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Collaborating Authors
Solving the Hydraulic Fracturing Puzzle in the HPHT KG Basin of India with Geomechanics-Enabled Design and Execution
Gondalia, Ravi Ramniklal (Schlumberger) | Kumar, Rajeev Ranjan (Schlumberger) | Nand, Ujjwal (Schlumberger) | Bandyopadhyay, Atanu (Schlumberger) | Narayan, Shashank (Schlumberger) | Bordeori, Krishna (Schlumberger) | Singh, Mukund Murari (Schlumberger) | Shah, Arpit (Schlumberger) | Das, Santanu (Oil and Natural Gas Corporation Limited) | Rao, Dasari Papa (Oil and Natural Gas Corporation Limited) | Shaik, Moulali (Oil and Natural Gas Corporation Limited)
Abstract The Mandapeta-Malleswaram field in India comprises Triassic-Jurassic age sands found at 4000m– 4500m depth, where reservoir pressure ranges 6,000 psi to 9,500psi with static temperature up to 340°F. This tectonically active basin with strike slip stress regime causes a heterogeneous distribution of in-situ stress which complicates the design and execution of effective hydraulic fracturing treatments. Previous attempts at fracturing from 2013 to 2017 were not successful and geomechanics inputs were different from actual values. This paper describes the lifecycle of a production enhancement project, from construction of a geomechanics-enabled mechanical earth model (MEM) to the successful design and execution of fracturing jobs on nine wells increasing proppant placement by 250% compared to previous hydraulic fracturing campaign and achieving 730% incremental gain in gas production compared to pre- fracturing production. Challenges like fracture modeling in tectonically stressed formations, issues of proppant admittance, and complicated fracture plane growth in highly deviated wells (>65°) were overcome by Geomechanical modeling. The modeling incorporated advanced 3D anisotropy measurements, providing better estimation of Young's modulus, Poisson's ratio, and horizontal stresses, resulting in realistic estimation of closure and breakdown pressure. Fault effects were modeled and taken into consideration for perforation depth selection and estimation of pumping pressure with model update based on extensive Minifrac injections and analysis. This study describes the results of injection tests (step rate, pump in-flowback, and calibration injection tests) carried out in the field addressing specific challenges in each well. Pre frac diagnostic injection and decline analysis was used to calibrate the MEM and tailor the design for every well. Proper job preparation for well completions and extensive stability testing involving a borate-based fluid system has reduced the screen out risk and enabled successful fracture placement. Effective pressure management on the job eliminated the problem with frequent screen outs and led to successful execution of all nine jobs while increasing the average job size from 30 t to ~150 t of proppant per stage. From this project, a practical guide to address issues of multiple complexities occurring simultaneously in a reservoir, such as the presence of tectonic stress, fracture misalignment, fissure mitigation, and high tortuosity was developed for future application in tectonically complex fields.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.34)
Increase in Oil Production: Methodology & Best Practices for Hydraulic Fracturing Candidate Selection and Execution in Assam-Arakan Basin
Mukku, Vinil (Schlumberger) | Lama, Tshering (Oil India Limited) | Verma, Sanjay (Oil India Limited) | Kumar, Pankaj (Oil India Limited) | Bordeori, Krishna (Schlumberger) | Chatterjee, Chandreyi (Schlumberger) | Kumar, Arvind (Schlumberger) | Mishra, Siddharth (Schlumberger) | Sharma, Lovely (Schlumberger) | Batshas, Siddhanta (Schlumberger) | Shah, Arpit (Schlumberger) | Prasad, C. B. (Oil India Limited) | Pathak, Digantha (Oil India Limited) | Saikia, Partha Protim (Oil India Limited)
Abstract Hydraulic fracturing can establish well productivity in tight and unconventional reservoirs, accelerate production in low- to-medium permeability wells and revamp production in mature wells. However, not all wells are suitable candidates for hydraulic fracturing and the technique can be detrimental if the right candidate is not chosen. An integrated approach is required to select the wells that are the most-suitable candidates for hydraulic fracturing. This paper discusses the hydraulic fracturing candidate selection workflow and execution carried out in the year 2015 to 2016, which has unlocked reservoir production potential of Upper Assam basin fields of Oil India Ltd. (OIL). Wells which showed poor/no inflow prior to hydraulic fracturing operations, exceeded operator expectations during post fracturing production. Better reservoir management through hydraulic fracturing, rejuvenated ceased wells with an incremental oil production rates of 1380 bopd cumulative rate from six wells, post fracturing. The candidate analysis workflow described in this paper, can serve as the best practices guide for any operator investigating workover candidates among multiple fields, with an objective of production enhancement. A customized candidate selection methodology was developed to identify the 10 best candidates from a pool of 70 vertical/deviated wells in two phases of the hydraulic fracturing campaign. In the absence of dynamic reservoir analysis, offset well data analysis assisted in filling the data gaps by enabling geological and reservoir level understanding. Well production models were calibrated with the production history, geo-mechanical models were prepared and used in the fracture modelling to generate optimum fracture geometry and predict post-fracturing production. Wells were ranked according to incremental hydrocarbon production coupled with risk factors including completions integrity. In the execution, fracturing model was validated by performing fracturing diagnostics tests such as Step Rate and Minifrac injection. The final calibrated model was then used to design the optimum fracturing treatment. Given the age of wells and traditional completions architecture, best practices were developed to counter challenges of high pressures and rate limitations in wells with depth greater than 3500 m. As stimulations and well preparation in completed wells are expensive, it was critical to identify the most-suitable candidates with the available dataset before attempting well preparation and further acquisition. This was addressed through a customized workflow to perform production rate transient analysis for reservoir dynamic flow properties, create synthetic geomechanical models for stress profile & fracture vertical growth estimation.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.69)
- Asia > India > Tripura > Assam-Arakan Basin (0.99)
- Asia > India > Assam > Upper Assam Basin > Tipam Formation (0.99)
Fracturing Fluid and Geomechanics Integration Solves Hydraulic Fracturing in the HP/HT Triassic – Jurassic Petroleum System, Krishna Godavari Basin, India
Gondalia, Ravi Ramniklal (Schlumberger) | Kumar, Rajeev Ranjan (Schlumberger) | Zacharia, Joseph (Schlumberger) | Shetty, Varun (Schlumberger) | Bandyopadhyay, Atanu (Schlumberger) | Narayan, Shashank (Schlumberger) | Bordeori, Krishna (Schlumberger) | Singh, Mukund Murari (Schlumberger) | Shah, Arpit (Schlumberger) | Choudhary, Dinesh (Schlumberger) | Sharma, Lovely (Schlumberger) | Ray, Maria Fernandes (Schlumberger) | Sarkar, Samarpita (Schlumberger) | Moulali, Shaik (Oil and Natural Gas Corporation Limited) | Das, Santanu (Oil and Natural Gas Corporation Limited) | Rao, Dasari Papa (Oil and Natural Gas Corporation Limited)
Abstract The Triassic–Jurassic petroleum system reserves in Krishna Godavari Basin are found at 3500 to 4500 m depth with bottomhole static temperature (BHST) ranging from 270 to 340°F. Hydraulic fracturing is required to produce economically from these wells because the in-situ permeability of these sands is in the range of ~ 0.01 md. Hence, after perforations, minimal production is observed or the flash production from these wells dies out in a short time span. Between 2010 and 2017, several appraisal wells were drilled and completed using hydraulic fracturing in the onshore Krishna Godavari Basin. However, the success rate of effective fracture placement and sustained production enhancement due to hydraulic fracturing was limited. This was attributed to insufficient understanding of rock mechanical properties and lack of a refined fluid fracturing system despite using a superior fluid system like carboxymethyl hydroxypropyl guar (CMHPG) with organometallic zirconate-based crosslinkers. In 2018, nine wells were successfully hydraulically fractured, and sustained production from these wells was established using a simple borate-based crosslinked fluid system. A key change for the field was rather than designing and pumping fracturing fluid based on only BHST, one of the critical components that led to better proppant placement is the stable fracturing fluid that was fine tuned for the well based on factors like change of source water, tubular shear exposure time for designed fracturing treatment pumping rate, and hydrocarbon properties. This combination of rock mechanical properties and fracturing fluids used is captured as the efficiency of the fluid system, and this governed the usage of fluid loss additives, again a novel introduction for the field. Finally, the key to producing these sands was adequate cleanup and minimal guar residue to maximize the proppant pack conductivity. The paper also discusses the strategy to design fluids with minimal guar loading to reduce polymer retention and to achieve maximum fracture fluid recovery. This robust management of fracturing fluids along with understanding of rock mechanical properties can be seen in the post-fracturing production results.
- Phanerozoic > Mesozoic > Jurassic (0.70)
- Phanerozoic > Mesozoic > Triassic (0.61)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.61)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.68)
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...)
Unconventional North Kuwait Jurassic Well with Extended Reach Horizontal Well in Tight Limestone Aiming to Establish Firsts in Kuwait with a Hybrid Approach to Multiple Hydraulic Fracturing
SLB, L. Peiwu (slb Kuwait, Ahmadi, Kuwait) | Al Ansari, S. I. (Kuwait Oil Company, Ahmadi, Kuwait) | Al-Saadoun, D. (Kuwait Oil Company, Ahmadi, Kuwait) | Ajayi, A. (Shell Kuwait, Ahmadi, Kuwait) | Medvedev, O. (Shell Kuwait, Ahmadi, Kuwait) | Al-salali, Y. (Kuwait Oil Company, Ahmadi, Kuwait) | Fidan, E. (Kuwait Oil Company, Ahmadi, Kuwait)
Abstract An extended reach, record-breaking horizontal (NKJG-ERH) well, being appraised by the North Kuwait Jurassic Gas (NKJG) into the tight (unconventional) Middle Marrat reservoir flow zone sections. The objective of NKJG-ERH is beyond what's been implemented in the NKJG asset. A total along-hole depth is designed to exceed 20,000 ft with thousands of feet of tight Middle Marrat exposure which is designed to provide commercially attractive production rates from unconventional stimulation and fracturing options. Additionally, NKJG-ERH will provide several benefits which aim to overcome Sabriyah Middle Marrat well challenges, such as poor relative to the rest of the field reservoir quality, limited number of drilling locations, an underperformance of the vertical wells in the area. An extensive industry experience in delivering ERH wells in Unconventionals are applied with the plans to complete the well using 4 ½″ liner across the reservoir section and 5″ production tubing stabbed into a polished bore receptacle. NKJG-ERH will then utilize the Plug-n-Perf and Frac (PnPnF) technique over several stages that will be defined per the open hole and cement bond logs. Rigless operation of such magnitude will require millions of liters of frac fluid, proppant and acid fracturing chemicals as multiple and large treatments will be implemented in a hybrid approach (combination of acid fracs and proppant fracs). Proppant fracs will be required in this tight carbonate to frac through the tight limestone but to prop-open the overlying dolomitic zone of interest. The proppant is envisioned to increase the chances of higher sustenance of the high initial production rate aimed in this well. It is clear that a well of this magnitude will require unusual resources such as coiled tubing, plugs, milling and testing capabilities, fracturing resource provisions and others. It will also require designing and procuring of a fit-for-purpose coiled tubing string for cleaning out the wellbore and milling out frac plugs. This paper will discuss the design details of this out-of-ordinary appraisal and production well, and share the learnings pertaining to the design and implementation phases from early conception to the end of well release for production.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.63)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Upper Marrat Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sabiriyah Mauddud (SAMA) Formation (0.99)
- (7 more...)