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Collaborating Authors
Assam
The Upper Assam Basin is one of the leading oil producing basins in India. Most of the producing oil fields are both structural and strati-structural in nature. Due to subsurface geological complexity and surface logistic issues, seismic imaging is limited in mapping subsurface information. Hence, to map the subsurface information including basement depth, deeply buried structures and sub-thrust structural information, as an objective, an Airborne Gravity Gradiometry (AGG) along with gravity, magnetic, and LIDAR survey has been accomplished in 2020-21. A multidisciplinary approach has been used to attain the objectives. In this study, integrated interpretation of seismic reflection data, well log density data along with terrain corrected AGG, gravity, and magnetic data is performed over the survey area. AGG, gravity, and magnetic data acquired in this survey have provided subsurface information matching very well with the known tectonics. Further, new segments of the Naga thrust are identified, and a subsurface extension of the Naga thrust transitioning into a strike-slip fault beneath the Manabum thrust has also been mapped. Interaction between the faults of the Naga-Schuppen Belt and the Manabum thrusts is interpreted through the geometric analysis of anomalies associated with each thrust system, providing a better broad picture of the structural tectonic framework of the basin. This study investigates anomalies associated with three convergent thrust systems and associated foreland basins.
- Overview (0.88)
- Research Report > New Finding (0.34)
- Phanerozoic > Cenozoic > Paleogene (0.48)
- Phanerozoic > Cenozoic > Neogene (0.30)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (1.00)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.70)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Reverse Fault > Thrust Fault (0.55)
- Geophysics > Magnetic Surveying (1.00)
- Geophysics > Gravity Surveying > Gravity Acquisition > Airborne Gravity Acquisition (1.00)
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Nahor Oil Sand (0.99)
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Digboi Oil Sand Group (0.99)
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Bappapung Sandstone (0.99)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Quantification of Complex Pore System in Heterogeneous Carbonate Reservoirs Using Borehole Resistivity Image Log from the West Coast of India
Panda, Soumya Chandan (Oil and Natural Gas Corporation Ltd India) | Kumar, Suraj (Oil and Natural Gas Corporation Ltd India) | Prasad, Surendra Kumar (Oil and Natural Gas Corporation Ltd India) | Kumar, Vinod (Oil and Natural Gas Corporation Ltd India) | Bahukhandi, Yogesh (Oil and Natural Gas Corporation Ltd India)
ABSTRACT The Western Offshore basin of India contributes about half of the domestic crude oil and two thirds of the gas production of the nation. The evaluation and quantification of carbonate reservoirs of the Western Offshore Basin, has always remained a challenging task for petro physicists, due to their highly heterogeneous nature in terms of porosity, permeability and facies. Porosity and permeability do not exhibit a linear relationship in carbonate reservoirs due to porosity alteration during diagenesis through geological time. In carbonates it is often found that good production can be obtained from intervals showing low porosity whereas zones with higher porosity may not produce as expected, owing to the inherent azimuthal anisotropy and lateral heterogeneities. In the present study an attempt has been made to classify and quantify different porosity components arising due the matrix, vugs, connected vugs etc. using high resolution resistivity image data only. The well under study has been drilled as a horizontal well with a 6" drain hole. Image textural analysis has been carried out to bring out the different contributions to the total porosity. The results from the textural analysis indicate hydrocarbon deposited in secondary porosity system like isolated vugs and connected vugs. The percentage of connected vugs out of the total porosity, is in unison with the well flowing economical volumes of hydrocarbons. Also the portion of isolated vugs opens doors for Enhanced Oil recovery after acid job in the later stages of field development. INTRODUCTION Mumbai Offshore basin is located on western continental shelf of India between Saurastra basin in NNW and Kerala Konkan Basin in South. Sediments deposited in Mumbai offshore basin over a period from Paleocene to Recent are dominated by sea level changes throughout. Both Clastic and Carbonate sediments deposited are hydrocarbon rich with good reservoir quality developed in most of the places. Carbonate reservoir facies in terms of porosity, permeability, and matrix varies widely due to depositional conditions and diagenesis (Lucia et al. 1995).
- Geology > Sedimentary Geology (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.49)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.48)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (33 more...)
Abstract The economic end of the life-cycle of a well is dynamic and it varies with the oil & gas market conditions and advances in extraction technologies. If production declines or the need for a workover arises, plugging and abandonment operations are followed. In case the wellsite has encountered accidental releases, systematic abandonment and remediation becomes even more crucial to avoid further environmental damage and capital investment. This paper analyzes the Baghjan oilfield blowout of the Assam-Arakan basin and provides abandonment practices for gas wells. The mobile workover rig was stationed at the Baghjan Well-5 with the aim to plug the lower producing zone at 3871 m and complete the well in the upper Lakadong+Therria sand at a depth of 3739 m. Baghjan Gas Well No.5 blew during the temporary abandonment which was planned to mitigate the leakage in the wellhead. Improper depth for the placement of cement plug, failure to check the plug integrity, and shortcomings in the regular inspection of annular casing pressure led to the well control situation at the Baghjan gas well. While pulling out the tubing conveyed perforation gun after perforating the Lakadong+Therria I+II sand, Shut-In Tubing Pressure of 4400 psi and 3900 psi Shut-In Casing Pressure was observed which indicated a leak in the Tubing Seal Assembly. The well was killed with a 9.76 lbm/gal sodium formate brine and in the middle of pulling the tubing, leakage in the W.F. Spool was identified which changed the priority of the operations. Therefore, a temporary abandonment operation was planned to mitigate the leakage problem in the primary and secondary seals, during which the well started flowing gas profusely after nipple-down of the blowout preventer. The shortcomings of the abandonment process can be conquered by the selection of an appropriate isolation material such as resin-based sealants or bismuth and thermite, which shall act as a primary barrier and provide enhanced zonal isolation. The isolation material should mitigate micro-fractures, minimize treatment volume and fluid loss, provide ample pumping time, and not degrade in the presence of wellbore fluids. The study discusses resin-based sealants, cement slurry designs, advances in conventional, unconventional, and rigless abandonment techniques, and suggests the most efficient method for the temporary and permanent abandonment operations to avoid further such incidents in the oil and gas industry.
- Asia > India > Tripura > Assam-Arakan Basin (0.99)
- Asia > India > Assam > Tinsukia District > Assam-Arakan Basin > Schuppen Thrust Belt > Baghjan Field (0.99)
Abstract E&P activities are the early stage of energy production and pivotal for generating and sustaining economic growth. However, negligence and evaluating the circumstances incorrectly during these operations can lead to calamities like blowouts. This paper discusses two such tragedies, the Pasarlapudi (Krishna-Godavari) Gas Well Blowout of 1995 & Baghjan (Assam-Arakan) Oil Field Blowout of 2020, and provides possible well control measures and lessons learned. Pasarlapudi blowout incident occurred during the drilling operations. The pipe stuck-up situation at 2727m MD (Measured Depth) was detected by conducting a stretch test. Further analysis could include circulating brine, checking lost circulation and identifying casing leaks by measuring Sustained Casing Pressure (SCP), Operator-imposed Pressure (OIP), and Thermal-induced Pressure (TIP). Baghjan's gas well at the depth 3870m was producing at 2.8-3.5 MMSCFD. The aim was to plug the lower producing zone and recomplete the well in the upper Lakadong+Therria sand zone. Well was killed using brine, cement plug was placed and BOP installed. BOP was removed after the plug was set to begin the process of moving the workover rig. Well blew gas profusely during this process. Simulating a blowout and facing one, are two completely different situations. In Pasarlapudi's case, the well blew with an enormous gas pressure of 281.2 ± 0.5 kg/cm. While drilling the production hole (8.5 inch), either differential pressure sticking, presence of water-swelling clay formation or the partial collapse of wellbore formation caused the pipe stuck-up situation. By conducting stretch test along with circulating brine, root cause of this problem could be identified. If differential sticking occurred, lost circulation could be checked & cured, while keeping the hole full. Circulating brine should solve the problem of swelling clay formation while formation collapse could have occurred due to the presence of plastic formation like salt domes. In the case of Baghjan gas well blowout during workover operations, probable safety measures could include placement of 2 or 3 backup cement plugs along with kill fluid or going for squeeze cementing before placing the cement plug & kill fluid while abandoning the lower producing zone. Attempts were made to bring the well under control by adequate water spraying, installing BOP. Water was pumped through the casing valve and a water reservoir was dug near the well plinth for the placement of pumps of 2500 gallon capacity. Proper safety measures should be used even when they're not the cheapest to avoid repetition of treatments and detrimental situations. SCP, OIP and TIP should be measured periodically whenever possible and the root cause of situations like lost circulation, pipe stuck-ups, kicks, casing leaks should be identified before proceeding towards drastic remedial operations. Innovations in countering well-control situations should be promoted invariably.
- Phanerozoic > Cenozoic > Paleogene > Eocene (0.69)
- Phanerozoic > Cenozoic > Paleogene > Paleocene (0.47)
- Geology > Rock Type > Sedimentary Rock (0.69)
- Geology > Mineral (0.68)
- Geology > Structural Geology > Tectonics (0.48)
- Asia > India > Tripura > Assam-Arakan Basin (0.99)
- Asia > India > Assam > Tinsukia District > Assam-Arakan Basin > Schuppen Thrust Belt > Baghjan Field (0.99)
- Asia > India > Andhra Pradesh > Bay of Bengal > Krishna-Godavari Basin (0.99)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Casing and Cementing (1.00)
- Health, Safety, Environment & Sustainability > Safety (1.00)
Evolution of Hydraulic Fracturing Operations & Technology Applications in India
Gondalia, Ravi Ramniklal (Schlumberger) | Sharma, Amit (Schlumberger) | Shende, Abhishek (Schlumberger) | Jha, Amay Kumar (Schlumberger) | Choudhary, Dinesh (Schlumberger) | Gupta, Vaibhav (Schlumberger) | Shetty, Varun (Schlumberger) | Bordeori, Krishna (Schlumberger) | Barua, Bhaswati Gohain (Schlumberger) | Singh, Mukund Murari (Schlumberger) | Zacharia, Joseph (Schlumberger) | Patil, Jayesh (Joshi Technologies International) | Murthy, P V (Oil and Natural Gas Corporation) | Das, Santanu (Oil and Natural Gas Corporation) | Mahawar, Dheeraj (Oil and Natural Gas Corporation)
Abstract From 2005 to 2020, the application of hydraulic fracturing technology in India has touched the length and breadth of the country in almost every basin and reservoir section. The variety of reservoirs and operating environment present in India governed this evolution over the past 15 years resulting in a different fit for purpose fracturing strategy for each basin varying from conventional single-stage fracturing (urban, desert & remote forested regions) to high volume multi-stage fracturing, deepwater frac-packs and offshore ultra-HPHT fracturing. The objective of this paper is to present the milestones along this evolution journey for hydraulic fracturing treatments in India from 2005 to 2020. This paper begins with a review of published industry literature from 2005 to 2020 categorized by reservoir type and the proven economical techno-operational fracturing strategy adopted during that period. The milestones are covered chronologically since the success or failure of technology application in one basin often influenced the adoption of novel hydraulic fracturing methods in other basins or by other operators during the initial years. The offshore evolution is branched between the west and the east coasts which have distinctly different journeys and challenges. The onshore evolution is split into 5 categories: Cambay onshore Barmer Hills & Tight Gas East India CBM and shale gas Assam-Arakan Basin Onshore KG Basin Each of these regions is at different stages of evolution. The Barmer region is in the most advanced state of evolution with frac factories in place while the Assam-Arakan Basin is in a relatively nascent stage. Figure 1 presents estimated hydraulic stage count based on published literature underlining the exponential growth in hydraulic fracturing activity in India. This paper enlists the technical and operational challenges present in the onshore and offshore categories mentioned above along with the identified novel techno-operational strategies which have proven to be successful for various operators in India. A comparison is presented of the different timelines of the exploration-appraisal-development journey for each region based on the economic viability of fracturing solutions available today in the Industry. Lastly, specific non-technical challenges related to available infrastructure, logistics and social governance are discussed for each region. This paper concludes by identifying the next step-change in the evolution of hydraulic fracturing operations in India among the 5 categories. Each of Government, operators and service providers have important roles to play in expanding the adoption of this technology in India. These roles are discussed for each identified category with the perspective of continuing the country's journey towards energy security.
- Asia > India > Rajasthan (0.96)
- Asia > India > Andhra Pradesh > Bay of Bengal (0.70)
- Phanerozoic > Cenozoic (0.68)
- Phanerozoic > Mesozoic (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.66)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.46)
- Asia > India > Tripura > Assam-Arakan Basin (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Raageshwari Deep Field (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Block RJ/ON-90/1 > Raageshwari Deep Field (0.99)
- (11 more...)
Abstract The use of LSWF (Low Salinity Water Flooding) is becoming more prevalent in recent years which can both improve the recovery factor and reduce the cost compared to other EOR (enhanced oil recovery) technics. This is especially important for the offshore oilfield development at present. Moreover, good quality of injected water is more applicable to low permeability sand which is characterized as smaller pore-throat radius and is easier damaged. Therefore, LSWF technology is proposed to address the above production problem while reduce the investment of equipment upgrade. In this paper, we presented the optimization and implementation of LSWF for offshore low permeability reservoir. Firstly, we provided a critical review of LSWF included the main mechanisms, laboratory test and field effect. Secondly, we designed and conducted several laboratory core flood tests. Thirdly, a lot of synthetic models were established to simulate the effects of LSWF and to optimize the field program. Finally, the production performance of the pilot wells was discussed. After LSWF, the water injection well presents the phenomenon of "scissors" - the injection pressure drops significantly below the safety pressure while the injection volume increases. Moreover, the decline of pilot well groups decreased by 20% ~ 26% compared with non-water flooded. The estimated recovery factor increased by 12%, which is consistent with other field tests worldwide. In summary, LSWF is a feasible, neconomic and efficient method for offshore low permeability reservoir production.
- North America > United States > California (0.28)
- Asia > Middle East > Syria (0.28)
- Asia > Middle East > Saudi Arabia (0.28)
- (3 more...)
- Geology > Mineral > Silicate (0.73)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.69)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.37)
- North America > United States > Montana > Target Field (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 375 > Block 34/7 > Snorre Field > Statfjord Group (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 375 > Block 34/7 > Snorre Field > Lunde Formation (0.99)
- (18 more...)
Budding petroleum engineers may find the two pictures interesting as they reflect India's oil history. I picked them up from DEW Journal's archives. The first picture shows elephant carts setting out for seismic survey in upper Assam during formative years of the oil industry in India. Amazing how things have changed over the years. The second picture shows Well No.1--India's first oil well, Digboi field, in 1890.
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Nahor Oil Sand (0.99)
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Digboi Oil Sand Group (0.99)
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Bappapung Sandstone (0.99)
Successful Drilling of Deep Wells Aided by Geomechanical Analysis and Real-Time Decision Making in Complex Geological Setting in the North-Eastern Part of the India
Bhardwaj, Sourav (OIL India Ltd.) | Baruah, Neelimoy (OIL India Ltd.) | Sharma, Dr. Manas (OIL India Ltd.) | Kumar, Rajeev Ranjan (Schlumberger)
Abstract High angle S-shaped and high displacement L-shaped well profiles are preferred now-a-days in Balimara field located in the northeast region of India. Main targets are the deep Clastic reservoirs of Oligocene age. Major events reported are while drilling against dipping formations with differential stuck pipe situations with variety of drilling complications in the unstable formations owing to shales in Tipam sandstone and thin sections of coal and shale alteration in oil bearing Barail sandstone formation. The substantial risk of wellbore instability in accessing the reservoirs with lateral variation in pore pressure threatened the commercial success of the project. This paper elaborates how geomechanical information along with BHA design and chemicals was integrated into the decision-making process during well design and drilling operations to avoid wellbore instability issues. Wellbore stability analysis through Mechanical Earth Model was conducted using estimated state of stress and mechanical properties of the overburden and reservoirs. The model incorporated data from several sources including geophysical logs, leak-off tests, advanced sonic far field profile and drilling records collected from the earlier wells. Examination of the deviated well bore profiles suggested occurrence of ledges due to lower mud weight and improper drilling parameters while drilling alternate layers of sand, shale and coal in Barail formation. Horizontal stress contrast increases in Barail formation supporting the need of higher mud weight with increased well deviation towards specific azimuth. The integrated geomechanical analysis provided key information: The 9 5/8" casing shoe should be set at shale layer of Tipam Bottom to isolate upper differential sticking prone sandstone layers with Barail Argillaceous sequence. This will help to drill 12.25-inch hole with 9.6 ppg-9.8 ppg only. Shale layers at Tipam bottom require 10.0-10.5 ppg, while Barail shale requires 10.5 ppg-11.0 ppg for vertical well. When the well deviation increases up to 30deg, mud weight requirement rises to 11.2 ppg-11.8 ppg. Based on analysis, the mud weight at the start of 8.5inch section was raised sufficiently to 10.5 ppg to avoid the hole collapse experienced in the earlier lower angle wells. Later, continuous review of torque and drag along with cutting analysis helped to raise mud weight up to 11.0 ppg till well TD. As a result, lower UCS shale and coal layers are drilled with minimal shear failure and improved hole condition. However, changes to the mud system were needed to limit fluid loss and avoid differential sticking across the sandstone. For deviated section, rotary BHA has been used to improve hole trajectory vs. planned with lesser ledges. Downhole hydraulics has been maintained with proper flow rate and rpm to main hole cleaning. The new well engineered with the integrated geomechanics information has been drilled from surface to extended TD while saving 15 rig days.
- Asia > India (0.71)
- North America > United States (0.47)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying (0.95)
Summary The brittleness index (BI) has major implications for hydraulic fracture studies and production toward optimized recovery in unconventional reservoirs. The paucity of brittleness studies in Mizoram and Upper Assam, located in northeastern India, motivates us to take up multimineral modeling and estimation of BI. Two commonly used BI estimation approaches, mineralogical and geomechanical, have been implemented to characterize the shaly sandstone in the study area. Laboratory analyses of the available drill-cutting samples and crossplots from well log data along with previous literature confirm the types of minerals present in the study area. With this mineralogical information, a new approach of BI log estimation from multimineral modeling is suggested here using conventional log data in the absence of core/drill cutting samples. A multimineral model for Mizoram and Upper Assam is developed by using bulk density (ρ), compressional sonic velocity (Vp), shear sonic velocity (Vs), lithodensity, and acoustic impedance (AI) logs to calculate volumetric percentage of minerals. Estimated mineralogical BI from well log data using four established models are compared and calibrated with X-ray diffraction (XRD)-derived BI to validate the proposed procedure. Most brittle zones having a BI ≥ 66% are demarcated for high Young’s modulus (Y ≥ 60 GPa) and low Poisson’s ratio (ν ≤ 0.25) values in the Y vs. ν crossplot for the study area. The presence of brittle minerals estimated from both XRD and the multimineral model suffices the reason for the high brittleness of shaly sandstone in Mizoram compared with Upper Assam.
- North America > United States > Texas (1.00)
- Asia > India > Mizoram (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.30)
Well Abandonment and Subsequent Elimination of Sustained B-Annulus Pressure: A Case Study
Saikia, Partha Protim (Oil India Limited) | Dutta, Udai Anand (Oil India Limited) | Gogoi, Porag (Oil India Limited) | Maut, Partha Protim (Oil India Limited) | Pathak, Diganta (Oil India Limited) | Tumung, Ranjit (Oil India Limited) | Dutta, Hiranya Kumar (Oil India Limited)
Abstract Maintaining well integrity during well life cycle plays a significant role in the life of a well. Sustained casing pressure (SCP) or Sustained annulus pressure (SAP) in oil and gas wells can result in leakage of the well fluid in undesired regions of the well. Failure to control or manage Annuli pressure may result in uncontrolled release of high-pressure hydrocarbon fluids from formation to the surface thereby leading to significant safety issues and environmental damage. The Exploratory Well A of Oil India Limited, in the western Block of the Baghjan Structure, was drilled to a measured depth of 4485 m as a J-Bend well and was completed in 4462-m Langpar Sand through perforation in the range 4462.0 m – 4464.0 m in May 2016 after completion with permanent packer. After few days of production testing gradual increase of pressure in the B annulus was observed although there was not any pressure at A- annulus indicating communication behind B annulus casing. Moreover sand, silt, stones and pebbles up to the size of 1.5 cm along with well fluid was observed at the control head. Subsequently, caving level was checked and found at 15 m from surface. Placing adequate well barriers to mitigate sustained annulus pressure became extremely challenging as killing methods viz circulation, bull-heading etc. did not show any encouraging results. CTU operation for wellbore cleaning/ killing was a no-no with available resources for the sizes of stone/pebbles in the bore. Owing to various well integrity issues it was decided to plug and abandon the well, however, with alternate methodology/approach as conventional methods won't yield. This paper discusses the details of workflow, design, surface arrangement, fluid selection, well control method deployed to subdue the well and subsequent successful abandonment of the well, mitigating sustained annulus pressure issue in a cost effective manner. The abandonment plan was designed on the basis of uncertainties in sub surface well condition, hazard identification, environmental impact and regulatory requirement. This paper also details the different approaches adopted for P&A and step by step plan vis-à-vis actual scenario combined with calculated risks encountered during the execution phase. As drilling and completion of exploratory wells are expensive, it is critical to identify any well integrity issues and place adequate well barriers in the most-suitable manner to ensure environmental protection as per regulatory requirement. We addressed this, through a customized workflow for design and placement of well barriers eliminating sustain annulus pressure and subsequent successful plug and abandonment using the available cost effective resources.
- Asia > India > Tripura > Assam-Arakan Basin (0.99)
- Asia > India > Assam > Upper Assam Basin > Tipam Formation (0.99)
- Asia > India > Assam > Tinsukia District > Assam-Arakan Basin > Schuppen Thrust Belt > Baghjan Field (0.99)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management (1.00)
- Well Completion > Well Integrity (1.00)
- (3 more...)