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underbalanced operation conference
Kuwait's First Successful Implementation of Managed Pressure Cementing in Deep Jurassic Reservoirs of Kra Al-Maru Field
Ekpe, Joseph (Kuwait Oil Company, KOC) | Al-Shehab, Ahmad Yousif (Kuwait Oil Company, KOC) | Al-Othman, Ahmad Hussain Eissa (Kuwait Oil Company, KOC) | Baijal, Sanjeev (Kuwait Oil Company, KOC) | Marin, German (Weatherford, WFD) | Benyounces, Hakim (Weatherford, WFD) | Aliyeva, Aida (Weatherford, WFD) | Alqabandi, Raghad (Weatherford, WFD) | Al-Fakeh, Bushrah (Weatherford, WFD)
Abstract The development of Najmah-Sargelu (NJ-SR) limestone fractured reservoir, has a significant role in Kuwait Oil Company (KOC) 2040 strategy. To achieve this objective, hydrocarbon potential across the NJ-SR reservoir will have to be evaluated in the West Kuwait of Kra Al-Maru (Figure 1). First and foremost, this section will have to be drilled to planned section TD, cased off and successfully cemented. This paper discusses KOC experiences and best practices implemented to ensure utilizing managed pressure drilling equipment to achieve a successful 7-5/8-in liner cement job at well depth of 16,945ft. MD (15,756ft. TVD), and reservoir pressure and temperature ranges of 12,000 - 15,000psi and 230 - 280 deg F respectively. This new approach to cementing is based on Managed Pressure Drilling technology. It addresses running the 7-5/8- in liner and cementing it in MPD mode. A step-bystep procedure is provided that ensures a constant bottom pressure is maintained throughout the process. Risk assessment showing what can go wrong and mitigations are provided, and the method is described in detail to allow readers comprehend the unique case presented in this paper. Managed Pressure Cementing (MPC) technique in case study well is compared to offset wells in West Kuwait Field where cementing was conducted conventionally. In most cases, the cement bond logs show cement dispersed throughout the annulus with no continuous bond - channels in the cement behind the casing. The most significant new findings from this paper are that, in a couple of wells where there were no losses while pumping cement conventionally- the cement bond logs showed moderate to poor cement behind casing and channels within the cement. Figure 1: Kra Al-Maru Field, West Kuwait This technology offers opportunity to achieve good cement bonding with liner in fractured limestone which can be problematic due to the risk of losses and the presence of hydrocarbons with high pore pressure in West Kuwait NJ-SR intervals. This novelty approach using Managed Pressure Cementing technique to case and cement liners in West Kuwait fields and tight margin reservoir will ensure good cement bond logs behind casing and improve well testing and completions strategies.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.45)
- Geology > Geological Subdiscipline > Geomechanics (0.34)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Kuwait Government (0.49)
- Asia > Middle East > Kuwait > Jafra Governorate > Arabian Basin > Widyan Basin > Kra' Almru Field (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)
- Well Drilling > Pressure Management (1.00)
- Well Drilling > Casing and Cementing > Cement and bond evaluation (1.00)
Abstract Underbalanced drilling is one of the drilling techniques which relies on reservoir fluid influx. After more than 2 decades of the invention of the underbalanced drilling technology, the calculation of the fluid influx into the wellbore is yet to be improved. A knowledge of the fluid influx into the wellbore while drilling is required for accurate hydraulic modelling for designing a successful underbalanced drilling operation. In this paper, the influx from the reservoir is defined by applying a transient mathematical solution with the possibility of incrementing the wellbore length in time. The mathematical model allows for permeability variation along the wellbore length leading to the possibility of formation evaluation while drilling. The results, through few examples, show that permeability is directly affecting the influx magnitude while drilling.
Reservoir Characterization in Transient Wellbore Conditions Resulting from Unintended Hydraulic Fracture Communications Utilizing MPD
Kvalo P. E., M. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Duarte, M. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Vargas, N. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Laird, E. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Sullins, T. (Comstock Resources, Frisco, Texas, United States of America) | Boddy, T. (Comstock Resources, Frisco, Texas, United States of America) | Janes, C. (Comstock Resources, Frisco, Texas, United States of America)
Abstract MPD for reservoir characterization in green field applications is often seen as vital for providing operators with valuable information about the reservoir's physical properties while drilling. This aspect of Managed Pressure Drilling (MPD) in mature fields is not often a driver for implementation as these characteristics are typically well-defined. However, external factors such as unintentional communication between drilling and fracking operations can significantly alter known reservoir characteristics. The proppant exponentially enhances the permeability of both the child and parent well. While the fracturing fluid initially increases the pore pressure and stress environment in the near wellbore region, followed by its subsequent reduction, the rate of which is dependent on the dominant regime: flow back on the parent well, pressure equalization of the reservoir, and/or diffusion of fluid into the drilling mud. The challenges and interactions associated with unintended frac communication and how primary reservoir characteristics are fundamentally altered as a result will be discussed. Additionally, the results of each reservoir characterization test can be interpreted to adjust the plan forward and utilized to navigate these transient wellbore conditions. Thus, providing clear insight into the wellbore's evolving drilling window, enabling the safe drilling and completion of the "fracked into" well.
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > South Dakota > Williston Basin (0.99)
- North America > United States > North Dakota > Williston Basin (0.99)
- (3 more...)
Riser Gas Handling from Theory to Practice: Incorporating Principles to Operational Procedures
Silva, Thiago (Blade Energy Partners, Frisco, Texas, USA) | Gabaldon, Oscar (Blade Energy Partners, Frisco, Texas, USA) | Luis, Romar A. Gonzalez (Blade Energy Partners, Frisco, Texas, USA) | Puerto, Gustavo (Blade Energy Partners, Frisco, Texas, USA) | Torres, Fabian (Blade Energy Partners, Frisco, Texas, USA) | Bedoya, Jorge (Blade Energy Partners, Frisco, Texas, USA)
Abstract This work discusses the experience and results of generating a rig-specific riser gas handling (RGH) procedure based on previous project experiences and the IADC Riser Gas Handling Guidelines developed by the Riser Gas Handling sub-committee of the IADC Underbalanced Operations and Managed Pressure Drilling Committee. In this work the authors differentiate between what should be considered RGH, and what should be considered dynamic influx management, and define the boundaries between both processes. It presents an example procedure under the following premises as main indicators to identify and differentiate the gas in the riser, for example a) high concentration of gas in the mud was detected in the shakers, b) gas units and LEL setting level, c) Undetected influx producing gas expansion in the riser increasing flow out. The presentation includes a brief discussion on the theory involved, preparation required, and responsibilities, and provides an example procedure and process flow diagram.
Is Handling Gas in the Riser a Safe Alternative? Exploring the Limits and Opportunities for Safer Kick Handling During Deepwater Drilling
Gabaldon, O. (Blade Energy Partners, Frisco, Texas, USA) | Humphreys, G. (Stena Drilling, Aberdeen, Scotland UK) | Teixeira, M. L. (Equinor, Sandnes, Norway) | Gonzalez-Luis, R. A. (Blade Energy Partners, Frisco, Texas, USA) | Souza, P. (Blade Energy Partners, Frisco, Texas, USA)
Abstract This work complements previous efforts exploring the opportunity for safer return to operations after an influx event in deepwater drilling operations when an MPD system is installed on the floating rig. Additionally, even kicks taken during conventional drilling, with rigs equipped with adequate RGH equipment, can benefit from an alternative way to address the event. An RGH Envelope is proposed, which can be incrementally adopted in a stepwise approach. For MPD operations, influxes greater than IME circulation limits, but within RGH Envelope limits, can be introduced into the riser and then removed using the Fixed Choke, Constant Output (FCCO) method. In non-MPD operations, all influxes need to be initially addressed by shutting the well on the BOP as soon as possible. Then, for influxes within the equivalent MPD IME limits, the surface RGH system can be engaged and routed to the rig choke, and the influx is completely circulated using Driller's method through the riser system. A potential expansion of this method, for influxes exceeding the original IME limits, but within RGH Envelope limits, can be circulated into the riser and then finalized by using FCCO method. For conventional drilling operations without a rotating control device (RCD) seal installed, consideration should be given to installing the seal assembly in the RCD prior to circulating hydrocarbons to surface with an open BOP. The authors explore the RGH Envelope limits and present guidelines for a comprehensive risk assessment on RGH process, limits, and how it impacts multiple aspects of the operations.
- North America > United States (0.97)
- Europe (0.68)
Abstract Digital Transformation through MPD Automation is revolutionising the oil and gas industry. Digital technologies provide access to higher-quality information about operations performance and allow companies to react quickly when unexpected events occur due to weather or equipment malfunctions/failures. Intelligent MPD (Managed Pressure Drilling) is an advanced form of Digital Transformation that applies sophisticated algorithms to optimise drilling operations. It takes full advantage of Big Data Analytics in order to maximise safety and performance during drilling operations by controlling pressure and flow rate, learning from machine twins, and providing greater insight into their operational performance. Intelligent MPD's ability to monitor real-time variables makes it a safer alternative as it enables faster response times in various situations that arise during the drilling process without manual intervention from personnel onsite. Digital transformation with MPD automation also helps reduce costs associated with manual labour as it requires fewer people for operational tasks and allows for more efficient use of resources (Elvin, 2023 and Sanchez, 2022). Other benefits of Digital Transformation through MPD Automation include improved accuracy in decision-making and greater transparency in operations processes. Advanced algorithms mean companies can make decisions based on reliable, up-to-date data rather than relying solely on human judgement, which can lead to mistakes or misjudgment, which can be costly. Additionally, Digital Transformation provides better visibility into the current state of the wellbore at all times, allowing for quicker response times when unforeseen circumstances occur. This drastically improves safety protocols and reduces potential risks for personnel onsite.
- North America > United States (0.48)
- South America > Argentina (0.29)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Data mining (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
- Information Technology > Security & Privacy (1.00)
- Information Technology > Artificial Intelligence (1.00)
- Information Technology > Architecture > Real Time Systems (0.93)
- Information Technology > Data Science > Data Mining > Big Data (0.71)
Kuwait's First Successful Implementation of Managed Pressure Cementing in Deep Jurassic Reservoirs of Kra Al-Maru Field
Ekpe, J. (KOC Kuwait Oil Company) | Al-Shehab, A. (KOC Kuwait Oil Company) | Al-Othman, A. (KOC Kuwait Oil Company) | Baijal, S. (KOC Kuwait Oil Company) | Marin, G. (Weatherford) | Benyounes, H. (Weatherford) | Aliyeva, A. (Weatherford) | Alqabandi, R. (Weatherford) | Selami, B. (Weatherford) | Al-Fakeh, B. (Weatherford)
Abstract The development of Najmah-Sargelu (NJ-SR) limestone fractured reservoir, has a significant role in Kuwait Oil Company (KOC) 2040 strategy. To achieve this objective, hydrocarbon potential across the NJ-SR reservoir will have to be evaluated in the West Kuwait of Kra Al-Maru (Figure 1). First and foremost, this section will have to be drilled to planned section TD, cased off and successfully cemented. This paper discusses KOC experiences and best practices implemented to ensure utilizing managed pressure drilling equipment to achieve a successful 7-5/8-in liner cement job at well depth of 16,945ft. MD (15,756ft. TVD), and reservoir pressure and temperature ranges of 12,000 - 15,000psi and 230 - 280 deg F respectively. This new approach to cementing is based on Managed Pressure Drilling technology. It addresses running the 7-5/8- in liner and cementing it in MPD mode. A step-bystep procedure is provided that ensures a constant bottom pressure is maintained throughout the process. Risk assessment showing what can go wrong and mitigations are provided, and the method is described in detail to allow readers comprehend the unique case presented in this paper. Managed Pressure Cementing (MPC) technique in case study well is compared to offset wells in West Kuwait Field where cementing was conducted conventionally. In most cases, the cement bond logs show cement dispersed throughout the annulus with no continuous bond - channels in the cement behind the casing. The most significant new findings from this paper are that, in a couple of wells where there were no losses while pumping cement conventionally- the cement bond logs showed moderate to poor cement behind casing and channels within the cement. This technology offers opportunity to achieve good cement bonding with liner in fractured limestone which can be problematic due to the risk of losses and the presence of hydrocarbons with high pore pressure in West Kuwait NJ-SR intervals. This novelty approach using Managed Pressure Cementing technique to case and cement liners in West Kuwait fields and tight margin reservoir will ensure good cement bond logs behind casing and improve well testing and completions strategies.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.45)
- Geology > Geological Subdiscipline > Geomechanics (0.34)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Kuwait Government (0.49)
- Asia > Middle East > Kuwait > Jafra Governorate > Arabian Basin > Widyan Basin > Kra' Almru Field (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)
- Well Drilling > Pressure Management (1.00)
- Well Drilling > Casing and Cementing > Cement and bond evaluation (1.00)
Abstract While drilling the 12" section, a water bearing formation is encountered prior to reaching the target gas reservoir formation. This formation is sporadically-charged across the field requiring a KMW up to 21 ppg. This poses major well integrity challenges as it becomes critical to avoid losses in the resulting narrow mud window and ensuring proper cement placement. Inability to predict the mud window makes it impossible to define the drilling strategy to implement. To understand the drilling challenges, in-depth offset wells analysis was performed. Based on mud weights required to drill across the reference formation, the heat-map for historical KMW was created based on confirmed well control events. It was difficult to predict formation-flow potential. Field geomechanics studies were then carried out to correlate the mapping done earlier. Once possibility of encountering abnormally pressured formation is flagged, in order prevent drilling risks such as loss circulation and poor cementing placement, proactive measures such as: Improved influx monitoring, drilling/cementing fluids optimization, liner-and-tieback system implementation, Managed Pressure Drilling/Cementing, optimized casing design were put in place. The integrated approach led to quick influx detection, proper definition of mud window, i.e. Pore Pressure and Fracture Gradient together, helped to prevent the losses, design of fit-for-purpose bridging strategy to ensure full drilling fluid column at all time while avoiding the cost associated with fluid losses. Drilling the section with Managed Pressure Drilling system (MPD) and low mud weight led to achievement of high ROP leading to substantial time saving. The Liner string was run and Managed Pressure Cementing (MPC) was implemented to manage the equivalent circulating density (ECD), avoid losses and ensure good zonal isolation. Overall non-productive time was reduced by 40% as compared to the offset wells in the area. Integrated drilling approach delivers great gains when there is good understanding of the well integrity challenges and solutions are tailored to solve identified problems.
- North America > United States (0.95)
- Europe > Norway > Norwegian Sea (0.66)
- North America > Canada > Alberta > Woodlands County (0.40)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.28)
- Asia > Middle East > Bahrain > Awali Field (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Tengiz Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Korolev Formation (0.99)
- Asia > Middle East > Israel > Southern District > Southern Levant Basin > Efe Field (0.97)
Abstract The strategic location of the Haynesville unconventional dry-gas shale, near some of the world largest petrochemical complexes, export facilities, and in proximity with the Gulf of Mexico makes it one of the most revenue attractive plays in the USA. However, with wellhead pressures in excess of 9,000 psi and bottom hole temperatures reaching 380°F, this deep shale is classified as a challenging dry-gas high pressure-high temperature basin. The conservative and conventional approach of using extremely high mud density to deal with pressure uncertainties and possible dry gas entering the annulus while drilling, making connections, or tripping combined with the high temperature detrimental effect over the drilling fluid properties, have made the operators incur time consuming activities during the well construction process in this area. After 4 years and 2 million feet of long reach horizontal production hole sections successfully drilled with MPD in this HPHT Texas-Louisiana shared unconventional gas play, our experiences after strategically developing and utilizing a state of the art precise, fast, and reliable-low maintenance electric set point choke in combination with reduced equipment footprint and crew on a setup to comply with easy mobilization for the rig to fit on the cost-efficiencies improvement plans from operators and rig contractors in the area are described on this document.
- North America > United States > Texas (1.00)
- North America > United States > Louisiana (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.55)
Perforating Using MPD Techniques: Design and Execution
Fernandes, André Alonso (Petrobras) | Ferreira, Davi Valle (Petrobras) | Schnitzler, Eduardo (Petrobras) | de Castro, Fabiano Hamilton (Petrobras) | do Carmo, Isadora Luisa de Paiva Goncalves (Petrobras) | Santana, Pedro Menezes (Petrobras) | Roman, Roger Savoldi (Petrobras)
Abstract An appraisal well was drilled in Brazilian pre-salt area using overbalance drilling fluid, with conventional techniques. While drilling reservoir (in a 12 1/4" phase), total losses were found. Unsuccessful attempts with LCM and cement pills revealed that only MPD/PMCD techniques could deliver the well to TD. It was decided to anticipate the installation of the 9 5/8" casing, covering only the upper portion of the reservoir, and well was suspended. The remaining reservoir could be drilled later with a rig equipped with MPD system. This well was designed as a 2-zones intelligent completion in cased hole configuration. Due to the fluid losses a new design had to be considered. Due to reservoir uncertainties, definition on the separation between zones would only be taken after drilling the remaining reservoir section. To overcome this challenge without adding time and complexity to the overall design, the best solution was to perforate the cased hole section after drilling the remaining section, meaning doing it with reservoir communicated to the wellbore and in PMCD mode. Several options were evaluated to design the TCP operation in PMCD. Well control strategies, contingencies, thermal effects, and dynamic shocks were considered. The solution consisted in running the TCP with a closed string, without NRVs and having robust contingencies in case of washout or drillpipe failure after perforating. The well was drilled, and total fluid losses occurred again. It was then successfully perforated still in PMCD, then lower and upper completion were installed. Despite these challenges, this was the fastest intelligent completion in all Petrobras pre-salt fields so far.
- South America > Brazil (1.00)
- North America > United States > Louisiana (0.24)