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Results
An Evolved Approach to Performing Underbalanced Perforating Interventions in Mexico: A Step-Change Improvement in Efficiency, Reliability, and Safety
Narcizo, O. Melo (PEMEX) | Aguilar, A. Martinez (PEMEX) | Mendo, A. Rosas (PEMEX) | Gordillo, J. C. (PEMEX) | Ramondenc, P. (Schlumberger) | Burgos, R. (Schlumberger) | Basurto, J. R. Cervantes (Schlumberger) | Rodriguez, F. L. (Schlumberger)
Abstract An innovative approach to underbalanced perforating in horizontal and highly deviated wells uses a new perforating head specifically developed to leverage the conveyance and real-time telemetry capabilities of coiled tubing (CT) equipped with fiber optics. The results and advantages of this approach have been demonstrated in wells in mature Mexican fields featuring significant reach and pressure limitations. In recent years, CT equipped with real-time fiber-optic telemetry has been a method of choice to perform interventions in deviated or horizontal wells, as it provides a cost-efficient and flexible alternative to heavier wired CT. In the Mexican fields, this real-time telemetry capability is used to accurately place the guns thanks to downhole casing collar locater and gamma ray tools. The need for pumping fluids to enable detonation, often performed during typical CT perforating operations, is eliminated through the use of a downhole microprocessor-controlled firing head, which is directed by commands sent from surface through the optical fiber. The result is a nearly instantaneous detonation downhole and positive confirmation provided in real time through an array of sensors in the bottomhole assembly (e.g., accelerometers, pressure, and temperature). The absence of working fluid eliminates any concern of hydraulically loading the well or the need for shut-in, thus significantly reducing the extent of deferred production. It also mitigates uncertainties linked to the influence of downhole conditions on the behavior of working fluids or the potential malfunctions of drop balls. This system is capable of multizone, selective detonation, therefore improving operational flexibility through reduced gun runs. It is also compatible with any other traditional CT service and can easily be combined with a bridge plug setting, a nitrogen lift, or a cleanout within the same run. The approach and its associated workflow enabled a significant reduction in intervention turnaround time by cutting as much as 75% of the time necessary to detonate the guns once the depth has been correlated, while providing fast and clear confirmation of downhole detonation. This evolved approach not only addresses the conveyance limitations of highly deviated and horizontal wells, it also greatly improves the safety, reliability, and efficiency of underbalanced perforating interventions by leveraging the real-time downhole monitoring and control capabilities of CT with fiber optic telemetry.
- Europe > United Kingdom > England > Hampshire Basin > PL 089 > Block 98/6 > Wytch Farm Field > Sherwood Formation (0.99)
- Europe > United Kingdom > England > Hampshire Basin > PL 089 > Block 98/11 > Wytch Farm Field > Sherwood Formation (0.99)
- Europe > United Kingdom > England > Hampshire Basin > PL 089 > Block 97/15 > Wytch Farm Field > Sherwood Formation (0.99)
- (6 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- (2 more...)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Communications > Networks (0.93)
Abstract Fiber-optic measurements are being applied more and more in unconventional reservoirs. Coiled tubing (CT) fiberoptic real-time telemetry can be used to perform distributed temperature sensing (DTS) and distributed acoustic sensing (DAS) providing valuable insight into how fracturing treatments have performed. Changes in vibration during pumping operations can indicate which zones are taking fluid. Fluctuations in observed temperature during pumping can indicate which zone(s) accepted fluid, and warm backs after pumping can determine the qualitative volume of injected fluid that went into each interval. Typically, fiber-optic cables are permanently installed on the outside of casing to monitor the fracturing treatment, other injection operations, and/or production profiles. This methodology presents many risks during installation and well operations, such as pinching, tearing, or perforating the cable or loss of coupling, resulting in poor data resolution. Additionally, once the cable is installed, it is restricted to the specific well or wells installed, hence it cannot be used in other wells or applications as it is a permanent component of the completion. As a result, the technical and commercial value of this technique requires high scrutiny, close supervision, and consideration based on the risk and cost versus value. The case study presented in this paper demonstrates an alternative approach. CT fiber-optic realtime telemetry was used to observe fluid flow along an openhole lateral drilled in an unconventional formation. The study well was produced for a period of time prior to the fracturing operation and the well was then stimulated in a continuous treatment utilizing degradable particulate and fiber material for diversion. Injection tests were performed prior to the fracturing operation allowing the real-time measurements to determine where depleted zones were and what type of rate needed to be pumped for fluid to flow further down the lateral. This allowed for the job to be modified to better target-stimulate the well. Various diversion recipes were pumped both prior to and in between proppant-laden fracturing treatment stages to encourage stimulation along a greater portion of the lateral. CT fiberoptic real-time telemetry was initially deployed to measure the well under static conditions to determine productive zones along the lateral prior to stimulation. It was then used to determine the relative success of each diversion stage during the stimulation treatment. The diagnostics provided by the CT fiber-optic real-time telemetry allowed for a better understanding and optimization of the diversion recipes than other methods. Results presented in this paper show the lessons learned and best practices moving forward for diverting in openhole fracturing treatments. These lessons learned may also be applied to refracturing treatments. Furthermore, CT fiber-optic real-time telemetry can be used in other wells to fine-tune diverter and fracturing fluid recipes.
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.46)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- (10 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- (4 more...)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Communications > Networks > Sensor Networks (0.54)
Abstract In the last decade, the number of horizontal wells drilled in North America has risen dramatically. As a result, there has been an associated increase in the use of the plug and perforation system and the ball-drop system used to complete these horizontal wells. After the fracturing treatment has been completed, the bridge plugs or ball seats are subsequently milled out via the use of coiled tubing (CT). During the plug or ball-seat milling phase, it is difficult to control weight-on-bit at the end of the CT. If the injector releases too much weight at surface, then the weight-on-bit is too high and the downhole motor can experience a stall. Alternatively, if the injector is not releasing enough weight at surface, then there is insufficient weight-on-bit to mill out the plug or ball-seat. Given that these operations are performed in horizontal wells, it is difficult to predict the optimal weight-on-bit without the presence of real-time downhole measurements. The current data acquisition software used on CT field operations does not analyze or interpret the data - - it only records the measurements. As a result, it is an arduous process to identify trends in pressure, depth or CT string weight changes over an extended period of time. However, analyzing changes in these variables is critical for optimizing the CT milling operation. This paper focuses on an innovative technique for analyzing real-time CT job data that can be used to calculate the required surface weight needed to achieve the optimal weight-on-bit. Furthermore, the technique also enables real -time interpretation of CT job data to confirm that the mill is making the desired progress. This technique has been implemented as a utility within a leading CT modeling software package. This paper will also present field case studies that demonstrate how the new CT interpretation utility software has optimized the milling efficiency in horizontal wells.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Modeling & Simulation (0.71)
Abstract Discrete technology solutions, such as real time data acquisition, distributed temperature sensing, etc. applied on selected-well basis seem to serve field development engineers well sometimes. Nevertheless, for engineers continually to improve field-wide operations and attain the cost and production advantages necessary to stay competitive in an industry shifting to cost-effective applications, integrating workflows is a strategic imperative. Engineers will need to concentrate and excel not just on specific technologies but on holistic rigless operations success driven by more attention to integration than individual technology solutions. The challenge facing asset teams remains how to execute comprehensive plans to make significantly higher returns from capital technology spending in the field. The scope of this paper is to present how engineers have adopted technology integration and alignment of numerous technology solutions for the specific situation of successfully developing and managing a giant oil carbonate field in readiness for a major production milestone. The approach presented entails an all-inclusive project-based method that involves performance reviews, elimination or reduction of idle times through close monitoring of incremental project stages, optimizing operational efficiency through increasing the speed of material delivery to the well sites, and improvement of logistics of people and equipment. The approach involves unifying role-based, process-based, and production workflows throughout the operation and building on a learning curve with each successive rigless operation. From the safe job execution of over 100 rigless activities, a model or scorecard is available to control important variables, assess the effectiveness of specific technologies, and provide support for leading or lagging indicators. As a result of seamless and routine inclusion of technology-based exercises at a project level, rigless activities have been completed over 60% faster than when the campaigns started nearly five years ago. Monetizing this value of technology integration in auditable and quantifiable terms translate to significant gains over the course of the rigless campaign. Through integration, engineers can implement effective programs for improvement in service levels and improve operations. Eventually these gains translate to fewer obstacles to project delivery. Introduction Technology is core and central to Manifa field development. Achievements in the Manifa field are testament that the field development team is savvy about applying fit for purpose technological solutions for lasting/sustainable gains. As a result of measurable improvements and integration of workflows between core technology applications, several world firsts have been credited to the Manifa team (Arukhe et al., 2014). Some of these records include the world's largest extended reach project (more than 75% if the field's wells are ERWs) and the use of the world's first tandem 2.125" CT tractor for ESP open hole completions (Arukhe, Duthie, Al-Ghamdi, Hanbzazah, Almarri, Sidle & Al-Khamees (2014). The first oil industry use of a specialized reusable filtration unit system in a long-term injection test, utilizing primary seawater filtration and chemical treatment was conducted in the field. A reflection of the project, upon successful commissioning of the first phase, reveals that the most critical success factor includes the degree of technology integration into the team's basic strategic approach to field development. The amount of solutions for rigless well interventions and well testing have multiplied considerably lately – from optimizing CT reach, well stimulation, multilateral access, and profiling to well testing. At present, these solutions deliver gains with possibility of influencing more efficient field development. As shown in this paper, technology adoption in CT reach and stimulation treatments results in gains from accelerated job execution and client satisfaction becomes evident. Consequently many wells have been successfully stimulated onshore and offshore.
- North America > United States (1.00)
- Asia > Middle East > Saudi Arabia > Arabian Gulf (0.91)
- North America > United States > Texas > Permian Basin > Delaware Basin > Grassroots Field (0.99)
- Asia > Middle East > Saudi Arabia > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > Manifa Field (0.99)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (6 more...)
- Information Technology > Architecture > Real Time Systems (0.69)
- Information Technology > Artificial Intelligence > Robots (0.67)
Abstract Discrete technology solutions, such as real time data acquisition, distributed temperature sensing, etc., applied on a selected-well basis, seem to serve field development engineers well sometimes. For engineers to continually improve field-wide operations and attain the cost and production advantages necessary to stay competitive in an industry shifting to cost-effective applications, integrating workflows is a strategic imperative. Engineers will need to concentrate and excel not just on specific technologies, but on holistic rigless operations success driven by more attention to integration than individual technology solutions. The challenge facing asset teams remains how to execute comprehensive plans to make significantly higher returns from capital technology spending in the field. The scope of this paper is to present how engineers have adopted technology integration and alignment of CT reach and stimulation technology solutions for the specific situation of successfully developing and managing major oil carbonate field in readiness for a major production milestone. The approach presented entails an all-inclusive project-based method that involves performance reviews, elimination or reduction of idle times through close monitoring of incremental project stages, optimizing operational efficiency through increasing the speed of material delivery to the well sites, and improvement of logistics of people and equipment. The approach involves unifying role-based, process-based, and production workflows throughout the operation and building on a learning curve with each successive rigless operation. From the safe job execution of many rigless activities, a model or scorecard is available to control important variables, assess the effectiveness of specific technologies, and provide support for leading or lagging indicators. Consequent upon routine and seamless inclusion of technology-based exercises at a project level, rigless activities have been completed over 60% faster than when the campaigns started nearly five years ago. Monetizing this value of technology integration in auditable and quantifiable terms translate to significant gains over the course of the rigless campaign. Through integration, engineers can implement effective programs for improvement in service levels and improve operations. Eventually these gains translate to fewer obstacles to project delivery.
- Asia > Middle East > Saudi Arabia (1.00)
- North America > United States > Mississippi > Marion County (0.24)
- North America > United States > Texas > Permian Basin > Delaware Basin > Grassroots Field (0.99)
- Asia > Middle East > Saudi Arabia > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > Manifa Field (0.99)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (7 more...)
- Information Technology > Artificial Intelligence (1.00)
- Information Technology > Architecture > Real Time Systems (0.88)
Azeri-Chirag-Gunashli basin is a large complex of oil fields in the Azerbaijan sector of Caspian Sea. Hydrocarbon deposits in ACG are mostly located in Sandstone reservoir thus formation sand invasion into the well encountered throughout the world at this type of the formation, is common issues experienced in the field. A-09Z oil producer well finished with open hole screen completion had screen failure issue which resulted large amount of sand filling up the wellbore. The operator requested to clean the sand out of the well along horizontal section and isolate the existing production zone by setting the bridge plug to further perforate an interval above. This paper describes the use of an integrated sand cleanout system to remove the formation sands out of this challenge well. The well was drilled to near horizontal with a large completion size and long tangential section around 60°. A hydraulically actuated, switchable circulation sub was used with a real time downhole measurement system. While running into the well, forward jets of the sub help break down debris. While pulling out of the well, the tool is switched to a low resistance, backward jetting mode, which sweeps debris more efficiently using higher flow rates. The real time downhole measurement with a robust conductor inside CT is used to verify the switchable circulation sub to be operated correctly. A sand monitor was used in the surface return line to continuously monitor the returned sand flux. The integrated cleanout system helps reduce the overall operation costs by making the job more efficient in terms of equipment usage and operation time.
- Asia (1.00)
- North America > United States > Texas (0.96)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Production and Well Operations > Well Intervention (1.00)
Saudi Arabia's Value Adding, Record-Breaking Coiled Tubing Interventions Travel Farther than Mount Everest
Arukhe, James (Saudi Aramco) | Ghamdi, Saleh (Saudi Aramco) | Dhufairi, Mubarak (Saudi Aramco) | Duthie, Laurie (Saudi Aramco) | Almari, Abdulrahman (Saudi Aramco) | Elsherif, Tamer (Schlumberger) | Othman, Bassem (Schlumberger)
Abstract Coiled tubing (CT) deployment with hydraulic tractors in extended reach open hole horizontal wellbores has been a challenging technology in the oil industry for reasons ranging from wellbore conditions like washouts to restrictions imposed by the completions. Consequently, delivering cost-effective well interventions solutions, for example through acid treatments to enhance well performance, or production logging to understand inflow profiles in deep injector wells have been particularly demanding. The authors examine how rigorous pre-job planning and teamwork were enablers to realizing the deepest CT reach at 30,365 ft (9.26 km) measured depth (1,336 ft longer than the height of Mount Everest at 29,029 ft) in a mega-reach open hole horizontal power injector well using a CT tractor to facilitate effective stimulation in Saudi Arabia. Among the operational challenges overcome in the well was tar accumulation on the tool string including the tractor during the well intervention. The tar accumulation on the string was part of a laterally extensive high viscosity tar layer between the overlaying oil column and aquifer. From a reservoir standpoint the tar layer posed a challenge in assuring sufficient aquifer support to the oil producers because of their partial sealing nature. The author discusses how the challenges imposed by tar restrictions and other operational concerns were overcome to ensure successful acidizing. The wells showed a marked injectivity improvement from acid stimulation thus demonstrating the benefit of informed decisions from real time fiber optic distributed temperature sensing (DTS) in fluid placement. The tractor traversed a difficult down hole environment overcoming washouts and H2S environments within the wellbore conveying the CT for an industry record tractor reach for open hole CT intervention at 30,365 ft. Concrete applications of these outcomes include the ability to employ real time information for cost-effective stimulation and real time log acquisition from extended reach open hole horizontal wells.
- North America > United States (1.00)
- Asia > Middle East > Saudi Arabia (0.85)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Well Completion > Acidizing (1.00)
- (4 more...)
- Information Technology > Architecture > Real Time Systems (0.96)
- Information Technology > Artificial Intelligence > Robots (0.69)
Abstract More than 30% of coiled tubing (CT) operations worldwide are related to debris removal from a wellbore. The process is affected by multiple variables including fluid properties/velocities, particle properties, wellbore geometry and deviation, pipe size and eccentricity, fill penetration rate, and wiper trip speed. Debris cleanout with CT is challenged by the achievable pump rates and lack of pipe rotation. This challenge is further compounded by highly deviated or horizontal well trajectories, especially in large-diameter wellbores with low bottom-hole pressures. A hydraulically actuated, switchable circulation sub was developed a decade ago. While running into the well, forward jets of the sub help break down debris. While pulling out of the well, the tool is switched to a low resistance, backward jetting mode, which sweeps debris more efficiently using higher flow rates. However, in some challenging conditions such as compacted sand columns, or scale in extended wellbores, the sub has to be combined with other downhole tools to meet operational requirements. This paper discusses how to combine the switchable circulation sub with a tractor, water hammer tool, and a mud motor/bit. It goes on to demonstrate a means of verifying the tool is operated correctly using real time downhole signals transmitted by a small but robust conductor inside the CT. The benefits of this combination are multi-fold. First, while running into the well the tractor or water hammer tool helps to reach target depth. While pulling out of the well, the switchable circulation sub cuts off flow to the lower BHA (bottom hole assembly), stopping the bit/PDM (positive displacement motor) and/or idling the tractor or water hammer tool. At the same time, the flow rate can be increased with relatively lower surface injection pressures improving the hole-sweeping efficiency and pipe fatigue life. A few field case histories are presented to demonstrate the benefits of these special BHAs in improving operational efficiency. The challenges, benefits, and lessons learned during these operations are reviewed.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- (5 more...)
A New Methodology for Stimulation of a High-Water-Cut Horizontal Oil Well through the Combination of a Smart Chemical System with Real-Time Temperature Sensing: A Case Study of South Umm Gudair Field, PZ Kuwait
Al-Najim, A.. (Chevron) | Zahedi, A.. (Chevron) | Al-Khonaini, T.. (Kuwait Gulf Oil) | Al-Sharqawi, A. I. (Kuwait Gulf Oil) | Tardy, P. M. (Schlumberger) | Adil, A. R. (Schlumberger) | Nugraha, I.. (Schlumberger) | Ramondenc, P.. (Schlumberger) | Al-Hadyani, F. S. (Schlumberger)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE/ICoTA Coiled Tubing & Well Intervention Conference & Exhibition held in The Woodlands, Texas, USA, 27-28 March 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract This paper presents a case study of a matrix acidizing treatment in a well located at the neutral zone between Kuwait and Saudi Arabia, whereby the combination of a "smart fluid" in a stimulation treatment pumped through a Coiled-Tubing (CT) with the real time distributed temperature sensing (DTS) technology helped improve the real-time decision process of fluid placement, temporary plugging placement, and treatment efficiency evaluation. As part of the analysis process and to facilitate the onsite decision-making process, a temperature inversion technique was also used to translate the actual temperature profiles into fluid invasion profiles across the horizontal open-hole section of the well.
- Asia > Middle East > Saudi Arabia > Saudi Arabia - Kuwait Neutral Zone ("Partitioned Zone") (0.86)
- Asia > Middle East > Kuwait > Ahmadi Governorate (0.86)
- North America > United States > Texas > Montgomery County > The Woodlands (0.24)
- North America > United States > Oklahoma > Anadarko Basin > M Formation (0.99)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > South Umm Gudair Field > Pre-Khuff Formation (0.99)
- Asia > Middle East > Kuwait > Ahmadi Governorate > Arabian Basin > Widyan Basin > South Umm Gudair Field > Khuff Formation (0.99)
- Africa > Tanzania > Indian Ocean > K Formation (0.99)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Acidizing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- (8 more...)
Next Generation Technologies for Underbalanced Coil Tubing Drilling
Kozlov, Anton (Baker Hughes) | Frantzen, Serve (Baker Hughes) | Gorges, Thomas (Baker Hughes) | Al Khamees, Shaker (Saudi Aramco) | Guzman, Julio C. (Saudi Aramco) | Aduba, Anthony A (Saudi Aramco) | da Silva, Thiago P. (Schlumberger)
Abstract Technology improvements are continuing to expand the capability of coiled tubing directional drilling (CTDD) worldwide. Increased CTDD activity in advanced underbalanced re-entry applications that require precise wellbore (multilateral) placement and real-time monitoring of downhole parameters has led to the development of bottom-hole drilling assemblies (BHAs) with enhanced functionality. Saudi Aramco identified CTDD as an important technology for redeveloping its gas reserves and is dedicated to expanding the technical limit of CTDD application. Saudi Aramco successfully completed its first underbalanced re-entry coiled tubing drilling (UBCTD) pilot project and is now progressing to consolidate this technology in subsequent UBCTD operations. A great impetus has now been placed on further improving UBCTD project economics through improved operational efficiency and the introduction of new underbalanced coiled tubing drilling techniques and services. This paper provides an overview of the new Rib Steered Motor (RSM) technology and its potential benefits to UBCTD. It details recent worldwide deployments of the rib steering motor technology focusing on operations in the Kingdom of Saudi Arabia which provide the perfect testing ground when geosteering with RSM. Future advances using UBCTD geosteering technology rely on a close working relationship between the field operator and the service company. Successful application of UBCTD applys to a wide range of mature oil and gas fields for enhancing access to the producing reservoir to drive the economic extraction of additional reserves.
- North America > United States > Texas (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- North America > United States > Alaska > North Slope Borough (0.47)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.96)
- North America > United States > Alaska > North Slope Basin > Prudhoe Bay Field (0.99)
- North America > United States > Alaska > North Slope Basin > Lisburne Field (0.99)
- Asia > Middle East > UAE > Sharjah > Oman Mountains Foldbelt Basin > Sajaa Field > Thamama Group Formation (0.99)
- (9 more...)
- Well Drilling > Pressure Management > Underbalanced drilling (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Operations > Coiled tubing drilling (1.00)
- (2 more...)