
- (3 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Faults and fracture characterization (1.00)
Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Physics
Dernaika, Moustafa (Ingrain Inc.) | Al Jallad, Osama (Ingrain Inc.) | Koronfol, Safouh (Ingrain Inc.) | Suhrer, Michael (Ingrain Inc.) | Teh, Woan Jing (Ingrain Inc.) | Walls, Joel (Ingrain Inc.) | Matar, Saad (Kuwait Oil Company) | Murthy, Natarajan (Kuwait Oil Company) | Zekraoui, Mohammed (Kuwait Oil Company)
Abstract The evaluation of unconventional formations is complicated by the structurally heterogeneous nature of fine-grained strata and their intricate pore networks, which are interdependent on many geologic factors including total organic carbon (TOC) content, mineralogy, maturity and grain-size. The low permeability of unconventional rocks requires massive hydraulic fracturing to enhance connectivity and increase permeability for the flow. To design an effective fracturing technique, it is necessary to have a good understanding of the reservoir characteristics and fluid flow properties at multiple scales. In this work, representative core plug samples from a tight carbonate source rock in the Middle East were characterized at the core- and pore-scale levels using a Digital Rock Physics (DRP) workflow. The tight nature of the carbonate rocks prevented the use of conventional methods in measuring special core analysis (SCAL) data. Two-dimensional Scanning Electron Microscopy (SEM) and three-dimensional Focused Ion Beam (FIB)-SEM analysis were studied to characterize the organic matter content in the samples together with (organic and inorganic) porosity and matrix permeability. The FIB-SEM images in 3D were also used to determine petrophysical and fluid flow (SCAL) properties in primary drainage and imbibition modes. A clear trend was observed between porosity and permeability related to identified rock fabrics and organic matter in the core. The organic matter was found to have an effect on the imbibition two-phase flow relative permeability and capillary pressure behavior and hysteresis trends among the analyzed samples. The data obtained from DRP provided information that can enhance the understanding of the pore systems and fluid flow properties in tight formations, which cannot be derived accurately using conventional methods.
- Europe (1.00)
- Asia > Middle East (1.00)
- North America > United States > Texas (0.68)
- North America > United States > Colorado (0.46)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.84)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.67)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.47)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)
Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Physics
Dernaika, Moustafa (Ingrain Inc.) | Jallad, Osama Al (Ingrain Inc.) | Koronfol, Safouh (Ingrain Inc.) | Suhrer, Michael (Ingrain Inc.) | Teh, Woan Jing (Ingrain Inc.) | Walls, Joel (Ingrain Inc.) | Matar, Saad (Kuwait Oil Company) | Murthy, Natarajan (Kuwait Oil Company) | Zekraoui, Mohammed (Kuwait Oil Company)
Abstract The evaluation of shale is complicated by the structurally heterogeneous nature of fine-grained strata and their intricate pore networks, which are interdependent on many geologic factors including total organic carbon (TOC) content, mineralogy, maturity and grain-size. The ultra-low permeability of the shale rock requires massive hydraulic fracturing to enhance connectivity and increase permeability for the flow. To design an effective fracturing technique, it is necessary to have a good understanding of the reservoir characteristics and fluid flow properties at multiple scales. In this work, representative core plug samples from a tight carbonate source rock in the Middle East were characterized at the core- and pore-scale levels using a Digital Rock Physics (DRP) workflow. The tight nature of the carbonate rocks prevented the use of conventional methods in measuring special core analysis (SCAL) data. Two-dimensional Scanning Electron Microscopy (SEM) and three-dimensional Focused Ion Beam (FIB)-SEM analysis were studied to characterize the organic matter content in the samples together with (organic and inorganic) porosity and matrix permeability. The FIB-SEM images in 3D were also used to determine petrophysical and fluid flow (SCAL) properties in primary drainage and imbibition modes. A clear trend was observed between porosity and permeability related to identified rock fabrics and organic matter in the core. The organic matter was found to have an effect on the imbibition two-phase flow relative permeability and capillary pressure behavior and hysteresis trends among the analyzed samples. The data obtained from DRP provided information that can enhance the understanding of the pore systems and fluid flow properties in tight formations, which cannot be derived accurately using conventional methods.
- Europe (1.00)
- North America > United States > Colorado (0.46)
- Asia > Middle East > UAE (0.28)
- Asia > Middle East > Saudi Arabia (0.28)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)