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Collaborating Authors
service provider
An Industry Game Changer Approach in Managing Medium-High Complexity of Well via Robust Risk & Reward Contract Strategy – A Win-Win Concept for Both Operators & Service Providers
Mohd Mokhtar, Mohd Khaidir Bin (PETRONAS) | A Kadir, Norazan Bin (PETRONAS) | Hamzah, Nurul Ezalina Binti (PETRONAS) | Xiong, Choi Yee (PETRONAS) | Yahaya, Fadzil Bin (PETRONAS) | W Othman, W M Safwan Bin (PETRONAS) | Md Saleh, Siti Noor Asheiah Binti (PETRONAS) | Leong, Chua Hing (PETRONAS) | Khairul Anuar, Khairina Binti (PETRONAS) | Amsidom, Amirul Adha Bin (PETRONAS) | Harun, Raihan Bin (PETRONAS) | Nordin, Azri Bin (PETRONAS)
Abstract The efficient and successful execution of oil and gas well projects are critical for companies operating in this industry. However, the conventional contract model, where operators company bear the entire economic and operational risk, has proven to be a deterrent in executing medium to high complexity wells. This manuscript explores a risk & reward contract strategy as an alternative approach to overcome the limitations of conventional contracts. The risk & reward model promotes risk sharing between the operator company and service providers, offering incentives for successful operations while mitigating the impact of failures. This manuscript discusses the benefits, challenges, and implementation considerations associated with adopting risk & reward contracts in the oil and gas industry.
To reach the goals outlined in the last SPE Live, "Methane Emissions Management for Operations", somebody has to actually "do something." This is where the Service Providers' come in. They are the actual part of the equation, collecting the data that can be read, stored, manipulated and ultimately utilized to define the measured results. This SPE Live features two speakers on the service side of the methane emissions management business. Their goal is to get the data that can ultimately be reported, including high-end research into effectively capturing the measurements and reading and quantifying the results for mitigation.
Management of Facilities Services Across ADNOC Group Companies
AlMazrouei, Mouza (Quality Management Department, Abu Dhabi, UAE ADNOC HQ, Abu Dhabi, UAE) | Ahmed, Reda Hashem (Quality Management Department, Abu Dhabi, UAE ADNOC HQ, Abu Dhabi, UAE) | Muckattu, Joseph (Quality Management Department, Abu Dhabi, UAE ADNOC HQ, Abu Dhabi, UAE)
Abstract ADNOC Group B&S managing its facilities across ADNOC Group Companies by planning, executing, and monitoring all facility services involved in building maintenance services, office space management, building asset management, and soft services by using Computer Aided Facility Management (CAFM) system. CAFM system is a specific type of facility management system that allows users to optimize a lot of customer-oriented services in an organization, such as facilities services, office space management, building assets management, and so on. Additionally, CAFM system allows for planning, executing, and monitoring of various activities within facilities once the building is ready after construction handover. ADNOC Group B&S is adding Service Provider contracts in the system and managing Service Providers operational scope of work such as Assets, Buildings, Resources, Maintenance Schedules, Spare-parts, Service Level Agreement (SLA) and Key Performance Indicator (KPI). Also, CAFM System h a s mobile solution which enabled ADNOC Group B&S to facilitate the Service Provider to perform real-time maintenance activities and allow business owners to monitor the Service Provider work-orders/service requests. One of the important tools that enable ADNOC Group B&S to have a visualization of information is by utilizing the Data Analytics and Business Intelligence dashboards.
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract Bit selection is one of the critical decisions that has traditionally been the responsibilities of Drilling Engineers based on the offset wells’ historical experiences to the planned well. This approach has limitations on the depth of the analysis, which could produce inaccurate or not-representative results. This paper will present a comprehensive, improved and optimized process along with fully automated software application for bit selection, generating reachable and more consistent outcomes and goals. The first step was the standardization of KPI calculations, which included cost per foot, rate of penetration, and footage. This is critical to help streamline and normalize KPI calculation methods across all varieties of operation types and service providers within the drilling activities. This was followed by a complex and detailed statistical analysis including the analysis of all related drilling runs that are repeatable and achievable. The statistical analysis is based on an extensive number of drilling parameters/observations for each drilling run including drilling systems, geological formations, mud attributes, WOB, rig types, service providers, encountered drilling troubles and many other critical parameters, which impact the overall performance of the bit. Secondary analysis provides a way to measure the consistency of the performance of any specific bit. This is to avoid the use of bits that do not show a consistent performance on similar applications. The implementation of this methodology has been transformed into a web-based solution for ease of access and use. By using this web-based solution, Drilling Engineers have significantly improved the drilling performance of the wells and reduced the cost per foot. In addition, the application enables the benchmarking of newly designed bits with legacy best performance bit runs under any defined condition. This feature is vital to help increase competition and eliminate single source applications where applicable.
- Asia > Middle East (0.69)
- North America > United States (0.47)
Limbayong: Decoding Industry Top Decile Reservoir Complexity for Marginal Deepwater Development
Mohamed Najib, Mohamed Aiman (PETRONAS Carigali Sdn. Bhd) | Phoon, Yong Ken (PETRONAS Carigali Sdn. Bhd) | Wan Shamshudin, Wan Fatimah (PETRONAS Carigali Sdn. Bhd) | Mustapa, Shazana Sofia (PETRONAS Carigali Sdn. Bhd) | Khalid, Aizuddin (PETRONAS Carigali Sdn. Bhd) | Yusof, Yunus Alwi (PETRONAS Carigali Sdn. Bhd)
Abstract PETRONAS Carigali (PCSB) has developed a solution to monetize industry top decile worth reservoir complexity in the deepwater environment via Limbayong field, Malaysia. The field complexity is acknowledged by Independent Project Analysis (IPA) as industry top decile reservoir complexity due to severe elongated structure (30km length, 2.5km width) with varying faults frequency, vertical intercalation of thin-bed, thick sand reservoir and lateral compartmentalization which impend effectiveness of well drainage and pressure maintenance. The four (4) appraisal wells result since 2002 give diverse subsurface understanding, indicated possible different depositional model and greater degree of complication. This paper describes the key development challenges and strategies that significantly improve the field value proposition for FID. PCSB pivoted to focus assessment on low realization case for development. It generated advanced reservoir mapping to simulate sand distribution and concentration through incorporated faults re-interpretation, refined grid resolution, and change of facies prediction, increasing the stratigraphic compartments. The team performed integrated subsurface-surface flow assurance modeling and validated turndown limit for production and operation. Subsequently, iterated concepts for incremental reservoir recoverable by high-grading producer-injector pairing, wells-facilities design provision for a base, upgrade, or future tie-in. The team formulated industry collaboration (IC) studies in each FEL phase with drivers for deepwater technology enablers implementation in EPCIC primarily via concept selection, engineering standardization, and design competition. Each distinct concept is ratified with project economics group value chain evaluation and stakeholders’ alignment. The breakthrough signifies merit in the key strategies and templates to overcome similar-scale project complexity with viable business cases. The IC affirmed cost proposition of 20 to 30% lower than industry average for deepwater wells and facilities, ensuring it to be positioned in top quartile project performance. It re-defined minimum technical design and demonstrated a prominent value trade-off for scaling-up concepts. It drives momentum to monetize high complexity reservoirs even further in the deepwater environment, which otherwise remains undeveloped. There is potential for replication throughout nearly 800MMboe scattered fields within deepwater offshore Sabah, Malaysia. Deepwater offshore has a niche role in bridging global transition between energy mix offering and net-zero economy target. It produces among the industry's smallest carbon footprints yet with high economic efficiency. Consolidated and efficient development strategies accelerate the decarbonization pathway. It advocates a hybrid capital project management model to manage extreme uncertainties with design thinking, lean startup, and agile approach.
- North America > United States > Texas (0.69)
- Asia > Malaysia > Sabah > South China Sea (0.35)
- Geology > Sedimentary Geology > Depositional Environment (0.47)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.34)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block G > Limbayong Field (0.99)
- Africa > Middle East > Libya > Al Wahat District > Sirte Basin > Sabah Field (0.98)
Abstract In order to realize the benefits of the digitalization and automation of production and processing systems, users first need to increase the level of integration, controllability and monitoring capabilities of each component applied. Therefore, digital twins turn out to be a highly important asset not only for designing greenfield applications, but also for improving brownfield machines. Up to now, digital twins were barely implemented to their full potential throughout the design, integration, and operation phases of production and processing equipment. Based on the experiences gained during the development of a subsea valve actuator, this paper highlights the importance of the digital twin to speed up the engineering and qualification of an innovative mechatronic system, reducing not only the time to market, but also increasing quality and allowing a fast reaction to the experience of the users. As a perspective, the paper shows how an accurate digital twin is a key to successful integration of a new component into complex machines. This includes the entire product lifecycle, from the conceptual work of a system and its virtual commissioning up to remote cloud-based monitoring systems. This paper finishes with an overview of some of the challenges which need to be resolved by the cooperation among different players in order to allow a wide and deep application of Digital Twin in the energy sector industry.
Every activity within a well alters the pressure being exerted on the open hole, and every mitigation technique attempts to maintain the desired pressure within acceptable limits. If the pressure becomes too low, kicks, borehole breakouts, and hole collapse are the primary consequences (Fig. 1). Pressure that is too high can damage the reservoir, induce fluid losses, and slow down operations. When these unfortunate events occur, remedial actions are usually necessary, increasing safety exposure, nonproductive time, and the overall costs of the project. To mitigate these concerns, operators have used the techniques of managed-pressure drilling (MPD) to maintain annular pressure and create a pressure-tight barrier against drilling hazards and manage inflow from the formation during drilling. While conventional drilling uses the hydrostatic pressure of the drilling mud to manage the pressure of the wellbore, MPD uses a combination of surface pressure, hydrostatic pressure, and annular friction to balance the exposed formation. Over the decades, MPD has been associated as a technology that is used only on problematic wells and only as a last resort. However, recent developments have highlighted that managing pressure is not just for drilling operations or just the most challenging wells. When integrated at the beginning of operations as part of a comprehensive well plan, managing pressure becomes a performance-enhancing solution for any type of well classification, including development, directional, multilaterals, and horizontals. Wellbore stability is maintained throughout the entire operation and pressure is dynamically altered in the annulus, enabling any operation to become faster with fewer challenges while delivering a more productive well and reducing overall costs and exposure to hazardous risks. The managed-pressure approach has even been leveraged to fully optimize a field/reservoir development program. An example of how MPD techniques can be incorporated into an overall well plan occurred on an ultradeepwater exploration well drilled by TotalEnergies in the Mexican waters of the Gulf of Mexico (SPE 200503). The operator and the service providers wanted to manage the pressure during the entire well program—including drilling, tripping, running casing, and cementing—to address pore pressure uncertainty, pressure ramp increase, and a narrow pore pressure/fracture gradient (PP/FG) window. The seafloor rested under 10,748 ft (3276 m) of water, and with the exploratory nature of the well, the conventional solution involved an excessive number of casing strings and an overbalanced mud weight (MW). Integrating MPD techniques enabled the operator to adjust the bottomhole pressure instantaneously, the result being a recognition that conventionally cementing a string of 13⅜ -in. casing to isolate the critical formation and safely continue drilling further stages of the well was impractical. To make the situation even more challenging, the engineers did not precisely know the size of the hole. A collaboration between the engineering teams of the operator, the cementing service provider, and MPD professionals resulted in a generated plan. A tail slurry of 15.86 ppg (1.90 SG) followed a 12.52 ppg (1.50 SG) lead gas-tight slurry. At a total depth of 13,622 ft (4152 m), the combination kept the equivalent circulating density (ECD) at 9.18 ppg (1.10 SG) without exceeding 9.51 ppg (1.14 SG). At the casing shoe, located at 12,801 ft (3902 m), the plan called for a 9.01 ppg (1.08 SG) without exceeding 9.35 ppg (1.12 SG), as shown in Fig. 2.
- North America > Mexico (0.36)
- North America > United States (0.35)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
Every activity within a well alters the pressure being exerted on the open hole, and every mitigation technique attempts to maintain the desired pressure within acceptable limits. If the pressure becomes too low, kicks, borehole breakouts, and hole collapse are the primary consequences (Figure 1). Pressure that is too high can damage the reservoir, induce fluid losses, and slow down operations. When these unfortunate events occur, remedial actions are usually necessary, increasing safety exposure, nonproductive time, and the overall costs of the project. To mitigate these concerns, operators have used the techniques of managed-pressure drilling (MPD) to maintain annular pressure and create a pressure-tight barrier against drilling hazards and manage inflow from the formation during drilling.
- North America > United States (0.16)
- North America > Mexico (0.16)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
New Methods for Improving Drilling Performance: The Power of Digital Workflows
Aguiar, Romulo (Schlumberger) | Barreto, Diogo (Schlumberger) | Tocantins, João Pedro (Schlumberger) | Barr, Alex (Schlumberger) | Lima, Laura (Schlumberger) | Li, Denis (Schlumberger) | Hemerly, Adriano (Schlumberger) | Martins, Guilherme (Schlumberger) | Lima, Flank (Schlumberger) | Sortica, Emanuel (Schlumberger) | Teixeira, Paulo (Schlumberger)
Abstract After 10 years of Brazilian presalt exploration and development, the carbonate reservoirs continue to pose drilling challenges, leading to unwanted bottomhole assembly (BHA) trips due to severe shock and vibration, low rates of penetration (ROP), and premature drill-bit cutting structure damage. Today, industry efforts to improve the performance in the Brazilian presalt carbonates are driven by trial and error, which is very costly in the ultradeepwater drilling environment. The adoption of a collaborative mindset since 2012 between a service provider and operator with the desire to bring about a step change in drilling efficiency on the Brazilian presalt cluster enabled a systematic learning framework to capture, evaluate, and reuse knowledge from drilling dynamics, geological, and petrophysical aspects. The innovation of this work is the implementation of an improved, fully digital bit design workflow, integrating calibrated 4D dynamic simulation model and petrotechnical expertise from drilling engineering, geomechanics, geology, and petrophysics groups to continue to push the drilling performance envelope in the challenging Brazilian presalt application.
- South America > Brazil (0.97)
- North America > United States > Texas (0.93)
- Geology > Geological Subdiscipline (1.00)
- Geology > Structural Geology > Tectonics > Salt Tectonics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Buzios Field > Guaratiba Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Barra Velha Formation (0.99)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- (2 more...)
- Well Drilling > Drillstring Design (1.00)
- Well Drilling > Drilling Operations > Drilling optimization (1.00)
- Well Drilling > Drill Bits > Bit design (1.00)
- (2 more...)
Enhancing Drill Bit Connections for Reliability and Longevity
Allison, Cliff (Baker Hughes Company) | Borders, Zachary (Baker Hughes Company) | Donaldson, Justin (Baker Hughes Company) | Grimes, Robert E. (Baker Hughes Company) | Lee, Roger K. (Baker Hughes Company) | Slavens, Stephen (Baker Hughes Company) | Daechsel, Dustin (Shell Oil Company)
Abstract Pursuit of drilling the technical limit has been a primary driver of cost and cycle time reduction from the onset in North America shale. This is increasingly evident in today's downhole mud motors, where motors designed to drill in 6.75 in. hole are now rated for 500+hp and over 10,000 ft-lbs of torque. Every unit of power added stresses current materials to the limit and increases the risk of mechanical failure. As will be demonstrated in the following sections, the increased power delivered to the bit now exceeds the strength and reliability of the standard 3 ½ REG connection for drill bits. The integrity and longevity of the drill bit pin connections is the primary focus of this paper. Details are provided of the technical aspects of drill bit solutions that meet current drilling requirements and recognizes industry trends that will continue to present future challenges for bit connections. This paper also describes the collaborative partnership between an operator and bit service provider that led to success and the development of a long term plan for continuing success.
- North America > United States > Wyoming > Laramie Basin > Niobrara Formation (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (34 more...)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Well Drilling > Drill Bits > Bit design (0.96)
- Well Drilling > Drilling Operations > Directional drilling (0.94)
- Well Drilling > Drillstring Design > Drill pipe selection (0.68)