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Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- Research Report > New Finding (0.93)
- Overview (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.72)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- (2 more...)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- North America > United States > Texas (1.00)
- Europe (0.93)
- Research Report > New Finding (0.93)
- Overview (0.88)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
A Successful Acid Fracturing Treatment in Asphaltene Problematic Reservoir, Burgan Oilfield Kuwait
Al-Shammari, A. (Kuwait Oil Company, Kuwait) | Sinha, S. (Kuwait Oil Company, Kuwait) | Sheikh, B. (NAPESCO, Kuwait) | Youssef, A. (NAPESCO, Kuwait) | Jimenez, C. (Kuwait Oil Company, Kuwait) | Al-Mahmeed, F. (Kuwait Oil Company, Kuwait) | Al-Shamali, A. (Kuwait Oil Company, Kuwait)
Abstract The Burgan Marrat Reservoir is a challenging high-pressure, high-temperature carbonate oil reservoir dating back to the Jurassic age. This specific reservoir within the Burgan Field yields light oil, but it has a significant issue with Asphaltene deposition in the wellbore. Additionally, its well productivity is hampered by low matrix permeability. Addressing these challenges is crucial, and a successful acid fracturing process can not only enhance well productivity but also address Asphaltene-related problems. This study delves into a comprehensive methodology that was employed. The focus of well selection was on ensuring good well integrity and maintaining a considerable distance from the oil-water contact (OWC). The approach involved conducting a Multi-Rate test followed by pressure build-up to establish a baseline for understanding the reservoir's behavior, including darcy and non-darcy skin. The treatment design aimed at better fluid loss control and initiating highly conductive fractures in the reservoir. Specific measures, such as using suitable diverters and acid, were employed to maximize the length of the fractures. To validate the approach, a nodal analysis model was fine-tuned to predict how the well would perform under these conditions. The results post-stimulation were impressive. There was a substantial improvement in well production and flowing bottom hole pressure. In fact, the productivity index of the well increased significantly, representing a substantial enhancement in output. The pressure build-up test after the fracture demonstrated a linear flow within the fracture, indicating a successful treatment with a fracture half-length of approximately 110 feet and a negative skin, which signifies an improvement in flow efficiency. Furthermore, the treatment effectively mitigated the risk associated with Asphaltene deposition, a significant accomplishment given the historical challenges faced in this reservoir. This success can be attributed to an innovative workflow that incorporated a meticulous surveillance plan, a well-thought-out fracturing treatment design, and the application of advanced nodal analysis. Together, these components not only optimized the well's performance but also paved the way for the development of similar high-pressure, tight carbonate reservoirs. This approach not only enhances productivity but also ensures successful mitigation of Asphaltene-related issues, marking a significant advancement in reservoir engineering techniques.
- 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)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > Greater Burgan Field > Mauddud Formation (0.99)
- (15 more...)
Protecting Parent-Well Production Using Far-Field Diverters in Unconventional Wells
Ajisafe, F. O. (Liberty Energy, Houston, Texas, United States) | Porter, H. (Lime Rock Resources, Houston, Texas, United States) | Kothare, S. (Lime Rock Resources, Houston, Texas, United States) | Colson, E. (Lime Rock Resources, Houston, Texas, United States) | Ellis, R. (Liberty Energy, Houston, Texas, United States) | Heaton, N. (Liberty Energy, Houston, Texas, United States) | Demars, B. (Liberty Energy, Houston, Texas, United States) | Mayerhofer, M. (Liberty Energy, Houston, Texas, United States)
Abstract The impact of fracture driven interaction (FDI) is an increasing concern in mature developed unconventional plays in the US. In this study, parent well production performance after infill well stimulation is evaluated to understand the effectiveness of far-field diverter in mitigating FDI's. Studies to determine if FDI's result in a negative or positive impact, have concluded that it varies from basin-to-basin (Miller et al 2016). In this project, the purpose of pumping far-field diverter is to mitigate wellbore sanding and production loss in existing parent wells. The far-field diverter pill includes a blend of multimodal particles to bridge the fracture tip, preventing excessive fracture length and height growth. Fracture modeling with a unique particle transport model is typically used to design the far-field diverter pill impact on fracture geometry. The pill design and contingency designs are executed in the infill well stimulation job, right after the pad step, in the beginning of the pump schedule. Optimization of the far-field diverter can be complemented with real-time pressure monitoring or cross-well fiber strain data on the parent well. Over the years, far-field diverter has, in one form or the other, been used for various applications in stimulation design. However, since mid-2010's, far-field diverter has been used to address growing concerns of FDI's observed in most mature plays in the US. In this study, since 2018, far-field diverters have been pumped in several wells for the purpose of mitigating the negative impact of FDI's between parent and child wells. While these jobs were operational successes, the next crucial step was to evaluate and quantify the effectiveness of the far-field diverter in mitigating production loss in the parent wells. It is important to note that the operator whose wells utilized far-field diverters, had experienced negative impact of FDI's in their parent wells in the form of production loss and sand in the wellbore which required clean outs at a significant cost. In this study, production data was evaluated comparing pre-stimulation production before shut-in and post-stimulation production after the parent wells were brought back online. Overall, about 75% of the parent wells protected show positive uplift in oil production. And about 80% of the child wells show superior or comparable production decline after about a year of production when compared with offset parent wells It is evident that far-field diverters for fracture geometry control in child wells can be extremely helpful in mitigating negative impact of FDI's. In unconventional reservoirs, where infill (child) well drilling is prevalent, the impact of far-field diverter in controlling fracture geometry has the potential to be a value added FDI mitigation technology to mitigate wellbore sanding and subsequent clean outs as well as optimize production performance of both child and parent wells. The early part of the project resulted in ~$2.5million in savings in well cleanup costs. In addition, fracture diagnostics along with production data evaluation can be highly beneficial in understanding the role of production depletion, completion design and well spacing on fracture driven interaction.
- North America > United States > North Dakota (1.00)
- North America > Canada > Saskatchewan (0.80)
- Geology > Geological Subdiscipline (0.46)
- Geology > Petroleum Play Type > Unconventional Play (0.34)
- North America > United States > North Dakota > Williston Basin > Lodgepole Formation (0.99)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation > Middle Bakken Shale Formation (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.97)
- (3 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- (3 more...)
A Unique Methodology and Successful Implementation While Testing Exploratory Well in Bahrah Field with Several Challenges: A Case Study in North Kuwait
Alotaibi, F. Z. (Kuwait Oil Company, Ahmadi, Kuwait) | Al-Ibrahim, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Ibrahim, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Binsafar, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Alkhulaifi, O. (Kuwait Oil Company, Ahmadi, Kuwait)
Abstract Objectives/Scope This paper presents a unique successful application and implementation of testing procedures in an exploratory cretaceous well in Bahrah field (North Kuwait). Used to evaluate productivity and characteristics of a reservoir and clearly understand the reservoir's potential, which helps in reducing the risks related to developing the field for a long-term with sustainable production, and selecting the optimum completion and artificial lift method. Methods, Procedures, Process The exploratory vertical well BH-X drilled to explore the hydrocarbon potential within the Northern Area of the Bahrah field targeting cretaceous Sandstone formation, with a total drilling depth 10,780 ft. Open-hole logs and collected WL open-hole fluid sample post drilling proved the oil bearing in the sandstone formation. The cement bond evaluation behind slim casing liner showed some doubt in quality in particularly cement image of ultrasonic tool. Decision was taken to proceed with testing without cement remediation, and perform a DST with down-hole real-time pressure gauges. The Formation interval was perforated using dynamic underbalance casing guns post displacing the completion fluid in hole OBM with filtrated brine. The Nitrogen (N2) lifting through Coiled tubing (CT) was used for well activation and to evaluate the well productivity on rig since the well ceased to flow naturally. Since these pressure events and analysis are crucial in making decisions in a low cost environment, It was decided to retrieve the downhole pressure data for preliminary Pressure Transient Analysis (PTA), which indicated that the formation skin was positive. Therefore, acid wash was performed to the sensitive sandstone formation to enhance the production rate. Results, Observations, Conclusions However, the results post the acid wash treatment showed increment in water cut. RIH with Water-Flow Log (WFL) to check the water source and identified channels behind pipe was challenging due to unavailability of E-coiled tubing. Thus, a unique solution was used to achieve a drawdown and dynamic condition while recording conventional WFL against the testing zone by using N2 and utilizing the DST tools functions. WFL results indicated the source of water behind casing above the test interval. Therefore, a cement squeeze job was performed and cement bond log was recorded again post the remedial job, which confirmed a good improvement in cement bond. The targeted interval was re-perforated utilizing dynamic underbalance perforation with STIM guns, the well was activated by CT using N2 lifting and showed clear improvement in production with zero water cut. Novel/Additive Information Overall, a unique methodology while using real time data has delivered better decision making and operational capabilities during rig and testing operations, which assists in reducing well testing operations cost and time.
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Bahrah Field > Marrat Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.98)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.98)
Rejuvenating Profitability and Performance of Aging Gas Field through Multi-Pronged Strategy: System De-Bottlenecking, Well Optimization and Opex Management
Awase, Azar (United Energy Pakistan Limited, Karachi, Sindh, Pakistan) | Memon, Sikandar Ali (United Energy Pakistan Limited, Karachi, Sindh, Pakistan) | Zafar, Jahangeer (United Energy Pakistan Limited, Karachi, Sindh, Pakistan) | Khan, Zaeem Hasan (United Energy Pakistan Limited, Karachi, Sindh, Pakistan) | Noman, Muhammad (United Energy Pakistan Limited, Karachi, Sindh, Pakistan) | Ejaz, Muhtashim (United Energy Pakistan Limited, Karachi, Sindh, Pakistan) | Ali, Mushtaque (United Energy Pakistan Limited, Karachi, Sindh, Pakistan) | Amjad, Muhammad (Prime International Oil and Gas Company, Karachi, Sindh, Pakistan) | Sirati, Muhammad Attar (Pakistan Petroleum Limited, Karachi, Sindh, Pakistan)
Abstract This paper presents a success case of optimizing a challenging mature gas field, producing at tail-end, with low reservoir pressure and increasing water gas ratio trend, complex surface network, and high operating cost. The situation demanded cost efficiency, novel strategies to optimize production and prudent decisions to safeguard reserves and sustain production. S-Field was put on production in 2003 and peaked production of 460 MMscfd in 2007. In 2021, reservoir pressure dropped from 5400 to 300 psi, wells became critical and front-end compressors approached lower limits. Additionally, field was close to economic threshold, owing to late life conditions and high Opex. An integrated approach was taken to mitigate the challenges. A network modeling exercise with multiple sensitivities were performed to simulate the application of different deliq techniques (soap sticks, velocity string, CSI) and operating field with expanded compressor envelop. Subsequently, the strategy was implemented in phases to optimize the field. Simulations performed for no further activity case with prevailing production technical limit suggested additional recoveries of only 4 Bscf for one year remaining. The simulated optimization cases predicted additional recoveries of around 20 Bscf with field life extension by 5 years. On top of production and reserves, the strategy envisaged significant improvement in field profitability by saving fuel gas (∼1 Bscf annual) and maintenance cost (2.5 $MM annual). The capital investment for the project was $10MM, with estimated project NPV of $17MM. The project implemented in Oct 2021 with optimized compression scheme, smaller tubing size, velocity strings, and cost-effective foam injection. The actual field delivery was vigilantly monitored and till day additional volumes of 8 Bscf have been materialized and field is demonstrating very stable performance, closely matching the premise. A novel aspect is that brown fields may be rejuvenated by expanding techno-commercial boundaries besides application of optimization techniques. At the stage where many operators would consider abandoning the fields, results driven strategy coupled with multidisciplinary inputs resulted in higher profits and additional recovery.
- North America > United States > Texas > Kleberg County (0.24)
- North America > United States > Texas > Chambers County (0.24)
First Unconventional Najmah Horizontal Well in Green Jurassic Gas Field Unlocked the Reservoir Potential and Setup Development Strategy Roadmap
Abdel-Basset, M. (SLB, Kuwait) | Al-Otaibi, Y. (Kuwait Oil Company, Kuwait) | Al-Ajmi, S. (Kuwait Oil Company, Kuwait) | Al-Mulla, S. (Kuwait Oil Company, Kuwait) | Bloushi, T. (Kuwait Oil Company, Kuwait) | Al-Mutawa, M. (Kuwait Oil Company, Kuwait) | Al-Ajmi, M. (Kuwait Oil Company, Kuwait) | Hadi, A. (Packers Plus Energy Services, Kuwait)
Abstract The journey of appraising unconventional reservoirs of North Kuwait Jurassic Gas (NKJG) fields achieved a significant milestone through the successful test in the first horizontal well completed in Najma Limestone (NJ-LS) reservoir in Bahra field. This accomplishment becomes even more remarkable given that none of the previous vertical wells’ tests were successful. This paper will demonstrate the challenges faced in the well placement, completion and stimulation, as well as the implementation of new technologies to achieve Kuwait’s highest ever initial gas production rate. This outstanding success in appraisal well has unlocked the potential of the NJ-LS reservoir and prompted a step-change in its development strategy. NJ-LS is a tight gas-condensate reservoir with typical porosity ranging from 2 to 9% and very low matrix permeability (~0.01mD) with primary production through natural fractures. To increase the chances of success in encountering fracture corridors, long drain-hole horizontal wells were deemed necessary. To overcome well planning and placement challenges, detailed seismic attribute mapping and integration of available core and log data were undertaken to place the well in the best sweet spot. Extensive screening of seismic data helped avoid possible seismically mappable hazards and optimize the trajectory to encounter areas with high fracture corridor. The well was drilled as 6in lateral length of approximately 2900ft and successfully landed as planned. State-of-the-art drilling and real-time geosteering technologies aided in precisely placing the wellbore in the target zone of NJ-LS. The integrated completion design included eight stages of Multi-Stage Completion, as first-time achievement in NKJG fields. The targeting of shorter stages aimed to accommodate better the reservoir heterogeneity (matrix, fractures, losses, etc) to improve acid stimulation efficiency. Many operational challenges were faced and overcame by multidisciplinary team during the multi-stage stimulation and flow back (e.g high surface pressure ~12,000 psia and presence of H2S). All eight stages were individually stimulated with high-rate matrix acidizing. Commingle activation, flow back and testing activities were executed in continuous back-to-back operations to fast track well delivery to production. Double degradable balls were used for the first time to open the corresponding FracPORT seat and isolate lower open stages. Two green burners used for the first time in Kuwait, accommodated the high returns during flow back and initial testing. Continued advancements throughout the full well cycle, from well placement to stimulation, culminated in achieving Kuwait’s highest ever gas production rate on the initial test, with low Water-cut at different choke sizes and high Wellhead pressure (+/- 6500 psia) Such outstanding results have encouraged the NKJG asset to fast track the extension of this success to other sweet spots as step-change in unconventional reservoirs, supporting the roadmap towards achieving and sustaining the asset’s production target.
- 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 > Bahrah Field > Marrat Formation (0.99)
Abstract Smart Liners rely on the limited-entry principle where a number of small holes act to distribute acid along the un-cemented reservoir section. Over the past two years, this technique has become a key method for matrix-acid stimulation of ADNOC's carbonate reservoirs. The objective of this paper is to summarize the learnings from more than 100 deployments and tie together the key elements of the hole spacing design, the stimulation job execution, and the performance monitoring. A software algorithm generates the hole spacing design to honor a predefined acid flow distribution along the drain length. Quantification of the stimulation efficiency is addressed in several ways. First, the baseline well performance is established with production tests covering several months and in some cases accompanied by a pre-stimulation production logging test (PLT). The stimulation job is then analyzed and compared against a wormhole model to derive the transient injectivity improvement versus acid volume pumped. After the stimulation, the stabilized performance is analyzed in terms of production testing and occasionally a pressure buildup survey and a PLT. Results have so far been very encouraging. Smart Liners have been deployed predominantly in oil producers and water injectors but a few implementations have targeted tight gas reservoirs. A typical steady-state productivity gain is 100-150% above the baseline unstimulated well and the technique consistently outperforms conventional matrix-acid stimulation techniques. The post-stimulation PLT's show that the entire wellbore contributes to flow, even in extended-reach wells. The majority of the efficiency improvement seems to occur with an acid coverage of 0.5 bbl/ft but some wells benefit from higher acid dosages. A wormhole model developed specifically for this completion-stimulation method can reproduce the observations and helps guide designs of future stimula0tion jobs by suggesting modifications to the hole spacing, which will improve the performance improvement using less acid volume.
- North America > United States (1.00)
- Europe (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.21)
- Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Chalk Formation (0.99)
- Asia > Middle East > Turkey > Selmo Field (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > Al Shaheen Field > Shuaiba Formation (0.99)
- (9 more...)
Abstract Smart Liners rely on the limited-entry principle where a number of small holes act to distribute acid along the un-cemented reservoir section. Over the past two years, this technique has become a key method for matrix-acid stimulation of ADNOC's carbonate reservoirs. The objective of this paper is to summarize the learnings from more than 100 deployments and tie together the key elements of the hole spacing design, the stimulation job execution, and the performance monitoring. A software algorithm generates the hole spacing design to honor a predefined acid flow distribution along the drain length. Quantification of the stimulation efficiency is addressed in several ways. First, the baseline well performance is established with production tests covering several months and in some cases accompanied by a pre-stimulation production logging test (PLT). The stimulation job is then analyzed to derive the transient injectivity improvement versus acid volume pumped. After the stimulation, the stabilized performance is analyzed in terms of production testing and occasionally a pressure buildup survey and a PLT. Results have so far been very encouraging. Smart Liners have been deployed predominantly in oil producers and water injectors but a few implementations have targeted tight gas reservoirs. A typical steady-state productivity gain is 100-150% above the baseline unstimulated well and the technique consistently outperforms conventional matrix-acid stimulation techniques. The post-stimulation PLT's show that the entire wellbore contributes to flow, even in extended-reach wells. The majority of the efficiency improvement seems to occur with an acid coverage of 0.5 bbl/ft but some wells benefit from higher acid dosages. A wormhole model developed specifically for this completion-stimulation method can reproduce the observations and helps guide designs of future stimulation jobs by suggesting modifications to the hole spacing, which will improve the performance improvement using less acid volume.
- Europe (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.21)
- Europe > Norway > North Sea > Central North Sea > Central Graben > PL 018 > Chalk Formation (0.99)
- Asia > Middle East > Turkey > Selmo Field (0.99)
Abstract Shuaiba formation is one of key reservoirs around Oman. Most of big Shuaiba plays are developed since the early days, however some plays were discovered and ranked as low recovery plays. Our focus is to highlight key elements were applied to unlock and accelerate development of one of those fields. The first exploration well was drilled targeting deep Gas reservoirs, the vertical hole shows an indication of HC within XX Shuaiba play. XX Shuaiba play was low relief structure which remains the key risk, so an appraisal well drilled vertically to assess the potential followed by lateral well to perform productivity test. As a result, from few appraisal wells around the field, the key challenges were: Project funding constrains. Steering the wells close to the roof. The reservoir permeability is high, and water is highly mobile. Crude processing Capacity limitations. Produced Water handling. Optimization of wells hook-up process. To overcome and accelerate the project, a strategic note submitted to get a fast approval for the updated FDP. Project strategy to minimize the cost by have rental stations and optimize cost of wells drilling and surface constructions. Well placement was continuously improved by implement different logging solutions (ex: Borehole imaging, Roof indicators …etc.). However, placement is also critical to delay water productions as the zones are vertically connected so mechanical shutoff implemented (Ex: scab liner, straddle packers… etc). In line with subsurface solutions, in surface for wells with High potential and low water cut an extended well test unit were carried on also an introduction of mini station has maximized and accelerate crude production and processing. In addition, major project established to handle the capacity of water and ramp up oil production. To fasten hookup process, LLRTP flow lines commissioned to connect wells to MSV also mobile DG used to power artificial lift down hole equipment till commissioning of OHL. The project recovered the cost in around 5 years with sustained oil production to date.
- Asia > Middle East > Oman (0.56)
- Asia > Middle East > UAE (0.49)
- Geophysics > Borehole Geophysics (0.90)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.35)