Fire Ferro cement Weir mesh Flexural strength Erroneous designNow-a-days repair and rehabilitation of the existing structures in developing countries has become solitary of the most thought-provoking tasks in Civil Engineering sector. Imperfections, fiasco and general distress in the structures can be the outcome of fundamental deficiency produced by inaccurate design, poor workmanship or overloading of the construction. It can also be instigated by corrosion, fire and natural calamities. A spoiled or distrait structure can be modernized to an acceptable level of performance at a reasonable cost by different approaches is called retrofitting. One of these techniques consists of strengthening fire damaged concrete beams by applying Ferro cement with wire mesh. Two types of Ferro cement with wire mesh are used with single layer and double layer in beam. One third point load test according to ASTM C78-02 is performed to measure the flexure performance of four specimens. The ultimate load carrying capacity for using the single layer Ferro cement strengthening, double layer Ferro cement strengthening showed an improvement of 46% and 72% respectively over the fire damaged specimens.

Casing degradation evaluation is of prime importance to ensure well integrity system reliability and sustainability. Multi-finger calipers have been around for more than 50 years and are used to assess internal casing damage. In addition, high resolution ultrasonic imaging, introduced relatively recently, determines casing thickness by transmitting pulse-echo waveforms to initiate thickness-mode of the casing through induction of mechanical resonance. A high-profile exploratory gas well was at stake of being compromised due to fishing and cable sticking incidents in the 7-inch section. In this work, a novel combination of multi-finger caliper and ultrasonic imaging is investigated to accurately determine metal loss with assistance of hybrid threedimensional casing morphological visualizations which is then utilized to validate casing derating models and ensure well integrity. In order to evaluate the casing condition, it was decided to run a 24-finger caliper tool and to make up for loss of coverage area, ultrasonic imaging was employed. In order to process caliper data from various fingers, a three-tier process was applied which includes finger calibration, caliper correction due to eccentricity, finger sticking, finger offset, and lastly statistical analysis was conducted to generate corrosion summary report for metal penetration computations. Next, characteristic of the casing resonance was processed to measure thickness and compared with the nominal thickness to determine metal loss percentage. Furthermore, arithmetical analysis of internal casing radius measurements from both the tools was done to ensure data reliability. Ultimately, combining the measurements, 3D descriptions were generated in order to better characterize localized damage. A multi-physics approach led to a comprehensive characterization of in-situ casing condition. Consistency between internal radius measured by the calipers and deduced by pulse- echo arrivals was observed, improving confidence on the end-product. In the 7-inch casing section, a 40-meters interval was identified to have medium intensity grooves where the maximum penetration was computed to be in excess of 20% of the nominal pipe thickness This groove can be associated with tripping in / out operations of drill string or BHA. Also, the log results agree with the relatively higher side forces across this interval due to increased dog-leg-severity. In addition, cyclic response in radius measurements identified another zone where potential casing deformation (ovalization) near the surface was observed. Results of torque and drag simulations and well trajectory parameters were integrated with casing degradation analysis from the logs which assisted in qualifying well barrier status for the casing.

In response to the highly volatile industry situation post-Covid19, E&P companies are abandoning or delaying exploration projects. It is anticipated that to meet growing energy demand in the future, it would require robust reservoir surveillance to improve individual well productivity. Production logging plays a key role in developing reservoir flow characterization and its integration with multiple data sources can allow for a holistic well dynamic description, leading to production enhancement on a well-by-well basis. Multiple case studies are presented in this work that propose a data-driven, integrated workflow which combines production logging data with plethora of under-utilized data sources to constitute an investigative analysis to solve water production conundrum. The workflow developed as part of this work incorporates three distinct stages. Firstly, an in-depth data analysis is conducted utilizing all historical production data/trends and well events to link it with water production as each will have its distinct impact on the type of production logging tools/techniques that would be deployed on the subject well to achieve job objectives. Secondly, real-time production logging is conducted to ensure job objectives as defined in stage one is being met which is crucial to the resultant wellbore zonal profiling. Finally, once the production log visual representation is created, various other open-hole petrophysical and cased-hole well integrity logs are analyzed to make sense of the derived results and suggest reasoning to the state of the reservoir production pertaining to producing water. The case studies discussed in this paper include the use of petrophysical logs, MDT formation testing data, ultrasonic cement evaluation logs, and production log time-lapse analysis. Integrating various data sources with production log analysis allowed for establishment of water production sources in the various case studies discussed. In one case, production related ambiguity was resolved by integrating formation testing and production logging data together. Another analysis revealed channeling behind the casing through a micro-channel in the cement which caused water to encroach shallow perforations. This highlighted the importance of azimuthal cement logging to detect small channels even when omni-directional sonic measurements are depicting good cement placement. Finally, through integrated time-lapse production log analysis, it was discovered how wellbore dynamics were changing chronologically.

Innovation is pivotal for sustainability in today's dynamically changing E&P industry. Global industry downturn and the pandemic has pushed operators towards squeezing expenditures and look for cheaper, but efficient alternatives to maximize production from producing/discovered resources. Carbonate reservoirs provide a unique set of formation and productivity evaluation related challenges due to the highly variable characteristics of the natural fractures. This work elucidates how production logging data, combined with multiple wireline logs, resulted in resolving water production ambiguity in a well drilled into a Naturally Fractured Reservoir (NFR). Value of integrative data analysis to extend production logging diagnostic capability will be the focus of this paper. The well under consideration in this paper is a wildcat well located in a region which involves complex geology and intricate fracture systems. Accordingly, a two-tier methodical approach to characterize formation evaluation and assess well producibility was proposed and implemented through an integrated lens. Firstly, a combination of petrophysical and fracture image logs helped in comprehensive open-hole characterization. Next, to evaluate reservoir deliverability from the fractures, formation testing with 3D Radial probe and then extended well testing operation was performed, which confirmed hydrocarbon presence however, variable Water Gas Ratio (WGR) posed as a challenge, and it became critical to confirm the source of water for deciding future completion strategy. Finally, to solve the produced water conundrum, real-time production logging with integration of all open-hole data and mud log was performed to provide a definitive answer product. Integration of borehole image logs allowed to delineate complex producing zones based on fracture clusters with classification of variable fracture types and linkage with production log zonal contribution profile. Moreover, analyzing mud logs in the same canvas as the production log, led to establishment of linkage between surface water production and drilling fluid losses at specific depths. Ultimately, produced water anomaly at different choke sizes was resolved through real-time production logging optimization which indicated water sump build up downhole due to lack of lifting capacity from nearby perforations at higher choke sizes. Integrating all relevant well data in a single layout including production logging results helped in achieving objectives and understanding well dynamics in context of fracture flow characterization, water production, and diagnostic capabilities.

Well testing is very challenging especially in northern parts of Pakistan, as there are complex lithologies and multiple formations encountered in a single well. These formations include both fractured carbonates and sandstones. In addition, lower matrix porosities make it more difficult and time consuming as it can take several weeks to months to test multiple formations individually using a casedhole drillstem test (DST). These tests impact the overall well cost due to the extended rig time required and production loss. Extended buildups are a huge concern that must be kept in consideration due to the high rig-time requirement. This paper describes the application of a wireline formation tester (WFT) for interval pressure transient testing (IPTT), which is also referred to as a mini-DST, to estimate flow regimes and reservoir properties along with vertical pressure profiling, fluid identification, and sampling. This technique was applied at two of the exploratory wells in TAL block. There, WFT was deployed with a single probe and straddle packers to achieve the desired results across four potential reservoirs. Vertical pressure profiles across the prospective formations were acquired using the single probe; this was followed by a mini-DST using straddle packers to test zone by zone for fluid type, collect samples, and record pressure buildups. Real-time pressure derivatives were monitored to optimize the buildup time at each station depth. This integrated IPTT gave necessary reservoir information in a very short span of time. It saved significant amount of time and costs, especially rig costs and entire well testing cost giving valuable information for completion strategy.