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Collaborating Authors
Fidan, Erkan
Successful Application of Co2 Foam Fracturing Enables Paradigm Shift in Stimulation Strategy of Kuwait Jurassic Depleted Reservoirs
Al-Mefleh, Kholoud (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Abdul-Samad, Zamzam (Kuwait Oil Company) | Al-Salali, Yousef (Kuwait Oil Company) | Al-Muhanna, Danah (Kuwait Oil Company) | Abdel-Basset, Mohamed (SLB)
Abstract The first ever CO2 foam fracturing new technology in Kuwait Oil Company (KOC) history was executed flawlessly in late 2021. Three treatments were executed. Co2 Foam Fracturing proved its significant added value of improving productivity in deep depleted tight carbonate Jurassic reservoirs, enhance flow back, reduce water consumption and carbon emission, and enable early production plus improving operation efficiency and cost saving. The stimulation operation has proven to be a huge success for all multidisciplinary teams involved as preliminary results showed over 50-70% production increase compared to offset wells. The main challenges of acid fracturing stimulation in depleted reservoirs are the need for extended formation cleanup to flow back the injected fluids via prolonging Nitrogen lift that add higher operational costs and intervention operations. Therefore, energetic high foam efficiency frac fluid becomes essential to assist flowback and retrieve pumped frac fluids from reservoir. To tackle these challenges, Carbon Dioxide CO2 is pumped in liquid phase as energetic fluid together with normal frac fluids. Due to CO2 liquid nature, high foam efficiency can be reached (40 – 50%) at much lower friction losses. So, it enables achieving pumping frac at high rates and high foam efficiency. The main benefits of CO2 Foam frac are better fracture cleanup due to expansion of the stored compressed gas in the liquid CO2, fluid loss control that is provided by foam, minimized fracture conductivity damage, and the increase in hydrostatic pressure while pumping that translates to lower surface pressures during injection. The selected pilot well is in depleted deep tight carbonate reservoir area of North Kuwait Jurassic gas fields. The executed acid fracturing operation required close planning starting from Q1-2021. Many challenges faced from logistical issues, lack of infrastructure and CO2 resources for the multi-faceted operation due to COVID-19 pandemic limitations. These challenges were tackled ahead with the integration of technical and operations teams to bridge the knowledge gap and to enable executing the operation safely. The pilot well’s net incremental production gain is estimated at 50-70% compared to offset wells, with improved flowback and formation cleanup with less well intervention. The resulting time and cost savings as well as the incremental well productivity and better operation efficiency confirmed high perspectives for the implemented foam acid fracturing approach. Another two CO2 Foam acid fracturing wells were executed with good results too. This paper will demonstrate the value of CO2 foam fracturing in depleted reservoir and KOC experience post first application and its plans to expand CO2 Foam Fracturing application across KOC different fields.
- Geology > Rock Type > Sedimentary Rock (0.69)
- Geology > Geological Subdiscipline (0.47)
- 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)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Upper Burgan Formation (0.94)
- (2 more...)
Successful Completion of CO2-Foamed Hydraulic Acid Fracturing Pilot Campaign in Jurassic Gas Wells in Kuwait
Al-Muhanna, Danah (Kuwait Oil Company) | Ahmed, Zamzam (Kuwait Oil Company) | Al-Qallaf, Aliah (Kuwait Oil Company) | Ajayi, Ayo (Shell Upstream International) | Al-Othman, Mohammad (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Al-Salali, Yousef (Kuwait Oil Company) | Al-Ajmi, Moudi (Kuwait Oil Company)
Abstract Jurassic Gas Field Development Group (GFDJ) of Kuwait Oil Company (KOC) completed the first ever CO2 foamed acid frac pilot campaign in four Jurassic sour HTHP wells. This innovative technology was utilized for the first time in KOC's history safely and effectively with exemplary well performance. GFDJ had been pursuing the CO2-foamed acid fracturing technology since 2019 with the objective of improving the stimulation and hydraulic fracturing efficiency in the Jurassic Middle Marrat formation. CO2-foamed acid fracs have several advantages over other stimulation techniques: CO2 is a miscible and non-damaging fluid which blends in water and also mixes with hydrocarbons. Pumped as a liquid and slightly heavier than water, leading to lower treating pressures due to heavier hydrostatic head. Effective in treating lower-pressured/partially-depleted, good K.H (permeability-height function) carbonate reservoirs. Reduces water-based gels and overall frac-load volume by the percentage of CO2 pumped in the frac fluid system (40% by volume is utilized in this pilot). Energizes the frac fluid and stays in solution until it heats up to gas. This property ensures the frac load recovery is achieved throughout the flowback. Eliminates the need to activate the well after the frac with CT/N2 applications potentially saving time and money to KOC. Has potential to lighten up the heavier ends of the hydrocarbons due to its miscible properties, hence may help with better hydrocarbon inflow. Creates stable foam structure with the frac fluid, increasing the frac fluid viscosity hence has the potential to generate better frac geometry and larger stimulated rock volume (SRV). A four-well campaign was completed within 12 months period. Three different monobore completion wells and one 3-1/2″ tubing with 5″ liner completion well were fracture-treated using an average of 40% downhole quality CO2-foam pumped at an average rate of 30 bpm. Different service companies and their fluid systems, as well as their operational capabilities were utilized in operations with exemplary clean up and production test results that surpassed the expectations of the asset. Additionally, pumping cryogenic CO2 at high ambient desert temperatures of September in Kuwait, safely, and operationally effectively is a major milestone and achievement in itself. This paper summarizes the design, operational, well clean-up and production performance details of the CO2 campaign. Learnings of the GFDJ asset will be shared in order to benefit from the learning curve that KOC went through in implementing this strategic application. Success of novel CO2 stimulation technique is critical for the GFDJ asset to continue expanding its production capacity in next 2-3 years while maintaining the strong production plateau achieved in 2021. Future plans of the assets will also be discussed to ensure cross-boundary opportunity realization will be possible in the industry for the region.
- Geology > Rock Type > Sedimentary Rock (0.68)
- Geology > Geological Subdiscipline (0.47)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Upper Burgan Formation (0.94)
- (2 more...)
First Ever in Kuwait, Successful Application of CO2 Foam Acid Fracturing Enables Paradigm Shift in Stimulation Strategy of Kuwait Jurassic Depleted Reservoirs
Al-Muhanna, Danah (Kuwait Oil Company) | Ahmed Abdul-Samad, Zamzam (Kuwait Oil Company) | Al-Qallaf, Aliah (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Al-Awadhi, Mansour (Kuwait Oil Company) | Al-Salali, Yousef (Kuwait Oil Company) | Abdel-Basset, Mohamed (Schlumberger)
Abstract The first ever CO2 foam fracturing new technology in Kuwait Oil Company (KOC) history was executed flawlessly in late 2021. Three treatments were executed. Co2 Foam Fracturing proved its significant added value of improving productivity in deep depleted tight carbonate Jurassic reservoirs, enhance flow back, reduce water consumption and carbon emission, and enable early production plus improving operation efficiency and cost saving. The stimulation operation has proven to be a huge success for all multidisciplinary teams involved as preliminary results showed over 50-70% production increase compared to offset wells. The main challenges of acid fracturing stimulation in depleted reservoirs are the need for extended formation cleanup to flow back the injected fluids via prolonging Nitrogen lift that add higher operational costs and intervention operations. Therefore, energetic high foam efficiency frac fluid becomes essential to assist flowback and retrieve pumped frac fluids from reservoir. To tackle these challenges, Carbon Dioxide CO2 is pumped in liquid phase as energetic fluid together with normal frac fluids. Due to CO2 liquid nature, high foam efficiency can be reached (40 – 50%) at much lower friction losses. So, it enables achieving pumping frac at high rates and high foam efficiency. The main benefits of CO2 Foam frac are better fracture cleanup due to expansion of the stored compressed gas in the liquid CO2, fluid loss control that is provided by foam, minimized fracture conductivity damage, and the increase in hydrostatic pressure while pumping that translates to lower surface pressures during injection. The selected pilot well is in depleted deep tight carbonate reservoir area of North Kuwait Jurassic gas fields. The executed acid fracturing operation required close planning starting from Q1-2021. Many challenges faced from logistical issues, lack of infrastructure and CO2 resources for the multi-faceted operation due to COVID-19 pandemic limitations. These challenges were tackled ahead with the integration of technical and operations teams to bridge the knowledge gap and to enable executing the operation safely. The pilot well's net incremental production gain is estimated at 50-70% compared to offset wells, with improved flowback and formation cleanup with less well intervention. The resulting time and cost savings as well as the incremental well productivity and better operation efficiency confirmed high perspectives for the implemented foam acid fracturing approach. Another two CO2 Foam acid fracturing wells were executed with good results too. This paper will demonstrate the value of CO2 foam fracturing in depleted reservoir and KOC experience post first application and its plans to expand CO2 Foam Fracturing application across KOC different fields.
- Geology > Rock Type > Sedimentary Rock (0.69)
- Geology > Geological Subdiscipline (0.47)
- 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)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Upper Burgan Formation (0.94)
- (2 more...)
Successful Completion of First Ever CO2-Foamed Hydraulic Acid Fracturing Pilot Campaign in Jurassic Gas Wells of KOC Delivering Exemplary Well Clean Up and Production Performance
Al-Muhanna, Danah (Kuwait Oil Company) | Ahmed, Zamzam (Kuwait Oil Company) | Al-Qallaf, Aliah (Kuwait Oil Company) | Ajayi, Ayo (Shell Upstream International) | Al-Othman, Mohammad (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Al-Salali, Yousef (Kuwait Oil Company) | Al-Ajmi, Moudi (Kuwait Oil Company)
Abstract Jurassic Gas Field Development Group (GFDJ) of Kuwait Oil Company (KOC) completed the first ever CO2 foamed acid frac pilot campaign in three Jurassic sour HTHP wells. This innovative technology was utilized first time ever in the KOC history safely and effectively with exemplary well performances. GFDJ had been pursuing the CO2-foamed acid fracturing technology since 2019 with the objective of improving the stimulation and hydraulic fracturing efficiency in the Jurassic Middle Marrat formation. CO2-foamed acid fracs have several advantages over other stimulation techniques:CO2 is a miscible and non-damaging fluid blends in water and also mixes with hydrocarbons. Pumped as a liquid and slightly heavier than water, leading to lower treating pressures due to heavier hydrostatic head. Effective in treating lower-pressured/partially-depleted good KH carbonate reservoirs. Reduces water-based gels and overall frac-load volume by the percentage of CO2 pumped in the frac fluid system (40% by volume is utilized in this pilot). Energizes the frac fluid and stays in solution until it heats up to gas. This property ensures the frac load recovery is achieved throughout the flowback. Eliminates the need to activate the well after the frac with CT/N2 applications potentially saving time and money to KOC. Has potential to lighten up the heavier ends of the hydrocarbons due to its miscible properties, hence may help with better hydrocarbon inflow. Creates stable foam structure with the frac fluid, increasing the frac fluid viscosity hence has the potential to generate better frac geometry and higher "stimulated rock volume" or SRV. A three-well campaign was completed between September 2021 and February 2022. Three different monobore completion wells were fracture-treated using an average of 40% downhole quality CO2-foam pumped at an average rate of 30 bpm. Different service companies and their fluid systems, as well as their operational capabilities were utilized in operations with exemplary clean up and production test results that surpassed the expectations of the asset. Additionally, pumping cryogenic CO2 at high ambient desert temperatures of September in Kuwait, safely, and operationally effectively is a major milestone and achievement in itself. This paper summarizes the design, operational, well clean-up and production performance details of the CO2 campaign. Learnings of the GFDJ asset will be shared in order to benefit from the learning curve that KOC went through in implementing this strategic application. Success of novel CO2 stimulation technique is critical for the GFDJ asset to continue expanding its production capacity in next 2-3 years while maintaining the strong production plateau achieved in 2021. Future plans of the assets will also be discussed to ensure cross-boundary opportunity realization can be possible in the industry for the region.
- Geology > Geological Subdiscipline > Geomechanics (0.68)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.46)
- 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)
- (17 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (4 more...)
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)
Conductivity Enhancement and Productivity Restoration of Deep North Kuwait Jurassic Gas-Condensate Well by Using Effective HRMA Stimulation Technique
BinMotlaq, Hind (Kuwait Oil Company) | Ahmed, Zamzam (Kuwait Oil Company) | AlSaeed, Abdullah (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | AlMutawa, Majdi (Kuwait Oil Company) | Salem, Abrar (Schlumberger) | Slama, Hedi (Schlumberger)
Abstract Achieving sustainable gas and condensate production from carbonaceous North Kuwait Jurassic Gas (NKJG) reservoirs has been challenging due to multi-dimensional inflow/outflow complications under restrictive operating downhole conditions. Production from the NKJG reservoirs has strategic importance for the State of Kuwait, where the formations are deep and sour, and produce gas-condensate and volatile oil, in which the produced fluids contain from 2 to 8% H2S and 1 to 3% CO2. High reservoir pressure of up to 12,000 psi is widespread trapped below an over-pressured salt structure. NKJG reservoirs have high temperature of ~275F and have been recently completed with monobore completions, to optimize overall commingled well performance and to ensure operational optimization of future well interventions. Differential depletion has had significant consequences in well and reservoir management including the design and execution of stimulation treatments, particularly the "high rate matrix acidizing (HRMA)" applications. In addition, vertical variations in lithological and mechanical rock properties contribute to drilling challenges which are progressively exacerbated as the deepest zones continue to produce most of the hydrocarbons whereas other potential horizons are not exploited at similar rates. Monobore completions have been deployed so that each flow unit could be segregated and stimulated separately, starting from the bottom, moving uphole as each stage is treated, activated, tested and isolated using drillable bridge plugs. After all zones are completed, the bridge plugs are drilled out using coiled tubing mills and commingled production is established from all zones. To overcome this complex technical challenge while utilizing the funds and resources efficiently, the team in charge of the project developed a novel method of assessing the zones similar in reservoir characteristics and generated a "bullheaded HRMA treatment design" concept which was applied in the subject well while stretching the length of the perforation interval to a gross 216 ft that can be effectively covered with sound wellbore diversion methodology using particulate chemical diverters as well as leak-off control diverters. The custom-designed fluid train was tailored to effectively stimulate each conductivity unit, followed by diversion into the subsequent stages. The perforated interval length has been stretched to 285 ft in subsequent wells based on the success of this well. The completion and intervention history of the subject well is covered in this paper followed by the successful field implementation of the HRMA application as a case study, and to share the learnings and recommendations providing pre-stimulation and post-stimulation production logging comparisons. As an additional challenge, the HRMA treatment overcame the heavy near-wellbore damage created during a workover fishing operation due to the well-kill with heavy drilling fluid. The results are confirmed by calibrated nodal analysis assessment providing evidence of the success in deploying this technology in unconventional tight gas reservoir of less than 10 mD permeability. Achieving optimal inflow distribution along vertically varied flow zones has enabled the asset to deploy this systematic approach in other new wells in the NKJG while saving significant cost and time.
- Asia > Middle East > Kuwait (0.93)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.15)
- Geology > Rock Type (0.48)
- Geology > Geological Subdiscipline > Geomechanics (0.34)
A Field Application of Successful Installation and Sequential Activation of 15,000-psi Rated Hydro-Mechanical Multi-Stage Completion in Peripheral Deep North Kuwait Jurassic Asset for Improved Completion Efficiency and Well Productivity
Al-Otaibi, Yousef (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Bloushi, Taha (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Sharma, Siddhartha (Kuwait Oil Company) | Pradhan, San Prasad (Kuwait Oil Company) | Manimaran, Palaniappan (Kuwait Oil Company)
Abstract Optimization of permanent liner completions in the North Kuwait Jurassic Gas (NKJG) reservoirs has been an ongoing challenge progressed on a steep learning curve within the last decade. Various completion options are field-tested in determining the optimal completion hardware and activation methodology. The asset's objectives have been multi-dimensional: preserve natural fractures, minimize formation damage, segregate, stimulate and activate optimally, while installing permanent completions hardware efficiently, which can withstand 15,000-psi differential pressure at high temperature and sour gas environment and sustain production for the well life of over 20 years. NKJG faces the enormous task of increasing the hydrocarbon production potential by over 200% within a short time period. The reservoirs are high-pressured and high-temperature (HTHP) gas condensate assets with tight matrix properties (i.e. <0.1 mD permeability), in variation with naturally fractured sections within flow-zones separated into eight segments. Preserving the natural fractures, removal of near wellbore damage and segregating flow-zones based on lithology and critical reservoir properties are important especially in peripheral subsurface locations, where the realization of full reservoir potential is not only essential for production success, but also required for appraisal of boundary conditions. For realizing these objectives, the asset custom-designed a multi-stage completion system with hydro-mechanical liner hanger packer, open-hole packers, hydraulic anchor and multiple frac ports set and activated as a drop-ball system. Due to the high completion loads, differential body and packer rating are manufactured to 15,000 psi using corrosion resistant alloy throughout, with the PBR and seal-bore assembly designed to withstand differential pressures and contraction during multiple fracturing events. Custom-designed multi-stage completion assembly (MSC-HP) was successfully installed, sequentially hydraulic-fracced and commingle-tested on flowback. Customized operational guidelines were established including a pre-set success criterion, openhole and caliper log sequences, tie-back cementation and subsequent clean out trips, followed by hole conditioning and reamer runs to compute the final drag and friction forces. Differential sticking risks were mitigated by avoiding the "pressure ramps" exacerbated by differential depletion evident in the area. Reservoir was segmented in three distinct intervals to maximize flow potential. As a result, the asset's objectives were successfully met, with the additional benefits of proving multiple zone activation, each with a complicated sequence of operational events, performed sequentially in four days. This paper documents the project cycle from successful planning and design, to installation and execution phases of the MSC-HP in peripheral deep NKJG asset. Key learnings and critical factors, which led to the successful well results in spite of less favorable subsurface location are summarized. Added complications due to the severe NKJG specs will be discussed as the number of global analogues is scarce leading to limited opportunities for the industry to learn from in unconventional/conventional mix layered carbonates.
- 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)
New Approach to Chemical Diversion Using Biodegradable Particulates and Fibers in Matrix Acidizing: Kuwait Case Studies
Al-Othman, Mohammed (Kuwait Oil Company) | A-Matrouk, Yousef (Kuwait Oil Company) | Ahmed, Zamzam (Kuwait Oil Company) | Ashkanani, Meshari (Kuwait Oil Company) | Buhamad, Ali (Kuwait Oil Company) | Al-Dousari, Mohammad (Kuwait Oil Company) | Ahmed, Abdul-Samad (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Mahmoud, Wael (Schlumberger) | Liu, Hai (Schlumberger) | Salem, Abrar (Schlumberger) | Nikolaev, Max (Schlumberger)
Abstract Heterogeneity across the producing interval is typical in oil and gas wells; it is rare to find uniform production distribution or fluid injection across a substantially long interval. Hence, diversion during matrix acidizing is critical, especially if the downhole pressure and/or temperature are high. In two Kuwait Jurassic fields, two wells were completed in an over 100 ft producing interval across a carbonate reservoir. Reservoir temperature is 280°F, and the estimated reservoir pressure is 11,000 psi. Multiple matrix acidizing trials to enhance well productivity have been performed with conventional diversion techniques and, as indicated by the surface pressure response, were not effective. This requires an adequately engineered near wellbore diversion system that can overcome the challenge of these bottomhole conditions and form a uniform production distribution across a substantially long heterogeneous interval. A new methodology was applied in two Jurassic wells that combined a multimodal blend of biodegradable particulates and fibers as a chemical diverter, and emulsified acids as main fluids for a matrix stimulation. In each diversion stage, the change in surface pressure ranged from 800 to 1,000 psi after the diversion pill hit the perforation tunnel. Moreover, a clear signature of diversion was demonstrated in the instantaneous shutin pressures. In another Kuwait field, the diversion pill was tested by using injectivity logging tests to monitor the changes in injectivity across the perforated interval during an acid fracturing treatment in comparison to the earlier injection profile. A remarkable change in injection was observed and a total of 80% change in the injection profile was quantified from before and after the diversion. The diversion pill is relatively small in volume and is easy and safe to handle. Fibers help to maintain the carrying capacity and allow safe landing of the biodegradable material to the formation face. Only a few barrels are required to plug the opened or stimulated interval, and the method allows the following stimulation stage to treat the subsequent interval. The first well revealed a 330% and 110% production increase in gas and oil rates, respectively. The production was set as one of the highest producers in the field. The second well yielded a 320% increase in total production, which set the highest record for the field. The new method is proved to be highly effective in terms of wellbore coverage, and highest production records in the field after matrix acidizing treatments.
- North America > United States (1.00)
- Asia > Middle East > Kuwait (0.92)
- 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)
Successful Recovery and Stimulation of a Long HP/HT Horizontal Well in One Intervention: A Case History of Acid Fracturing and New Generation of Diversion Systems Combination, Middle Marrat Carbonate Formation
Sierra, Leopoldo (Halliburton) | Alboueshi, Alaa Eldine (Halliburton) | Elmofti, Mohamed (Halliburton) | Eid, Walid (Halliburton) | Sadeddin, Salma (Halliburton) | Allam, Ahmed (Halliburton) | Al Othman, Mohamed (KOC) | Ahmed, Zamzam (KOC) | Fidan, Erkan (KOC) | Al-Zaidani, Ibrahim (KOC) | Nilotpaul, Neoq (KOC) | Ashkanani, Meshari (KOC) | Buhamad, Ali (KOC) | Al-Dousari, Mohammed Abdullah (KOC) | Ahmed, Abdul-Samad Mohammed (KOC) | Al-Matrouk, Yousef (KOC)
The case history presented in this paper describes the performance of an acid fracture intervention in a HP/HT well where, because of a number of problems encountered during the well construction stage, this intervention was the last procedure considered to evaluate the productivity of a Marrat formation well. In view of the stimulation challenges encountered, the architecture of the wellbore, and the intervention stimulation requirement to evaluate the productivity of the horizontal well completed in the Marrat formation, it was necessary to change the proppant fracture stimulation technique originally planned. Instead, it was decided that a selective acid fracture stimulation would be performed in the prospective part of the horizontal section where three long perforation clusters had been placed. Acidizing fracture stimulation was performed in one intervention using a next-generation liquid and soluble solid diversion system that enabled the generation of one selective fracture per perforation cluster. The planned acidizing fracture stimulation process was implemented properly in the field in accordance with the design constraints. The reactive fluid system diversion and the generation of a new fracture when the diversion system reached the perforation were clearly observed. The post-acid fractured well productivity index (PI) showed the high quality of the stimulation performed in a challenging environment, demonstrating the effectiveness of the new diversion system for creating selective fractures in a horizontal wellbore with multiple perforation clusters. Considering the well's architecture, HP/HT nature, and single intervention requirement, the case study documented in the paper can be helpful in the decision-making process when selecting a proper stimulation technique for challenging conditions. The effectiveness of the new diversion systems is also discussed.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock (0.69)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff C Formation (0.99)
- (4 more...)