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ABSTRACT This paper describes a case history using an improved cement bond evaluation workflow integrating traditional cement evaluation logs and downhole permanent temperature data in a tight oil play in southern Oklahoma. A pair of producer and monitor wells were drilled and completed in a field development study project. Comprehensive data collection and analytics were carried out to devise an optimized well placement strategy in a basin with heterogeneous reservoir rocks and stacked pay zones. With permanent installation of pressure and temperature gauge arrays and fiber optic sensors in the casing annulus of the monitoring well, it is critical to accurately assess cement quality and well integrity to ensure that satisfactory zonal isolation is achieved. Minimal cross-gauge interference is desired for reliable real-time data acquisition during fracture stimulation and production monitoring. Cement evaluation log interpretation is inherently qualitative and subjective in nature. To this end, a multi-physics data interpretation workflow was used to integrate downhole distributed temperature data recorded during cementing operations with conventional acoustic cement evaluation log data. A thorough cement evaluation logging program was devised to collect sonic and pulse-echo ultrasonic logs under standard and pressurized wellbore conditions. Also included in the logging program was a time-lapse component comprised of additional logging runs after the hydraulic fracture operation performed in the nearby producer. The comparison of before and after frac data analyses provides valuable insight in the interpretation process to evaluate growth of fractures originated from producer and propagating to monitor wellbores. Results from the integrated workflow indicate that zonal isolation has been achieved across the instrumented segment of the monitor wellbore. Although features such as micro-debonding and small-scale liquid filled voids were observed in certain intervals, these low impedance features do not appear to be interconnected. No fluid channels and conduits around fiber optic cables were observed. Temperature data illustrates cement slurry flow during placement as well as the post-placement cement hydration process. The ultrasonic pulse-echo log proved to be critical in understanding casing integrity. The time lapsed cement evaluation logs show signs of cement bond improvement suggesting that a post completion compaction trend acts upon the wellbore.
- North America > United States > Texas > Permian Basin > Midland Basin (0.99)
- North America > United States > Texas > Permian Basin > Delaware Basin (0.99)
- North America > United States > New Mexico > Permian Basin > Delaware Basin (0.99)
- (24 more...)
- Well Drilling > Casing and Cementing > Cement and bond evaluation (1.00)
- Well Completion (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
- Information Technology > Communications > Networks > Sensor Networks (0.34)
Holistic Integrated Approach for Reliable Leak Detection Using Beamforming of Acoustic Waveform and Basic Cased Hole Logging
Kozlowski, Maciej (Halliburton) | Howard, Rodney (Halliburton) | Vican, Kresimir (Halliburton) | Lee, Chung Yee (Halliburton) | Dominguez, Ana Maria Garcia (Enagas Transporte SAU) | Cansado, Borja Gonzalez (Enagas Transporte SAU)
ABSTRACT Well integrity is the obvious condition for safe and reliable well operations, therefore reliable logging diagnosis and description of present leaks is necessary to plan and conduct effective and safe remediation. The case study well is an underground gas storage reservoir located on land. During a recent workover, the upper completion was removed and as a best practice a multi-finger caliper survey was performed to check the status and integrity of the casing. No major problems with casing integrity were identified. The Operator subsequently installed a new upper completion, and a successful pressure test was conducted confirming tubing integrity. However, a significant pressure drop was observed during testing annulus A – between tubing and the casing. Since no potential leak point could be ascertained from the multi-finger caliper logging the customer confirmed a requirement to perform further diagnosis with cased hole logging in the tubing to detect the leak. The proposed methodology included acquisition and analysis of basic production logging sensor analysis in both static and dynamic conditions along with spectral noise leak detection tool logging in continues and stationary mode. The results of the subsequent logging acquisition program were consistent and pointed out a few areas of concern where the source of the leak could exist. The key element of investigation was beamforming analysis of the acoustic waveform. Beamforming yields an estimate of the radial distance of the noise source of the leak from the tool. The beamforming analysis combined with corroborating data from high resolution temperature (PRT), multi-finger caliper (MIT), casing collar locator (CCL) pin-pointed the leak source at a collar connection, thus distinguishing it from tubing to casing or formation noise, as the source of the leak. This holistic approach required analysis of all available logging data – starting from basic cased hole logging sensors and advanced techniques for radial noise location. Especially beamforming technology allows for identification of radial distance as well as drawing of the flow map at the leak point.
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
We will make facility The new governance model that expanded the Board of Directors adjustments so that a larger percentage of abstracts can be accepted two years ago has spread the workload of individual Board in future years. The SEG Annual Meeting is not the only members. It has also provided some year-to-year continuity in large meeting that SEG has a hand in each year, but the others oversight of SEG program activities. I have been privileged to are often partnerships with sister organizations. SEG partners be on the Board with some of the most dedicated, talented, and with the Society of Petroleum Engineers (SPE), the American effective members of the Society, and they have served the Society Association of Petroleum Geologists (AAPG), and the European well. I will hand over the presidential reins to Chris Liner in Association of Geoscientists and Engineers (EAGE) to October, and I can assure you that SEG will be in good hands.
- South America (1.00)
- North America > Canada (1.00)
- Europe (1.00)
- (6 more...)
- Instructional Material > Course Syllabus & Notes (1.00)
- Financial News (1.00)
- Research Report (0.92)
- (2 more...)
- Geology > Structural Geology > Tectonics (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.66)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Magnetic Surveying (1.00)
- (5 more...)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > China Government (0.67)
- North America > United States > Oklahoma > Arkoma Basin > Cana Woodford Shale Formation (0.99)
- North America > United States > Arkansas > Arkoma Basin > Cana Woodford Shale Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Abu Dhabi Field (0.97)
- (10 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- (17 more...)
- Information Technology > Artificial Intelligence (1.00)
- Information Technology > Information Management (0.92)
- Information Technology > Communications > Social Media (0.92)
- Information Technology > Sensing and Signal Processing (0.92)
Abstract The second phase of Johan Sverdrup came on stream in December 2022. This paper focuses on the execution of Johan Sverdrup phase 2 and describes the assessments and investments for improved oil recovery (IOR) from one of the largest oil fields in Norway. The Johan Sverdrup field development has been called Equinor's ‘digital flagship’, and this paper includes the proof of concept for the digital initiatives after more than three years of operation. Despite the Covid-19 pandemic Johan Sverdrup phase 2 has been able to deliver on schedule, under budget, and with an excellent safety record. The paper includes experiences from the concept development and engineering phase to the global contracting strategy, through the construction on multiple building sites in Norway and globally, and until the end of the completion phase offshore Norway. Johan Sverdrup is the third largest oil field on the Norwegian Continental Shelf (NCS), and with recoverable reserves estimated at 2.7 billion barrels of oil equivalents, has the resources to be a North Sea Giant. Start-up of the Johan Sverdrup phase 2 extends and accelerates oil and gas production from the NCS for another five decades. This paper aims to highlight what it took to make Johan Sverdrup a true North Sea Giant, fit for the 21st century: a safe and successful execution of a mega-project, with next-generation facilities adapted to a more digital way of working, with an ambition to profitably recover more than 70% of the resources, while limiting carbon emissions from production to a minimum. In many ways the Johan Sverdrup development has set a new standard for project execution in Equinor. The impact of different variables made during the execution of the project, such as the Covid-19 pandemic, market effects, procurement strategies, value improvement initiatives, execution performance and reservoir characteristics is addressed, as well as describing assessments and investments for improved oil recovery (IOR). Data acquisition, Permanent Reservoir Monitoring (PRM), fibre-optic monitoring of wells, innovative technologies, and digitalization, as well as new ways of working are included. Equinor´s digital strategy was established in 2017, and Johan Sverdrup was highlighted as a digital flagship at that time and a frontrunner in applying digital solutions to improve safety and efficiency from the development to the operational phase. What has been implemented so far together with experiences will be shared.
- Europe > Norway > North Sea > Central North Sea > Utsira High > PL 501 > Block 16/5 > Johan Sverdrup Field > Zechstein Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Utsira High > PL 501 > Block 16/5 > Johan Sverdrup Field > Viking Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Utsira High > PL 501 > Block 16/5 > Johan Sverdrup Field > Vestland Group (0.99)
- (58 more...)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Management > Strategic Planning and Management > Project management (1.00)
- (8 more...)
- Information Technology > Sensing and Signal Processing (0.93)
- Information Technology > Communications > Networks > Sensor Networks (0.93)
- Information Technology > Artificial Intelligence (0.68)
Abstract A deviated well in Caspian Sea with 5-in open hole gravel pack (OHGP) screens started production on 2009 (Fig. 1). Oil production rate was stable until mid-2017 when it started to decline rapidly with a water breakthrough that reached 90% before well was shut-in on early 2022. Due to wax deposition in the tubing, 30 m3 of wax dissolver was injected in mid-2022, before the well was shut in. A de-completion operation to isolate existing reservoir and sidetrack started on mid-2022. During a slickline operation with a 4.275-in. drift, a hold up depth was reached at 60m MD recovering heavy wax on tool string. With a 3.5-in. gauge cutter and 3-in. dump bailer, maximum depth reached was 145m MD. At this time, a decision was made to perform a Coiled Tubing (CT) clean out operation until target depth of 4,200m MD for de-completion operation. Three runs were performed with a tubing encapsulated electrical wire enabled CT telemetry (CTT) system which consists of a customized Bottom-Hole Assembly (BHA) that transmits real-time differential pressure, temperature, and casing collar locator (CCL) data for depth correlation to surface through a non-intrusive tube wire installed inside the CT. For the first time in the region, a Tension Compression Torque (TCT) sensor was deployed with a High-Pressure Rotary Jetting (HPRJ) tool to control the wax clean out process with accurate measurement of axial forces downhole. After successfully reaching 215m MD with HPRJ tool, two additional runs were done with the CTT system. First, a drift run with 5-in Outside Diameter (OD) fluted centralizer to confirm 7-in tubing section clearance up to 199.3m MD and a second drift run with 4.275-in fluted centralizer to target depth at 4,200m MD to confirm 5.5-in tubing clearance. Figure 1: Well 3D Survey CTT technology was a key element to successfully clean out wax on the 7-in and 5.5-in tubing sections. De-completion operations were completed after this intervention as follows: set a bridge plug at 4,115m MD, cut the 5.5-in tubing at 4,084.5m MD, circulate the well and pull out the upper completion to prepare the well for subsequent sidetrack operations. Using the CTT system and TCT sensor for real-time data monitoring of the HPRJ tool at bottom-hole conditions during a wax clean out operation was proven, thus, expanding their use in the field.
- Asia (1.00)
- North America > United States > Texas (0.96)
- 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)
- Production and Well Operations (1.00)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)
Static Gradient Survey Reveals Temperature Anomaly in the CaMI CO2 Injection Well
Behmanesh, Hamid (Carbon Management Canada) | Cooper, Joanna (Carbon Management Canada, University of Calgary) | Macquet, Marie (Carbon Management Canada) | Kolkman-Quinn, Brendan (Carbon Management Canada) | Lawton, Donald (Carbon Management Canada, University of Calgary) | Osadetz, Kirk (Carbon Management Canada) | Maidment, Greg (Carbon Management Canada)
Abstract In view of the complex wellbore dynamics associated with liquid/vapor CO2 in the Containment and Monitoring Institute (CaMI) of Carbon Management Canada (CMC) CO2 injection wellbore, a Static Gradient Survey was conducted with the focus on the verification of in-tubing pressures and temperatures at various depths in the wellbore. Specifically, the knowledge sought was to learn about the temperature profile in the regions above and below the gas-liquid interface as well as the temperature profile below the Distributed Temperature Sensing (DTS) fiber termination point in the well, where there is no temperature measurement. For the static gradient survey, four surveys (passes) were conducted over a span of 6 hours, using tandem pressure/temperature recorders. For the first and second passes, loweringand raisingthe wireline string in and out of the wellat a steady rate was undertaken. The third pass involved stopping the gauges at specified depths for approximately 10 minutes prior to extracting them out of the wellbore. Recognizing that the responses of the gauges to temperature were much slower than to pressure, the duration of the stops variedat different depths, depending on the location of interest. The final pass took place some 6 hours after the initial run. The location of the liquid level in the well was identified, not only by the change in pressure gradients but also by a change in temperature gradients. At the gas-liquid interface, the liquid was boiling and caused localized cooling around the interface. This cooling event was registered in the DTS data where the temperature departed from the baseline temperature gradient. Another cooling event was observed near the base of the wellbore where the recorded temperature profile cooled before it again approached the normal thermal gradient. We interpreted the cause of this cooling event to be that some of the injected CO2 has migrated up-section into the shallower formation. The corresponding decrease of pressure caused a phase change and evaporationof CO2 which resulted in a reduction in the CO2 temperature. The temperature anomaly at the base of the injection well is consistent with the geophysical monitoring results from vertical seismic profiles (VSP) and the borehole electrical resistivity tomography (ERT) surveys. Understanding of the thermal processes related to Geologic Carbon Storage(GCS) is crucial for a successful deployment of projects. Our observations of temperature anomalies within the reservoir will contribute to the feasibility of employing temperature signals as a monitoring tool for the subsurface migration of the CO2 plume.
- Geology > Geological Subdiscipline (0.68)
- Geology > Rock Type > Sedimentary Rock (0.46)
- Information Technology > Sensing and Signal Processing (0.48)
- Information Technology > Communications > Networks > Sensor Networks (0.48)
New Experimental Results Show the Application of Fiber Optic to Detect and to Track Gas Position in Marine Risers and Shed Light on the Gas Migration Phenomenon Inside a Closed Well
Santos, Otto (Louisiana State University (Corresponding author)) | Almeida, Mauricio (Louisiana State University) | Sharma, Jyotsna (Louisiana State University) | Kunju, Mahendra (Louisiana State University) | Chen, Yuanhang (Louisiana State University) | Waltrich, Paulo (Louisiana State University)
Summary The main objective of this paper is to present and discuss the results and significant observations gathered during 13 experimental runs conducted in a full-scale test well at Louisiana State University (LSU). The other two objectives of this manuscript are to show the use of distributed fiber-optic sensing and downhole pressure sensors data to detect and track the gas position inside the test well during the experiments, and to discuss experimental and simulated data of the gas migration phenomenon in a closed well. An existing test well at LSU research facilities was recompleted and instrumented with fiber-optic sensors to continuously collect downhole data and with four pressure and temperature downhole gauges at four discrete depths within an annulus formed by 9 5/8 in. casing and 2 7/8 in. to a depth of 5,025 ft. A chemical line was attached to the tubing allowing the nitrogen injection at the bottom of the hole. The research facilities were also equipped with a surface data acquisition system. The experiments consisted in injecting nitrogen into the test well filled with water by two means: either injecting it down through the chemical line or down through the tubing to be subsequently bullheaded to the annulus. Afterward, either the nitrogen was circulated out of the well with a backpressure being applied at surface to mimic a managed pressure drilling (MPD) operation or left to migrate to the surface with the test well closed. During the runs, the three acquisition systems (fiber optic, downhole gauges, and surface data acquisition) recorded all relevant well control parameters for a variety of gas injected volumes (2.0–15.1 bbl), circulation rates (100–300 gal/min), and applied backpressures (100–300 psi). The experimental results gathered by the acquisition systems were very consistent in measuring gas velocities inside the well. The numerical model predictions matched very close to the pressure behavior observed in the experimental trials. In the gas migration experiments, it was observed that the stabilized casing pressure at the end of gas migration is less than the initial bottomhole pressure, and it is a function of the volume of gas injected in the well. These facts are supported by the numerical simulation results. In this paper, we show the possibility of the use of fiber-optic and downhole pressure sensors information to detect and track the gas position inside a well or the marine riser during normal or MPD operations. Additionally, the vast amount of experimental data gathered during the experiments in which the nitrogen was left in the closed well to migrate to surface helped shed light on the controversial issue concerning the surface pressure buildup while the gas migrates to surface in a closed well. Numerical simulations were all instrumental for supporting the findings.
- South America (0.92)
- North America > United States > Texas (0.68)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- Well Drilling > Pressure Management (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- (3 more...)
- Information Technology > Sensing and Signal Processing (1.00)
- Information Technology > Communications > Networks > Sensor Networks (1.00)
Abstract HPHT wells are typically associated with high complexity, technically challenging, long duration, high risk and high NPT as many things could go wrong especially when any of the critical nitty- gritty details are overlooked. The complexity is amplified with high risk of losses in carbonate reservoir with high level of contaminants compounded by the requirement of high mud weight above 17 ppg during monsoon season in an offshore environment. The above sums up the challenges an operator had to manage in a groundbreaking HPHT carbonate appraisal well which had successfully pushed the historical envelope of such well category in Central Luconia area, off the coast of Sarawak where one of the new records of the deepest and hottest carbonate HPHT well had been created. This well took almost 4 months to drill with production testing carried out in a safe and efficient manner whereby more than 4000m of vertical interval was covered by 6 hole sections. With the seamless support from host authority, JV partners and all contractors, the well was successfully delivered within the planned duration and cost, despite the extreme challenges brought about by the COVID-19 pandemic. This paper will share the experience of the entire cycle from pre job engineering/planning, execution, key lesson learnt and optimization plan for future exploitations which includes an appraisal well and followed by more than a dozen of development wells.
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drillstring Design (1.00)
- Well Drilling > Drilling Operations (1.00)
- (11 more...)
- Information Technology > Sensing and Signal Processing (0.68)
- Information Technology > Architecture > Real Time Systems (0.47)
Abstract The study is based on multi well analysist drilled side by side in carbonate reservoir using high-resolution resistivity image. The objective is to define reservoir characterization, facies architecture, heterogeneity, and connectivity between two wells that is ready for reservoir modeling. The methods presented in this paper are using an automatic inversion and advanced algorithm to generate matrix conductivity images and curves, histogram, analyses rock texture heterogeneities, quantify fluid filled vugs density from high resolution borehole images, fast extraction of dips (beds, fractures), delineate planar features crossing deviated borehole over long distances, extract fracture traces and statistics. More than 3,000 picks of boundaries and fractures were found in a 3,300 ft horizontal length. Those divided into 6 different categories (Bed Boundary, Conductive Fracture, Discontinuous Conductive Fracture, Resistive Fracture, Litho-Bound Fracture, and Vugular fracture). Using high-definition imaging-while-drilling service provides supreme logging-while-drilling (LWD) imaging for reservoir description, from structural modeling, sedimentology analysis, image-based porosity determination and thin-bed analysis. The presence of heterogeneity in carbonates poses a challenge for the characterization of such rocks. The identification of textural variations advanced techniques in borehole image analysis have been applied and presented good results that determine secondary porosity and litho-facies, and, moreover, delivered new insight into previously established interpretations of the reservoir. The data comparison and validation to other measurement show a significant relationship to bring the value even beyond. By using an automatic inversion, the geological interpretation can be constantly delivered around the clock with higher consistency with the number of feature variation. It has been demonstrated that with the advanced analysis, microelectrical borehole images can provide quantitative measures of important reservoir parameters. Accuracy and consistency have been greatly improved since the introduction of microelectrical borehole image logging and subsequent automatic interpretation workflows.
- Asia > Middle East (0.46)
- North America > United States (0.28)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Borehole imaging and wellbore seismic (1.00)
Abstract Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS) measurements are technologies which are adding some benefits in the aim to replace or complete traditional logging measurements like noise logging tools (NLT) or production logging tools (PLT). The aim of well integrity interventions using distributed fiber optic sensing (DFOS) is to significantly reduce the duration and the cost of these operations, and to provide additional information in comparison to traditional logging tool. The combination of DAS and DTS can offer both qualitative and quantitative information regarding fluid dynamics in the context of well integrity investigation, as the flow characteristics (intensity of turbulences). In this study, we will investigate different failure patterns occurring on the well completion, as the production tubing or packers. On the first hand, we will see that the combination of DAS and DTS provides complementary information regarding leaks characterization. On the other hand, we will investigate the monitoring of temperature gradient (DTGS for Distributed Temperature Gradient Sensing) using DAS by the integration of low frequency acoustic signal (< 1 Hz).
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Passive Seismic Surveying (0.49)
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Information Technology > Sensing and Signal Processing (0.75)
- Information Technology > Communications > Networks > Sensor Networks (0.75)