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Collaborating Authors
Enhancing Rigless Intervention Efficiency in Bi-Lateral Oil Producer Through Coiled Tubing Optical Telemetry, Multilateral Tool, and Single-Phase Retarded Inorganic Acid: A Case Study from South Kuwait
Al-Mutairi, F. (Kuwait Gulf Oil Company) | Sanyal, S. (Kuwait Gulf Oil Company) | Al-Mutawa, M. (Kuwait Gulf Oil Company) | Al-Ayyaf, E. (Kuwait Gulf Oil Company) | Al-Bader, A. (Kuwait Gulf Oil Company) | Al-Otaibi, A. (Kuwait Gulf Oil Company) | Al-Anezi, T. (Kuwait Gulf Oil Company) | Al-Dhafiri, S. J. (Saudi Arabian Chevron) | Al-Najim, A. (Saudi Arabian Chevron) | Aldawaish, M. (Saudi Arabian Chevron) | Hedi Slama, M. (SLB) | Badrawy, K. (SLB) | Molero, N. (SLB) | Ujagar, U. (SLB) | Adel Sebaih, M. (SLB) | Ayyad, H. (SLB)
Abstract Developments in horizontal drilling and completion techniques have enabled drilling an increasing number of wells. In the pursuit of cost optimization and enhanced recovery through maximized reservoir contact, operators are placing special interest on multilateral completions. However, multilateral wells add complexity to rigless intervention and production enhancement work as those activities are heavily dependent on lateral accessibility. An advanced rigless intervention in a multilateral well relied on coiled tubing (CT) equipped with optical fiber and real-time downhole measurements and a multilateral entry tool (MLT). Downhole readings included casing collar locator (CCL), gamma ray, CT internal pressure, annulus pressure, annulus temperature, and axial force. Optical telemetry was used for lateral identification and for optimal actuation of the orienting and bent sub-components of the MLT while profiling and accessing the lateral. Throughout the stimulation treatment, optical telemetry was instrumental to understanding changing downhole conditions and keeping injection rates below fracturing pressure. The candidate well was a carbonate bi-lateral oil producer completed through 6 1/8-in. uncased horizontal sections. Both laterals exhibited average length of 2,400 ft, and the reservoir featured a bottomhole temperature near 140ยฐF and bottomhole pressure close to 3,050 psi. Because of real-time optical telemetry, profiling of the lateral was completed in less than 3 hours, which represents 50% reduction of the average profiling time in similar wells. Both laterals were stimulated via CT with a total of 4,000 bbl of single-phase retarded inorganic acid system (SPRIAS), which enables carbonate stimulation with better wormholing performance than emulsified acid while eliminating its drawbacks, such as high CT friction pressure and potential emulsion issues. In comparison with emulsified acid, the pumping time with SPRIAS was 35% lower, bringing additional efficiency to the intervention. The ability to make fast, informed decisions based on optical telemetry was the cornerstone of this intervention approach. This paper documents a value case study for CT rigless intervention in South Kuwait, where the combination of an array of technologies, such as CT optical telemetry, MLT, and SPRIAS, enhanced rigless intervention efficiency, reducing total operation time by 30%, when compared to conventional CT stimulation approach in multilateral wells.
- North America > United States (1.00)
- Asia > Middle East > Kuwait (0.62)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion (1.00)
A Tailor-Made Approach for Temporary Well Suspension Saves Cost for Remedial Stimulation and Well Activation: A Case Study from Northern Kuwait
Ahmad Mohammed AlMatar, Mohammed (Kuwait Oil Company) | Al-Bahar, Zakaria (Kuwait Oil Company) | Mahmoud Bastaki, Fahad (Kuwait Oil Company) | BinOmar Chong, Mizan (Kuwait Oil Company) | Hamed Barki, Jassim (Kuwait Oil Company) | Jamal, Mariam (Kuwait Oil Company) | Al-Mehena, Mehanna (Kuwait Oil Company) | Slama, Mohamed Hedi (SLB) | Badrawy, Kareem (SLB) | Molero, Nestor (SLB) | Pochetnyy, Valentin (SLB) | Adel Sebaih, Mohannad (SLB)
Abstract Following the rig-based well testing stage, completion programs of high-pressure wells in North Kuwait call for well killing with heavy oil-based mud (OBM). The workover rig is then demobilized, and production flowlines are installed. Well activation plans are carried out riglessly, and coiled tubing (CT) is instrumental to bringing the wells back to sustainable production. One of the major drawbacks from this practice is the formation damage generated by the OBM, which often requires additional interventions for remediation. To address this limitation, a new approach leveraging instrumented CT for temporary well suspension was recently implemented. Real-time downhole telemetry is enabled by an optical line installed in the CT pipe and used to accurately set a through-tubing inflatable packer (TTIP). Once the latter is anchored at the planned depth, above the interval open to the formation, CT is disconnected from the packer assembly, and the fishing neck is protected with a sand plug. CT is then retrieved to surface, and a slickline dump bailer is run to spot cement on top of the sand plug. Once the cement has set, CT is run to displace the wellbore to kill fluid. Two pilot wells were selected to implement this new approach for temporary well suspension. Both wells had a maximum potential wellhead pressure in the order of 7,400 psi, and 15.0-ppg OBM was originally planned for well suspension purposes. Upon completion of the zonal testing program - which included initial stimulation, well activation, and flowback - instrumented CT was run with high- pressure rotary jetting to condition the TTIP setting depth and displace the wellbore with brine, after which, a shut-in wellhead pressure near 2,000 psi was observed. In the next CT run, TTIP was set close to the end of the production tubing, and critical stages, such as depth correlation, packer inflation, and packer anchoring testing were closely controlled via real-time downhole measurements. Additional verification of the TTIP effective seal was carried out before the CT was disconnected from the packer assembly through an inflow test relying on live downhole pressure monitoring. Once the TTIP released, the temporary suspension was completed following the methodology described above. Finally, the wells were observed at surface with zero pressure for more than 24 hours, receiving acceptance from the operator. This alternative approach for temporary well suspension represents an innovative solution to bring wells back into production without additional restimulation or well activation. This methodology greatly relies on CT real-time downhole telemetry, and operators from the Middle East can benefit from the experience gained in this project.
- 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)
A Custom-Fit Approach for Temporary Well Suspension Saves Remedial Stimulation and Well Activation in North Kuwait
Bastaki, Fahad Mahmoud (Kuwait Oil Company) | AlMatar, Mohammed Ahmad Mohammed (Kuwait Oil Company) | Al-Bahar, Zakaria (Kuwait Oil Company) | Chong, Mizan BinOmar (Kuwait Oil Company) | Barki, Jassim Hamed (Kuwait Oil Company) | Jamal, Mariam (Kuwait Oil Company) | Al-Mehena, Mehanna (Kuwait Oil Company) | Slama, Mohamed Hedi (SLB) | Badrawy, Kareem (SLB) | Molero, Nestor (SLB) | Sunagatov, Rustem (SLB) | Sebaih, Mohannad Adel (SLB)
Abstract Following the rig-based well testing stage, completion programs of high-pressure wells in North Kuwait call for well killing with heavy oil-based mud (OBM). The workover rig is then demobilized, and production flowlines are installed. Well activation plans are carried out riglessly, and coiled tubing (CT) is instrumental to bringing the wells back to sustainable production. One of the major drawbacks from this practice is the formation damage generated by the OBM, which often requires additional interventions for remediation. To address this limitation, a new approach leveraging instrumented CT for temporary well suspension was recently implemented. Real-time downhole telemetry is enabled by an optical line installed in the CT pipe and used to accurately set a through-tubing inflatable packer (TTIP). Once the latter is anchored at the planned depth, above the interval open to the formation, CT is disconnected from the packer assembly, and the fishing neck is protected with a sand plug. CT is then retrieved to surface, and a slickline dump bailer is run to spot cement on top of the sand plug. Once the cement has set, CT is run to displace the wellbore to kill fluid. Two pilot wells were selected to implement this new approach for temporary well suspension. Both wells had a maximum potential wellhead pressure in the order of 7,400 psi, and 15.0-ppg OBM was originally planned for well suspension purposes. Upon completion of the zonal testing program - which included initial stimulation, well activation, and flowback - instrumented CT was run with high-pressure rotary jetting to condition the TTIP setting depth and displace the wellbore with brine, after which, a shut-in wellhead pressure near 2,000 psi was observed. In the next CT run, TTIP was set close to the end of the production tubing, and critical stages, such as depth correlation, packer inflation, and packer anchoring testing were closely controlled via real-time downhole measurements. Additional verification of the TTIP effective seal was carried out before the CT was disconnected from the packer assembly through an inflow test relying on live downhole pressure monitoring. Once the TTIP released, the temporary suspension was completed following the methodology described above. Finally, the wells were observed at surface with zero pressure for more than 24 hours, receiving acceptance from the operator. This alternative approach for temporary well suspension represents an innovative solution to bring wells back into production without additional restimulation or well activation. This methodology greatly relies on CT real-time downhole telemetry, and operators from the Middle East can benefit from the experience gained in this project.
- 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)
World's First Successful Coiled Tubing Intervention to Stimulate Four Laterals in a Single Trip
Matar, Khaled M. (Halliburton) | Al-Mutairi, Abdullah B. (Kuwait Oil Company) | Khandelwal, Nakul (Halliburton) | Chawla, Sapna (Halliburton) | Alkreebani, Mohammad (Halliburton) | Robles, Fernando (Halliburton) | Al-Obaidi, Abdul Mohsen (Kuwait Oil Company) | Al-Otaibi, Khaled (Kuwait Oil Company) | Al-Azmi, Mohammad (Kuwait Oil Company) | Al-Mehanna, Mehanna (Kuwait Oil Company) | Saleh, Buthainah (Kuwait Oil Company) | Al-Bahar, Zakaria (Kuwait Oil Company) | Abdul Azim, Shaikh (Kuwait Oil Company) | Attia, Adel (Kuwait Oil Company)
Abstract Drilling a multilateral well is generally recommended for several reasons such as achieving higher productivity indices and improving recovery in tight, low-permeable zones. While the many benefits of multilateral wells are attractive, they also have drawbacks which make these wells challenging. A key challenge is how to effectively stimulate all the laterals after they have been drilled. This paper presents the application of a unique intervention technique in a multilateral well to stimulate several laterals in a single run. To increase reservoir contact area the operator drilled a multilateral well composed of 4 legs. This was carried out despite the absence of proven ways to stimulate each lateral individually. This intervention would also present the following challenges: Well displacement and stimulation would require multiple re-entries into each lateral, all conducted from a drilling rig. All the laterals were known to branch off from the low side of the bore, so individual lateral and main-bore selection would be complex. Extended reach laterals require accurate friction lockup modelling and mitigations. The unique solution presented in this paper includes the use of real-time Hybrid cable coiled tubing (RTHCT) technology. This incorporates a hybrid cable installed in the coiled tubing (CT) string and a modular sensing bottom-hole assembly (MSBHA). Electrically controlled indexing tool, inclination sensor, tool-face sensor, and hydraulic knuckle joint were used as part of the BHA to enable real-time diagnostics and dynamic controls from surface to successfully enter the lateral legs. The MSBHA enabled the orientation of the BHA electrically to any position required using software to determine and control the exact position of the BHA. This paper presents a solution to all the above-mentioned challenges. It discusses the successful implementation of the RTHCT to displace and stimulate all the 4 laterals in a single CT trip in less than seven days, pumping over 7,000 bbls of various chemical systems and covering an open-hole length of 11,176 ft. Unlike other technologies, the RTHCT technology confirmed entries into the laterals without the need to tag the bottom of the lateral, saving substantial time. Enabling re-entry in these 4 laterals represented a world record translating into major efficiency improvements and cost savings for the project. This intervention also represented the first time in Kuwait that more than 2 laterals have been accessed in a CT run.
Successful Intervention into a Six-Leg Multi-Lateral Well Using an Electrical MultiLateral Tool Deployed on Real-Time Hybrid Coiled Tubing for Acid Stimulation of a Kuwait Field - A Case Study
Bastaki, Fahad (Kuwait Oil Company) | Al Matar, Mohammed (Kuwait Oil Company) | Omar, Mizan (Kuwait Oil Company) | Barki, Jassim (Kuwait Oil Company) | Jamal, Mariam (Kuwait Oil Company) | Al-Mutairi, Fayez (Kuwait Oil Company) | El-Aziz, Sabry (Kuwait Oil Company) | Albahar, Zakaria (Kuwait Oil Company) | Al-Mehena, Mehanna (Kuwait Oil Company) | Khandelwal, Nakul (Halliburton) | Chawla, Sapna (Halliburton) | Gaur, Rishika (Halliburton) | Alkreebani, Mohammad (Halliburton) | Travesso, Joshua (Halliburton)
Abstract Multilateral technology offers multiple benefits to oil and gas operators, including lowering the field development cost by minimizing wellsite construction work and increasing reservoir contact leading to enhanced reservoir production. To gain full advantage of these complex wells, they must be stimulated properly. The operator in Kuwait drilled, cased, and cemented a six-leg, level IV multilateral well targeting two different formations, the upper and lower Tuba. This provided various production options and the flexibility of taking production from either the lower or upper laterals or even all six laterals to help mitigate the risks of drilling horizontal or directional wells. As such, multilateral technology can positively transform the economic viability of reserves in marginal fields. Exploiting the advantages of multilateral technology requires a multi-disciplinary approach to select appropriate well structure, completion design, re-entry flexibility, and production longevity. Intervention in this level IV multilateral well presented several challenges, such as Oil Based Mud (OBM) in all the laterals, encountering a fault in one of the laterals while drilling, and high shale content that can lead to stuck Coiled Tubing (CT) and the loss of fluid returns. Real-time hybrid cable CT was chosen along with an electric multilateral tool to mitigate the various risks involved. This solution includes a hybrid fiber optic and electrical cable installed in the CT string and a modular Bottom Hole Assembly (BHA) equipped with various sensors. An electrically controlled indexing tool, inclination sensor, tool- face sensor, downhole camera, hydraulic knuckle joint, and pulsating stimulation tool were used as part of the BHA to enable real-time diagnostics and dynamic controls from the surface to successfully enter and stimulate all the lateral legs. This configuration helped identify each different lateral without the need to tag the bottom of each lateral. The paper focuses on applications, strategies, and benefits of specific tool configurations developed for multilateral well intervention, enabling the stimulation of all the lower Tuba laterals. This was a particularly challenging operation due to shale in one of the laterals causing several instances of stuck CT with the possibility of a collapsed hole mitigated by using the real-time camera in the BHA. This paper includes strategies that address proper tool selection, confirmation of lateral entry, hydrostatic pressure balance, borehole stability, and acid design. It also explores the potential of new, synergistic strategies and work processes planned for stimulation of the upper Tuba field.
- Asia > Middle East > Kuwait (1.00)
- Asia > Middle East > Iraq > Basra Governorate (0.24)
- 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)
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