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Results
Release the Unconventional Reservoir Potential with 3D Reservoir Characterization Method in Horizontal Wells
Xu, Wei (Sinopec Shengli Oilfield Co. Ltd.) | Yang, Donggen (Sinopec Shengli Oilfield Co. Ltd.) | Li, Shenzhuan (SLB China) | Gu, Xiao (SLB China) | Sun, Bo (Sinopec Shengli Oilfield Co. Ltd.) | Zhao, Daohan (Sinopec Shengli Oilfield Co. Ltd.) | Xin, Zhongbin (Sinopec Shengli Oilfield Co. Ltd.) | Zhao, Meng (SLB China) | Wu, Fangfang (SLB China) | Wu, Jinlong (SLB China) | Zhao, Xianran (SLB China)
Abstract The exploration and development of unconventional oil and gas resources have become anew hot frontier in China. In these reservoirs, the porosity is mainly less than 10%, and the permeability is mainly less than1.0mD. Hence, to maximize the productivity, horizontal wells are drilled, and big scale sand fracturing is usually designed to solve the problem. Horizontal well drilling is extremely difficult due to high heterogeneity and uncertain fault and fractures. The reservoir quality and completion quality vary along the borehole, and as a result, itis very difficult to optimize the stimulation design to unlock the potential of the reservoir. To provide better understanding of the reservoir in horizontal wells, we introduced an integrated solution which incorporates the reservoir evaluation for the pilot well and horizontal well and provided inputs for the optimization of horizontal well drilling and stimulation. Firstly, in the pilot well, we integrated micro-resistivity logging data, gamma-ray spectroscopy logging data, 2D NMR data to get accurate lithology, TOC, porosity, and oil saturation with an unconventional evaluation approach. Then, we built the petrophysical evaluation models using some AI algorithm, and criteria for horizontal wells. And the geologist conducted an accurate well correlation and built a3D structural model with new technology based on resistivity image data and conventional logs to target the best reservoir as much as possible when drilling the horizontal well. Finally, we combined Reservoir Quality (RQ), Completion Quality (CQ), and 3D structural models to design depths for the stages and perforation clusters and helped to optimize the stimulation design and helped to enhance the oil production. With this approach, we integrate the RQ and CQ parameters into the 3D structural model, not only can we evaluate the effective porosity, saturation, minerals, fractures and TOC along the wellbore, but also can get a clear picture of these properties in 3D distribution. Hence, multistage hydraulic fracturing design can be made more effectively and at lower cost. Application of this approach in several wells has helped to increase the production by 20%. It was used to use mud logs to divide the stages for fracking, and as a result, we could not get a clear idea about the RQ and CQ along the wellbore and close to the wellbore. We introduced movable oil porosity as a key petrophysical parameter to rank the reservoir more accurately and build a better geological model close to the wellbore to provide the guidance for fracking design.
- Geology > Geological Subdiscipline (1.00)
- Geology > Mineral > Silicate (0.49)
- Geology > Rock Type > Sedimentary Rock (0.34)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- (2 more...)
Tight Oil Field Development Challenges, Lessons Learnt and Successful Implementation of Selected Artificial Lift (SRP) Along with Operational & Digital Solutions: ABH Field, Rajasthan, India
Varma, Nakul (Cairn Oil & Gas, Vedanta Ltd) | Negi, Avdesh (Schlumberger) | Kumar, Manish (Cairn Oil & Gas, Vedanta Ltd) | Chauhan, Shailesh (Cairn Oil & Gas, Vedanta Ltd) | Bohra, Avinash (Cairn Oil & Gas, Vedanta Ltd) | Kothiyal, Manish (Cairn Oil & Gas, Vedanta Ltd)
ABSTRACT Aishwariya Barmer Hill (ABH) field area consists of a laminated high porosity (25-35%), low permeability (~1 mD) unit of 50-250 meters thick hydrocarbon bearing payzone. With the success of the first 6 pilot wells, it was decided to extend to the whole field with more than 44 horizontal wells. The horizontal wells are ~2300-2600 mMD long, lateral average length of 1000m and multistage hydraulic fracturing (10-17). These wells face numerous complications due to high gas-oil ratio, sand production, and corrosion tendencies because of high CO2 mole percent concentration (40-60%) in fluid. Further complications include downhole pumps setting at very high deviation (60-65 deg), rod failures-wear in high deviation wells, rod rotation due to deviation and gradual productivity declines due to sand deposition at lower side of downhole completion. Due to low permeability and low mobility fluid nature, it was necessary to find efficient ways to enhance the overall hydrocarbon recovery factor of the field. Several sensitivities were performed, on the number of wells, number of hydraulic fractures, well design, artificial lift options, water, and gas injection. According to the sensitivities results, the best developed scenario envisages high number of multiple frac wells to increase the recovery factor. Based on the detailed evaluation of available artificial lift options, SRP was selected over Jet pumps as the most suitable artificial lift considering the requirement of large drawdowns & operating costs of lifts. The risk of gas issues was mitigated by keeping the tubing-production casing annulus vented and further alleviated by running suitable downhole gas separators. Other problems were analyzed, and multiple attempts of solution implementation were done. This paper addresses an inhouse ways to tackle sand, high gas rate issues, along with rectifications &learning of other problems faced during the last 3 years of field operations, including digitalization projects for visualization of well behavior. This paper also addresses a few remarkable calculated parameters which are - actual production loss calculations whenever well is shut-in (considering wellbore column storage effects), calculated gas free liquid level pump submergence and pump intake pressure from pump load live data. The purpose of this paper is to describe technical & operational challenges along with lessons learnt/solutions implemented in last 3 years.
- North America > United States > Mississippi > Improve Field (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Mangala Field > Barmer Hill Formation (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Bhagyam Field > Barmer Hill Formation (0.99)
- (4 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Completion Selection and Design > Completion equipment (1.00)
- (7 more...)
- Information Technology > Sensing and Signal Processing (0.94)
- Information Technology > Architecture > Real Time Systems (0.47)
This Dictionary contains more than 3,200 entries and presents a terminology-guided summary of the gravity and magnetic theory, measuring instruments, methods of data acquisition, processing, analysis, and interpretation for geophysical studies of the Earth and other planets. Terrestrial applications include engineering (karst and faults), geodesy, geothermal, groundwater, volcano and global tectonic studies, CO2 sequestration and reservoir monitoring, as well as exploration for oil and gas, rare earth elements (REE), iron, gold, and other mineral resources.
- Oceania > Australia (1.00)
- North America > United States > Texas (1.00)
- North America > United States > Louisiana (0.92)
- (4 more...)
- Geology > Structural Geology > Tectonics > Plate Tectonics (1.00)
- Geology > Structural Geology > Tectonics > Extensional Tectonics (1.00)
- Geology > Structural Geology > Fault (1.00)
- (17 more...)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- (12 more...)
- Transportation > Air (1.00)
- Media (1.00)
- Materials > Metals & Mining > Iron (1.00)
- (11 more...)
- North America > Canada > Saskatchewan > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Northwest Territories > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Manitoba > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- (10 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- (19 more...)
Abstract This paper presents a novel application of pressure transient analysis to calculate completion efficiency in long horizontal wells with limited entries to calculate completion efficiency in long horizontal wells, using pressure transient analysis to unleash flow efficiency restrictions and maximize well productivity. This calculation scheme could be done prior to well drilling using reservoir data and calculating unsteady flow pressure perturbation around flow ingresses, using Green's functions, or during production modes at any time using downhole pressure transient behavior at each flow restriction. The total flow efficiency is impacted by the configuration of well architecture and the distribution of flow entries along horizontal sections and laterals. The unsteady flow pressure perturbation could be augmented into the wellbore flow hydraulics to determine the overall performance of wells, especially in finite-conductivity horizontal and multilateral wells. The use of pressure transient analysis showed a very instrumental tool to calculate the overall efficiency of completion in horizontal wells. It can explain why some horizontal wells didn't produce to the design capacity and help salvage well completion design. This advanced calculation scheme has never been used as a tool to calculate a completion efficiency factor by which the overall all performance of horizontal wells are measured. The scheme is an innovative way to design and maximize well completion to decide on the configuration of well architecture and placement of flow entries/restrictions in horizontal sections. This is best applied during production mode to continuously monitoring completion efficiencies in cases where multiphase flow occurs, with real-time data acquisition of pressure transient downhole.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Pressure transient analysis (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Sensing and Signal Processing (0.89)
Summary The Orinoco Oil Belt in Venezuela contains the largest known deposits of heavy oil in the world, and Cerro Negro is part of the fields in this area. However, the sand production is a major issue which affects the oil production in this field. There are some major issues that stand in the way of the proper cleanout of these wells. These problems include low reservoir pressure, geometry of the wells, and extremely high oil viscosity. Another major problem is the presence of big pieces of progressing cavity pumps (PCP) elastomers, some metallic parts from pressure and temperature sensors configuration, and other metallic parts from previous workover rig operations, encountered during cleanout operations. As a result of these difficulties, some of the past jobs performed in this field were unsuccessful. After these unssuccessful jobs, a campaign of recent multiple sand cleanout jobs was planned in the Cerro Negro field. Numerous difficulties arose during these jobs. These issues were largely due to the presence of big pieces of PCP elastomers and metallic parts. An additional issue was the low reservoir pressure. Due to the size of the casing/liner and the horizontal section, the annulus fluid velocity obtained was insufficient. Therefore, several techniques were applied to overcome these problems. One of these methods was to use reverse circulation for the sand cleanout in the 9-5/8-in. slanted casing section, while circulation was still possible to obtain a higher fluid velocity. Afterward, once the circulation was lost, a special stroking pump was used alongside a large string of tubing to store large amounts of sand and debris. This tool was also used to recover pieces of PCP elastomers and other metallic parts. This tool uses a piston pump to create a vacuum effect, and fluid circulation is not needed for the cleanout. Without this innovative stroking pump, it would have been almost impossible to recover these large pieces. This was the first time this innovative tool was used in these types of wells. When the open horizontal 7-in. production zone was reached, coiled tubing (CT) was used with the proper proportion of diesel and nitrogen to obtain enough fluid velocity and the proper equivalent density. In the end, when necessary, a smaller reliner was run depending on the information obtained during the analysis of the grain sizes. Some techniques were applied to run the reliner successfully in an old and worn out casing, where the geometry of the well and high doglegs caused difficulties. The challenges to complete the cleanout of the well with lost circulation problems included a large annulus area in the highly slanted and horizontal sections, the extremely high oil viscosity, and the presence of large pieces of PCP and metallic parts. These challenges were overcome by using different methods such as the special stroking pump, reverse circulation in the 9.625-in. section, and CT with the proper diesel and nitrogen proportions. Additionally, to keep sand production under control in the cleaned wells, a smaller reliner was run. Finally, these workover jobs were finalized to bring these wells back into production successfully. The oil production results of these operations are shown in this paper, and demonstrated that it is possible to retrieve the production in the sanded wells of the Orinoco Belt in a profitable way.
- South America > Venezuela > Anzoátegui (0.60)
- South America > Argentina > Santa Cruz Province (0.60)
- South America > Argentina > Mendoza Province (0.60)
- South America > Argentina > Chubut Province (0.60)
- South America > Venezuela > Carupano Basin > PetromonaField (0.99)
- South America > Venezuela > Anzoátegui > Eastern Venezuela Basin > Maturin Basin > Cerro Negro Area Field (0.99)
- Well Drilling > Pressure Management (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Sand Control (1.00)
- (6 more...)
- Information Technology > Sensing and Signal Processing (0.54)
- Information Technology > Communications > Networks > Sensor Networks (0.54)
Abstract Horizontal well completions are often equipped with Inflow Control Devices (ICDs) to optimize flow rates across the completion for the whole length of the interval and to increase the oil recovery. The ICD technology has become useful method of optimizing production from horizontal wells in a wide range of applications. It has proved to be beneficial in horizontal water injectors and steam assisted gravity drainage wells. Traditionally the challenges related to early gas or water breakthrough were dealt with complex and costly workover/intervention operations. ICD manipulation used to be done with down-hole tractor conveyed using an electric line (e-line) cable or by utilization of a conventional coiled tubing (CT) string. Wellbore profile, high doglegs, tubular ID, drag and buoyancy forces added limitations to the e-line interventions even with the use of tractor. Utilization of conventional CT string supplement the uncertainties during shifting operations by not having the assurance of accurate depth and forces applied downhole. A field in Saudi Arabia is completed with open-hole packer with ICD completion system. The excessive production from the wells resulted in increase of water cut, hence ICD's shifting was required. As operations become more complex due to fact that there was no mean to assure that ICD is shifted as needed, it was imperative to find ways to maximize both assurance and quality performance. In this particular case, several ICD manipulating jobs were conducted in the horizontal wells. A 2-7/8-in intelligent coiled tubing (ICT) system was used to optimize the well intervention performance by providing downhole real-time feedback. The indication for the correct ICD shifting was confirmed by Casing Collar Locator (CCL) and Tension & Compression signatures. This paper will present the ICT system consists of a customized bottom-hole assembly (BHA) that transmits Tension, compression, differential pressure, temperature and casing collar locator data instantaneously to the surface via a nonintrusive tube wire installed inside the coiled tubing. The main advantages of the ICT system in this operation were: monitoring the downhole force on the shifting tool while performing ICD manipulation, differential pressure, and accurately determining depth from the casing collar locator. Based on the known estimated optimum working ranges for ICD shifting and having access to real-time downhole data, the operator could decide that required force was transmitted to BHA. This bring about saving job time while finding sleeves, efficient open and close of ICD via applying required Weight on Bit (WOB) and even providing a mean to identify ICD that had debris accumulation. The experience acquired using this method in the successful operation in Saudi Arabia yielded recommendations for future similar operations.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Sensing and Signal Processing (0.94)
Integration Success Story in Shilaif Shale Oil from Vertical Pilot to Horizontal
Alharthi, Amena Dhawi (ADNOC) | Van Laer, Pierre (ADNOC) | Brooks, Trevor (ADNOC) | Goiran, Pierre Olivier (ADNOC) | Baig, Muhammad Zeeshan (ADNOC) | Lazreq, Nabila (ADNOC) | Abdelhalim, Hamza (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Coscia, Marco (ADNOC)
Abstract The development of unconventional target in the Shilaif formation is in line with the Unconventional objective towards adding to ADNOC reserves. For future optimization of development plans, it is of utmost importance to understand and test and therefore prove the productivity of the future Unconventional Horizontal Oil wells. The Shilaif formation was deposited in a deeper water intrashelf basin with thicknesses varying from 600 to 800 ft from deep basin to slope respectively. The formation is subdivided into 3 main composite sequences each with separate source and clean tight carbonates. The well under consideration (Well A-V for the vertical pilot and Well A-H for the horizontal wellbore) was drilled on purpose in a deep synclinal area to access the best possible oil generation and maturity in these shale Oil plays. Due to the stacked nature of these thick high-quality reservoirs, a pilot well is drilled to perform reservoir characterization and test hydrocarbon type and potential from each bench. Fracturing and testing are performed in each reservoir layer for the primary purpose to evaluate and collect key fracturing and reservoir parameter required to calibrate petrophysical and geomechanical model, landing target optimization and ultimately for the design of the development plan of this stacked play. Frac height, reservoir fluid composition and deliverability, pore pressure are among key data collected. The landing point selected based on the comprehensive unconventional core analysis integrated with petrophysical and geomechanical outcomes using post vertical frac and test results. Well A-H was drilled as a sidetrack from the pilot hole Well A-V. This lateral section was logged with LWD Triple Combo while Resistivity Image was acquired on WL. Based on the logging data the well stayed in the target Layer / formation, cutting analysis data for XRD and TOC was integrated with the petrophysical results in A-H well. Production test results from subject were among the highest rate seen during exploration and appraisal of this unconventional oil plays and compete with the current commercial top tier analog unconventional oil plays. Achieving those results in such early exploration phases is huge milestone for ADNOC unconventional exploration journey in UAE and sign of promising future development.
- North America (0.68)
- Europe > Norway > Norwegian Sea (0.45)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.18)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.70)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.61)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.46)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- (2 more...)
- Information Technology > Sensing and Signal Processing (0.46)
- Information Technology > Architecture > Real Time Systems (0.46)
Development of Tight Upper Cretaceous Reservoir in Offshore Black Sea Adds Life to a Mature Asset
Mitrea, I. (M. Chraief OMV Petrom S.A.) | Cataraiani, R. (M. Chraief OMV Petrom S.A.) | Banu, M. (M. Chraief OMV Petrom S.A.) | Shirzadi, S. (M. Chraief OMV Petrom S.A.) | Renkema, W. (M. Chraief OMV Petrom S.A.) | Hausberger, O. (M. Chraief OMV Petrom S.A.) | Morosini, M. (M. Chraief OMV Petrom S.A.) | Grubac, G. (M. Chraief OMV Petrom S.A.)
Abstract This Upper Cretaceous reservoir, a tight reservoir dominated by silt, marl, argillaceous limestone and conglomerates in Black Sea Histria block, is the dominant of three oil-producing reservoirs in Histria Block. The other two, Albian and Eocene, are depleted, and not the focus of field re-development. This paper addresses the challenges and opportunities that were faced during the re-development process in this reservoir such as depletion, low productivity areas, lithology, seismic resolution, and stimulation effectiveness. Historically, production from Upper Cretaceous wells could not justify the economic life of the asset. As new fracturing technology evolved in recent years, the re-development focused on replacing old, vertical/deviated one-stage stimulations low producing wells with horizontal, multi-stage hydraulic fractured wells. The project team integrated various disciplines and approaches by re-processing old seismic to improve resolution and signal, integrating sedimentology studies using cores, XRF, XRD and thin section analysis with petrophysical evaluation and quantitative geophysical analyses, which then will provide properties for geological and geomechanical models to optimize well planning and fracture placement. Seven wells drilled since end of 2017 to mid-2021 have demonstrated the value of integration and proper planning in development of a mature field with existing depletion. Optimizing the well and fracture placement with respect to depletion in existing wells resulted in accessing areas with original reservoir pressure, not effectively drained by old wells. Integrating the well production performance with tracer results from each fractured stage, and NMR/Acoustic images from logs enhanced the understanding of the impact of lithofacies on stimulation. This has allowed better assessment and prediction of well performance, ultimately improving well placement and stimulation design. The example from this paper highlights the value of the integrating seismic reprocessing, attribute analysis, production technology, sedimentology, cuttings analysis and quantitative rock physics in characterizing the heterogeneity of the reservoir, which ultimately contributed to "sweet spot" targeting in a depleted reservoir with existing producers and deeper understanding of the development potential in Upper Cretaceous. The 2017-2021 wells contribute to more than 30 percent of the total oil production in the asset and reverse the decline in oil production. In addition, these wells have two to four times higher initial rates because of larger effective drainage area than a single fracture well. Three areas of novelty are highlighted in this paper. The application of acoustic image/NMR logging to identify lithofacies and optimize fracturing strategy in horizontal laterals. The tracers analysis of hydraulic fracture performance and integration with seismic and petrophysical analysis to categorize the productivity with rock types. The optimization of fracture placement considering the changes of fluid and proppant volumes without compromising fracture geometries and avoiding negative fracture driven interactions by customized pumping approach.
- North America > United States > Texas (0.67)
- North America > Canada > Alberta (0.66)
- Europe > Romania > Black Sea (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.49)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.34)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.86)
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean > Columbus Basin > South East Galeota Block > Cannonball Field (0.99)
- Europe > Bulgaria > Black Sea > Black Sea Basin > Western Black Sea Basin (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Western Black Sea Basin > Lebada East Field (0.98)
- (2 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- (3 more...)
- Information Technology > Artificial Intelligence (1.00)
- Information Technology > Sensing and Signal Processing (0.93)
- Information Technology > Architecture > Real Time Systems (0.46)
Abstract Immediately offsetting the Hydraulic Fracture Test Site II (HFTS II) were two horizontal wells that had been fracture stimulated and produced for several years. Horizontal well image logs recorded in the new HFTS II laterals were used to describe the existing hydraulic fracture geometry for reservoir simulation and to calibrate a 3D hydraulic fracture model. Similarly, in a Rocky Mountain Powder River Basin Turner development a standalone multifractured horizontal well was produced prior to drilling adjacent infill horizontal wells. Horizontal well image logs were recorded in the multiple offsetting laterals to describe the existing hydraulic fracture geometry for hydraulic fracture modeling and reservoir simulation. The image log observations were critical in defining a development plan and well spacing for the Turner formation. When standalone wells are drilled and stimulated by hydraulic fracturing, image logs recorded in the lateral of subsequent offset horizontal wells are a powerful diagnostic tool that can be used to understand hydraulic fracture geometry and to calibrate reservoir simulators. Unlike far-field fiber optic strain-rate measurements or closed-wellbore pressure monitoring, which provide a dynamic observation of hydraulic fracture growth between horizontal wells, image logs provide a static observation of hydraulic fractures that originated from a standalone or "parent" well and crossed an offset wellbore. Fracture swarms observed in an image log can often be extrapolated back to the parent well perforation cluster corresponding to the hydraulic fracture origin. Since hydraulic fractures grow as swarms, an algorithm accounting for swarm width was developed to aid in the correlation of image log hydraulic fracture swarms to perforation clusters in a parent well (or wells) to improve the confidence in the analysis. In HFTS II, 90% of the image log observed fractures had a dip angle greater than 70°, which is often indicative of hydraulic fractures, and 75% of the interpreted fractures were within the expected fracture azimuth window. Fifty-six percent of the image log fractures could be correlated back to the treatment well clusters using a 5-ft swarm window, but the correlation improved to 96% using a 0.5° azimuth window. Hydraulic fractures from both treatment wells impacted the HFTS II infill wells and having two treatment wells increases the difficulty in identifying the originating cluster for each fracture swarm. In the Turner formation, 100% of the fractures had a dip angle greater than 70° and were within the expected fracture azimuth window, which suggests all fractures were hydraulic fractures. Even though a single parent well as a source simplifies the analysis somewhat, only 55% of the image log fractures could be correlated back to discrete clusters. The correlation improved to 98% when the using stage origination as opposed to discrete cluster locations. Lastly, the image logs demonstrated conclusively that hydraulic fracture half-length was greater than 2,640 ft in all treatment stages.
- North America > United States > Colorado (1.00)
- North America > United States > Texas > Harris County > Houston (0.28)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.68)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.46)
- North America > United States > Wyoming > Powder River Basin (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (30 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Information Technology > Modeling & Simulation (0.55)
- Information Technology > Communications > Networks (0.49)
- Information Technology > Sensing and Signal Processing (0.46)
A major challenge of Arabian heavy‑oil development is the problem of generating competitive advantages through deploying technological innovations while making cost-effective solutions a crucial part of a firm's strategy for rigless interventions. The purpose of this paper is to examine coiled-tubing (CT) -stimulation and -logging technologies used in the timely project execution of one of Saudi Arabia's largest field developments to enhance matrix-stimulation success in a cost-effective manner. The Manifa field is located in Saudi Arabia and measures approximately 45 km in length and 18 km in width, encompassing both onshore and offshore areas with water depths between 4 and 6 m. It was discovered in 1957, with first sustained production in 1964. However, because of low demand, the field was shut down in 1984.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (6 more...)
- Information Technology > Architecture > Real Time Systems (0.74)
- Information Technology > Sensing and Signal Processing (0.48)