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Collaborating Authors
Al-Mutawa, Majdi
First Worldwide Implementation of 6-inch Slim Advanced Downhole Formation Tester in Challenging North Kuwait Deep Tight Jurassic Gas
Abdel-Basset, Mohamed (SLB) | Al-Ajmi, Saad (Kuwait Oil Company) | Al-Otaibi, Fahad (Kuwait Oil Company) | Al-Azmi, Mejbel (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Bloushi, Taha (Kuwait Oil Company) | Alajmi, Sarah (SLB) | Ayyad, Hazim (SLB) | Metwally, Mahmoud (SLB) | Kho, Djisan (SLB) | Murat Nohut, Omur (SLB)
Abstract The novel 6-inch slim Downhole Formation Tester (DFT) with its advanced Downhole Fluid Analyzer (DFA) sampling tool has been successfully implemented as first time ever worldwide in 6-inch open hole and as first time ever in Kuwait in Jurassic gas deep tight gas Middle Marrat carbonate reservoir. Downhole sampling was always being declined by the drilling team due to differential sticking risks associated with long sampling time using conventional downhole sampling tools in tight reservoirs. This paper will discuss the tool's first successful operation to overcome the formation evaluation and fluid sampling challenges and its immediate added value to subsequent completion and stimulation plan. The formation evaluation of North Kuwait Jurassic deep tight carbonate reservoirs is challenging due to the uncertainty of conventional log measurements and the oil-based mud filtrate (OBMF) invasion. The induction resistivity logging tool, which is based on formation conductivity, is known to have high uncertainty in this low conductivity environment. Deep oil base mud filtrate invasion is also expected and can be observed by comparing real-time logging while drilling (LWD) resistivity and Wireline (WL) resistivity logs. The deep invasion is caused by the slow mud cake building up due to the low formation permeability. The uncertainty in the water saturation computation is further complicated by the parameter's uncertainty of the water saturation (Sw) equation, i.e., variable cementation factor and the saturation exponent. The determination of free water level or the potential water zones cannot be easily determined from the log interpretation alone. In this case study, the high-definition NMR tool was run to detect the free oil, free water and the OBMF invasion volume by continuous T1-T2 mapping. Formation fluid sampling is also needed to confirm the fluid type to firm up the perforation interval. However, the formation pressure testing and fluid sampling in this field had been cancelled in most of the wells due to the operation risk. Low permeability, which requires longer stationary time and the high differential pressure due to the reservoir depletion need to be addressed properly to avoid the risk of the tool getting stuck. The slim advanced DFT tool design has smart hardware to enable rapid acquisition and automated capture of representative formation fluids in short time that reduces operational risk in challenging open hole environment. Once the presence of representative fluid has been verified, further analysis can be conducted by extensively profiling fluid properties with a suite of high-precision, high-accuracy measurements. The valves, gauges, and hundreds of other key system components have smart controls that are AI ready and can intercommunicate, enabling downhole automation of complex workflows. This ensures that data can be reliably integrated into the reservoir context in real time for quick, informed decision making. Many operational challenges were faced and overcome by multidisciplinary team integration. The success and demonstrated added value of first implementation encouraged plans for more implementations across other different assets. The sampling results confirmed mobile water and had immediate added value on the subsequent design of a multistage completion that was installed in the sampled well. The following testing results confirmed mobile water from the sampled interval. Results match the fluids computation by the high-definition Nuclear Magnetic Resonance (NMR) results. The advanced DFT platform can be a better option in terms of cost and operation time. This option used to be impossible in any tight reservoir until the novel 6-inch slim advanced DFT sampling tool was introduced to the industry.
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
North Kuwait Jurassic Gas Experience of Expanding Multistage Completion Strategy for Managing Deep Tight Gas Development Challenges
Abdel-Basset, Mohamed (SLB) | Al-Otaibi, Yousef (Kuwait Oil Company) | Bloushi, Taha (Kuwait Oil Company) | Al-Dhafiri, Anood (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Abdelbagi, Mamoun (SLB) | Hadi, Ahmed (Packers Plus)
Abstract North Kuwait Jurassic Gas asset has strategic importance for Kuwait production strategy as the only non-associated gas producing fields in Kuwait. This paper demonstrates the added value, experience, challenges and lessons learned of recent paradigm shift in Jurassic tight gas wells’ completion strategy from cemented liner to multistage completion. A successful expansion of Multi-Stage Completion (MSC) technology has been achieved on field level led by integrated team efforts since early 2020 to date. This helps to enhance overall well production potential, selective stimulation, overcome reservoir and intervention operations challenges, and early production delivery. The Jurassic gas asset produces mainly from deep high pressure and temperature, conventional and unconventional tight carbonate reservoirs. The recovery from such complex heterogeneous reservoirs is extremely challenging if conventional development strategies are applied. Due to the high reservoir tightness, permeability contrast among different flow units and dual permeability effect (matrix and natural fractures), well productivity potential significantly depends on the effectiveness of subsequent stimulation treatments of such complex heterogeneous reservoir to improve well productivity and connect the natural fractures. Selecting proper well completion is critical to overcome such reservoir challenges and ensure efficient acid stimulation treatments of such unconventional formations that need convenient diversion mechanism during the stimulation to enhance the productivity of each individual reservoir layer, and enable future flexibility of selective re-stimulation and reservoir management. The asset team has applied a step change in completion strategy to open-hole HPHT multistage drop-ball completions using state-of-the-art MSC technologies including closable frac ports, full 3.5in monobore post milling and debris sub to protect the MSC string during upper completion operations. This is to overcome such reservoir complexity, eliminate wellbore cleaning and multiple perforation intervention operations challenges and risks, eliminate cement quality uncertainties, improve overall cost, and fast track well delivery to production to meet asset production target by significantly reducing operation time from approximately one month of plug and perf technique to less than one week of continuous and less subsurface intervention operations. Total of 23 new Multi-stage completions were successfully installed in last 2 years including 4 systems in horizontal unconventional Najmah reservoir with overall good production results and significant improvement in selective acid stimulation (matrix and Fracturing), intervention operations efficiency and fast well delivery to production. Therefore, the asset plans to continue expansion in Multi-stage completion strategy. Based on gained experience, an integrated protocol for multi-stage candidate well selection, staging design and installation procedures workflow has been built by the integrated multidisciplinary team to ensure standard process across fields which can be used for application in other fields.
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
First Time in Kuwait: Successful Hybrid Multistage Completion Accelerates Production of Najmah Unconventional Jurassic Gas Reservoir
Abdel-Basset, Mohamed (Schlumberger) | Bloushi, Taha (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Al-Saeed, Abdulla (Kuwait Oil Company) | Al-Otaibi, Yousef (Kuwait Oil Company) | Hadi, Ahmed (Packers Plus)
Abstract North Kuwait Jurassic Gas asset development has strategic value of gas independency for Kuwait as it is the only non-associated gas producing asset. This paper will share the experience, added value, challenges and lessons learned from the successful implementation of first ever Hybrid 15k Multi-Stage Completion in Kuwait across Najma unconventional gas carbonate reservoir commingled with lower cemented liner completion in conventional Middle-Marrat tight carbonate reservoir. This completion configuration enables acceleration of selective stimulation and testing of Najma unconventional production potential in existing wells, and simultaneous comingled production from both reservoirs to maximize well production potential. The development of North Kuwait Jurassic deep unconventional gas carbonate reservoirs is key to compensate the production decline from conventional producing Middle-Marrat reservoir and to achieve the production target of Jurassic gas asset. The recovery from such unconventional reservoirs is extremely challenging if conventional development strategies are applied. Therefore, a dedicated full development plan applying integrated upstream and downstream technologies is important to achieve commercial production. The NK field development team has initiated a study to test the potential of unconventional Najmah formation in existing wells to evaluate the production potential and accelerate production from such reservoirs. The typical completion of Jurassic wells include Najmah reservoir in the 7-5/8″ cemented liner section followed by the Marrat reservoir completed in 5″ or 4.5″ cemented liner section. The multidisciplinary team efforts have yielded an innovative hybrid completion solution of 15K rated cased-hole ball-drop multistage completion across Najma reservoir layers and cemented liner across Middle-Marrat reservoir layers that allows selective commingled production of Middle-Marrat and Najmah with ensuring full selective stimulation potential across Najmah reservoirs through the multistage completion. Many completion design, operations and installation challenges were resolved to ensure mechanical isolation of lower depleted conventional reservoir before perforation the upper unconventional reservoir and running the multistage across it. This is to mitigate the challenges of high differential pressure of approximately 5,000 psi between the two reservoirs in completion phase to avoid high formation damage to the depleted Middle-Marrat lower reservoir plus well control during rig operation. This innovative hybrid completion has been installed successfully in one well as first time ever in Kuwait. Najmah and Middle Marrat reservoirs have been selectively stimulated and tested individually then commingled production from both reservoir as first time in Jurassic gas fields and Kuwait. PLT showed positive production contribution from Najma open frac ports and no cross flow among open reservoirs. There is a plan to expand such Hybrid completion to other candidates. This innovative completion configuration can be used in similar application for commingling production to minimize cost of new wells for different reservoirs.
Using Hybrid Geosteering to Proactively Position a Well in Fractured Tight Carbonate Jurrasic Rock – A Middle East Deep-Gas Reservoir Case Study
Al-Mutawa, Majdi (Kuwait Oil Company) | Bloushi, Taha (Kuwait Oil Company) | Al-Ajmi, Saad Abdullrahman Hassan (Kuwait Oil Company) | Al-Bader, Fahad Khned (Kuwait Oil Company) | Pattnaik, Chinmaya (Kuwait Oil Company) | Pasaribu, Ihsan Taufik (Schlumberger) | Keot, Chandan Jyoti (Schlumberger) | Osman, Salih Noreldin (Schlumberger) | Siam, Mahmoud (Schlumberger) | Basset, Mohamed Abdel (Schlumberger)
These challenges are due to the inherent very low porosity characteristics with an average 2 to 6% matrix porosity and 0.01 to 1.5 mD permeability. Natural fractures play a primary role in the producibility of these reservoirs. High angle well is being planned as a way to intersect as many fracture systems as possible for production improvement. To better visualize the subsurface structure while drilling, Ultra Deep reservoir mapping while drilling was deployed to map the whole reservoir boundaries in real time and know the formation dip and precise trajectory position from reservoir roof and base at any point in the lateral section. The 3D reservoir mapping gives precise geological geometry of the reservoir and enhances the placement of the well. The information from Reservoir Mapping While Drilling integrated to other downhole measurements such as Near bit Gamma Ray, Resistivity and the surface logging of gas composition and geo-chemical data could help immensely to determine the productive fracture zones. The foremost drilling challenge in deep Jurassic carbonates is exposure to high borehole temperature which can go up to 300 degF, due to high friction factor at depths of more than 12000 ft vertical depth from sub-sea (TVDSS), combined with high temperature gradient. This downhole high temperature environment almost reaching LWD tools maximum temperature thresholds, could potentially affect the LWD tools while drilling because of excessive fatigue to the electronics. This paper will discuss the case study of well placement challenges in deep Jurassic tight carbonate reservoirs and solutions to ensure of the success of the well operation and achieve well objectives.
- Europe (1.00)
- Asia > Middle East > Kuwait (0.48)
- Geology > Geological Subdiscipline > Stratigraphy (0.89)
- Geology > Rock Type > Sedimentary Rock (0.74)
- Geophysics > Borehole Geophysics (0.95)
- Geophysics > Seismic Surveying (0.90)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Upper Burgan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Mauddud Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Lower Burgan Formation (0.99)
- (3 more...)
North Kuwait Jurassic Gas Experience of Expanding Multistage Completion Strategy for Managing Deep Tight Gas Development Challenges
Abdel-Basset, Mohamed (Schlumberger) | Al-Otaibi, Yousef (Kuwait Oil Company) | Blushi, Taha (Kuwait Oil Company) | Al-Dhafiri, Anood (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Abdelbagi, Mamoun (Schlumberger) | Hadi, Ahmed (Packers Plus)
Abstract North Kuwait Jurassic Gas asset has strategic importance for Kuwait production strategy as the only non-associated gas producing fields in Kuwait. This paper demonstrates the added value, experience, challenges and lessons learned of recent paradigm shift in Jurassic tight gas wells’ completion strategy from cemented liner to multistage completion. A successful expansion of Multi-Stage Completion (MSC) technology has been achieved on field level led by integrated team efforts since early 2020 to date. This helps to enhance overall well production potential, selective stimulation, overcome reservoir and intervention operations challenges, and early production delivery. The Jurassic gas asset produces mainly from deep high pressure and temperature, conventional and unconventional tight carbonate reservoirs. The recovery from such complex heterogeneous reservoirs is extremely challenging if conventional development strategies are applied. Due to the high reservoir tightness, permeability contrast among different flow units and dual permeability effect (matrix and natural fractures), well productivity potential significantly depends on the effectiveness of subsequent stimulation treatments of such complex heterogeneous reservoir to improve well productivity and connect the natural fractures. Selecting proper well completion is critical to overcome such reservoir challenges and ensure efficient acid stimulation treatments of such unconventional formations that need convenient diversion mechanism during the stimulation to enhance the productivity of each individual reservoir layer, and enable future flexibility of selective re-stimulation and reservoir management. The asset team has applied a step change in completion strategy to open-hole HPHT multistage drop-ball completions using state-of-the-art MSC technologies including closable frac ports, full 3.5in monobore post milling and debris sub to protect the MSC string during upper completion operations. This is to overcome such reservoir complexity, eliminate wellbore cleaning and multiple perforation intervention operations challenges and risks, eliminate cement quality uncertainties, improve overall cost, and fast track well delivery to production to meet asset production target by significantly reducing operation time from approximately one month of plug and perf technique to less than one week of continuous and less subsurface intervention operations. Total of 23 new Multi-stage completions were successfully installed in last 2 years including 4 systems in horizontal unconventional Najmah reservoir with overall good production results and significant improvement in selective acid stimulation (matrix and Fracturing), intervention operations efficiency and fast well delivery to production. Therefore, the asset plans to continue expansion in Multi-stage completion strategy. Based on gained experience, an integrated protocol for multi-stage candidate well selection, staging design and installation procedures workflow has been built by the integrated multidisciplinary team to ensure standard process across fields which can be used for application in other fields.
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
First Worldwide Implementation of 6-Inch Slim Advanced Downhole Formation Tester in Challenging North Kuwait Deep Tight Jurassic Gas
Abdel-Basset, Mohamed (Schlumberger) | Al-Ajmi, Saad (Kuwait Oil Company) | Al-Otaibi, Fahad (Kuwait Oil Company) | Al-Azmi, Mejbel (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Bloushi, Taha (Kuwait Oil Company) | Alajmi, Sarah (Schlumberger) | Ayyad, Hazim (Schlumberger) | Metwally, Mahmoud (Schlumberger) | Kho, Djisan (Schlumberger) | Murat Nohut, Omur (Schlumberger)
Abstract The novel 6-inch slim Downhole Formation Tester (DFT) with its advanced Downhole Fluid Analyzer (DFA) sampling tool has been successfully implemented as first time ever worldwide in 6-inch open hole and as first time ever in Kuwait in Jurassic gas deep tight gas Middle Marrat carbonate reservoir. Downhole sampling was always being declined by the drilling team due to differential sticking risks associated with long sampling time using conventional downhole sampling tools in tight reservoirs. This paper will discuss the tool’s first successful operation to overcome the formation evaluation and fluid sampling challenges and its immediate added value to subsequent completion and stimulation plan. The formation evaluation of North Kuwait Jurassic deep tight carbonate reservoirs is challenging due to the uncertainty of conventional log measurements and the oil-based mud filtrate (OBMF) invasion. The induction resistivity logging tool, which is based on formation conductivity, is known to have high uncertainty in this low conductivity environment. Deep oil base mud filtrate invasion is also expected and can be observed by comparing real-time logging while drilling (LWD) resistivity and Wireline (WL) resistivity logs. The deep invasion is caused by the slow mud cake building up due to the low formation permeability. The uncertainty in the water saturation computation is further complicated by the parameter’s uncertainty of the water saturation (Sw) equation, i.e., variable cementation factor and the saturation exponent. The determination of free water level or the potential water zones cannot be easily determined from the log interpretation alone. In this case study, the high-definition NMR tool was run to detect the free oil, free water and the OBMF invasion volume by continuous T1-T2 mapping. Formation fluid sampling is also needed to confirm the fluid type to firm up the perforation interval. However, the formation pressure testing and fluid sampling in this field had been cancelled in most of the wells due to the operation risk. Low permeability, which requires longer stationary time and the high differential pressure due to the reservoir depletion need to be addressed properly to avoid the risk of the tool getting stuck. The slim advanced DFT tool design has smart hardware to enable rapid acquisition and automated capture of representative formation fluids in short time that reduces operational risk in challenging open hole environment. Once the presence of representative fluid has been verified, further analysis can be conducted by extensively profiling fluid properties with a suite of high-precision, high-accuracy measurements. The valves, gauges, and hundreds of other key system components have smart controls that are AI ready and can intercommunicate, enabling downhole automation of complex workflows. This ensures that data can be reliably integrated into the reservoir context in real time for quick, informed decision making. Many operational challenges were faced and overcome by multidisciplinary team integration. The success and demonstrated added value of first implementation encouraged plans for more implementations across other different assets. The sampling results confirmed mobile water and had immediate added value on the subsequent design of a multistage completion that was installed in the sampled well. The following testing results confirmed mobile water from the sampled interval. Results match the fluids computation by the high-definition Nuclear Magnetic Resonance (NMR) results. The advanced DFT platform can be a better option in terms of cost and operation time. This option used to be impossible in any tight reservoir until the novel 6-inch slim advanced DFT sampling tool was introduced to the industry.
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Un-Realize Application of LWD Multipole Sonic Tool for Evaluating Cement Quality: Optimizing the Well Operation in a Highly Deviated North Kuwait Deep Jurassic Well Case Study
Al-Mutawa, Majdi (Kuwait Oil Company) | Saffar, Ali Hussein (Kuwait Oil Company) | Al-Azmi, Mejbel Saad (Kuwait Oil Company) | Al-Otaibi, Fahad Barrak (Kuwait Oil Company) | Abdulmohsen, Naser Bader (Kuwait Oil Company) | Ragaey, Mohsen Mohammed (Kuwait Oil Company) | Kumar, Joshi Girija (Kuwait Oil Company) | Alomar, Abdulrahman Ahmad (Kuwait Oil Company) | Tiwary, Devendra Nath (Kuwait Oil Company) | Pasaribu, Ihsan Taufik (Schlumberger) | Al-Bannai, Khaled (Schlumberger) | Kho, Djisan (Schlumberger)
Abstract Cement quality is an important well integrity consideration to ensure proper hydraulic sealing. Traditionally, wireline cement bond logs have been used extensively in the Jurassic formation of North Kuwait. The case study well presented in this paper had an 80° inclination and 3,000 ft of a 6-in. open hole, which has remained opened for quite some time. Cement evaluation was required inside the 7 5/8-in liner to determine the cement quality behind the liner and integrity of liner shoe. This information is important for achieving a successful of multistage completion for the producing interval in the 6-in open hole. The target interval had a vertical depth greater than 14,000ft from mean-sea level with a well deviation more than 80°. Four operational days were required to run drill pipe conveyance of conventional cement evaluation wireline tools. This operation would have exposed the 2,500ft of open hole to potentially collapsing situation due to the time dependence of the wellbore stability. The capability of logging-while-drilling (LWD) multipole sonic tool for evaluating the cement quality was considered, as there was plan to acquire open hole log data using LWD technology, which included the LWD multipole sonic tool. While running in the hole to the open hole section, the LWD multipole sonic tool can acquire sonic-based cement evaluation data inside of the 7 5/8-in liner. This operating method consumes no rig time while obtaining the well integrity information. This paper presents the case study, along with the LWD multipole sonic tool theory for measuring cement bond quality index, operation preparation, and the results of the data acquisition.
- Asia > Middle East > Kuwait (0.72)
- North America > United States (0.69)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Paradigm Shift from Cemented Completions to Multi-Stage Completion Strategy for Managing Tight Gas Development Challenges
Abdel-Basset, Mohamed (Schlumberger) | Al-Otaibi, Yousef (Kuwait Oil Company) | Al-Saeed, Abdulla (Kuwait Oil Company) | Blushi, Taha (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Abdelbagi, Mamoun (Schlumberger) | Hadi, Ahmed (Packers Plus)
Abstract The development of North Kuwait Jurassic gas assets has strategic importance for Kuwait's production strategy as the only non-associated gas-producing field in Kuwait. This paper demonstrates the benefits, challenges and lessons learned of the recent paradigm shift in Jurassic tight gas wells’ completion strategy from cemented liner to multi-stage completion. Successful expansion of Multi-Stage Completion (MSC) technology is achieved at the field level led by the integrated team efforts in 2020/21, despite challenging constraints of COVID-19. MSC's help to enhance overall well production potential, overcome reservoir and intervention operation challenges, and allow early production delivery, which is a key factor to achieve a strategic asset production target of 70-80% by 2024/25. Many technical and logistic challenges were experienced during first installations of which the relevant learnings will be shared in this paper. The Jurassic gas asset produces mainly from deep high pressure and temperature, conventional and unconventional tight carbonate reservoirs. The recovery from such complex heterogeneous reservoirs is extremely challenging if conventional development strategies are applied. Therefore, a dedicated full development plan applying integrated upstream and downstream technologies is important to achieve the strategic production target. Due to the excessive Jurassic carbonate reservoir tightness, permeability contrast and dual permeability effect (matrix and natural fractures), well productivity potential significantly depends on the effectiveness of subsequent stimulation treatments of such complex heterogeneous reservoirs to improve well productivity and potentially connect with natural fractures. Selecting proper well completion design is critical to overcome such reservoir challenges and ensure effective acid stimulation treatments for the mix of conventional and unconventional formations that need convenient diversion mechanism during stimulation to enhance the productivity of each individual reservoir flow unit and enable selective future flexibility of re-stimulation and reservoir management. The asset team has recently applied a step change in completion strategy to open hole multi-stage ball drop completions using state of the art MSC technologies including closeable frac sleeves, full 3.5-in monobore ID post frac sleeves milling and debris sub enclosure to protect the MSC string during casing tie-back operations. This is to overcome reservoir complexity, eliminate wellbore cleaning and decrease the challenges and risks that accompany multiple perforation intervention operations. As well as, eliminate cement quality risks and uncertainties, improve overall cost, and fast track well delivery to production to meet asset production targets by significantly reducing operation time from approximately one month for plug and perf techniques to less than one week when using continuous and less subsurface intervention operations. Recently, a total of 13 new MSC installations and subsequent multi-stage stimulations were achieved in seven months, fromQ3-2020 to Q1-2021, with positive overall production results, significant improvement of intervention operation efficiency and faster well delivery to production. This paper will describe the details of progress to date, and the plan forward for optimization and new technology trials to further improve well performance.
- Asia > Middle East > Kuwait (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
A Field Applications of Effective Stimulation High Pressure/Temperature Multi-Stage Completion which Shows Significant Well Performance Improvement in Deep North Kuwait Jurassic Unconventional Reservoir
Al-Saeed, Abdullah (Kuwait Oil Company) | Al-Dhafiri, Anood (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Abdul Hadi, Ahmad (Packers Plus Energy Services Inc)
Abstract Selecting the completion design and stimulation technique in North Kuwait Jurassic Gas (NKJG) were critical to overcome reservoir challenges by stimulating these unconventional formations efficiently and effectively. Therefore, the completion design must be high-pressure rated upto 15,000 psi, high temperature of 275°F and sour service specified because of high H2S & CO2 content. These reservoirs are heterogeneous carbonate type with various productivity index due to existence of natural fracture which needs proper completion type that treat each reservoir layer separately. The most challenging factor in these unconventional reservoirs is the high permeability contrast among the different flow units because of the dual porosity effect which needs convenient diversion mechanism during the stimulation. The reservoir was segmented into different intervals to enhance the productivity index of each flow unit. For that reason, "High Rate Matrix Acidizing (HRMA)" method was obtained with retardard acid to restore the well productivity due to the drilling fluids which alter the effective permeability near the wellbore. By dividing each flow unit into separate stages across packer system and stimulate them subsequently is the aim to overcome high permeability contrast across the reservoir flow units. The Monobore Multi-stage was chosen as a completion type to produce from different zone of interest. These Reservoirs are divided into different stages and acid treated with various stimulation techniques (Acid fracturing & High Rate Matrix Acidizing). The success of the stimulation treatment in monobore Multi-stage completion depends on several factors such as: selecting proper fluid recipes, rock/fluid properties, job design, and field implementation. That type of completion is activated as a drop-ball system to stimulate each flow zone individually but in single well intervention setup. This paper presents a 15K open-hole HPHT MSC field success case application that describes the best practices, learning, planning, design, installation and stimulation in NKJG unconventional reservoirs to enhance well performance and overcome reservoir challenges. An improvement in understanding of production performance from several reservoir sections is the key enabler selective stimulation and effective testing. After stimulating all the stages milling of the ball seats of completion was obtained in order to pinpoint well production profile. The post stimulation flow tests results and production logs provided a good evidence for applying this technology these unconventional reservoirs.
- Asia > Middle East > Kuwait (0.88)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.66)
- Geology > Geological Subdiscipline > Geomechanics (0.47)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Abstract North Kuwait has a vision to produce about 1 million BOPD within next couple of year. As a part of this strategy, all efforts & opportunities are being synchronized to maximize the production. A serious threat to this plan was confronted by observation of Naturally occurring radioactive materials (NORM) at some of the producers, a new challenge for which the asset did not anticipate or had any plan earlier. The paper proposal covers how this threat was converted into an opportunity. A comprehensive review of the wells with NORM was done to understand the link to specific reservoir related issues or zone's mineralogy. As this kind of production problem has been faced for the first time in North Kuwait, brainstorming and technical pros & cons were investigated with internal as well as external consultants. A due diligence was conducted to existing rules & procedures within KOC and Kuwait. Case histories from different parts of the world were reviewed as to how such issues had been resolved. Measurement of NORM, accuracy & validity was also looked into, which varied from vendor to vendor. Thus the gathered knowledge was shared with all stake holder teams. As almost 30-40 MBOPD was the locked in potential, fast track actions have been taken to create a contract to manage wells suffering from NORM. After going through a fast track identification of suitable vendor, contract was awarded to one of the international vendor. Accordingly, workover rigs were made ready to handle NORM remediation operations professionally. Simultaneously, technical evaluation of the performance of wells infected with NORM was done to understand the phenomenon and the relationship with the changes in reservoir pressure / stimulation. A workover schedule was prepared and implemented to revive the shut-in production potential to the GCs, resulting in a bump in oil production for North Kuwait. As a result of the strategy adopted, deferment of oil production due to NORM, which hovered to more than 1.5 years in the past, is prevented, thus helping production target requirements for the Asset. Performance evaluation of wells indicated that there is a strong relationship of reservoir pressure and stimulation with the NORM level. NORM management requires an integrated team approach, ranging from working units to the organization level and a proactive analytical approach to understand the impact of ongoing sub-surface operations on NORM tendencies. The proper understanding and analysis done in overcoming the NORM has aided in enhancing and sustaining the production via having extended productive life for the wells.
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Upper Marrat Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sabiriyah Mauddud (SAMA) Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > SAMA Formation (0.99)