Over the last few years, different types of bits have been introduced to meet the chal lenges of steerable as well as rotary steerable systems; and it is imperative that bits be utilized optimally in these systems. Aw challenges increase with increasing depths, it becomes even more important for one to efficiently utilize the available energy (Robello, S., 2013, "Modeling and Analysis of Drillstring Vibration in Riserless Environment," ASME J. Energy Res. Technol., 135(1), p. 013101). A new correlation identifying ineffi cient drilling conditions is presented in this paper. Mechanical specific energy (MSE) has been used to improve drilling rates, with mixed results. Hydro MSE (HMSE), which is introduced here, encompasses hydraulic as well as mechanical energy. HMSE quantifies the amount of energy required to drill a unit volume of rock and remove it from under neath the bit. HMSE includes axial, torsional, and hydraulic energy and is different from MSE because it includes a hydraulic term. The initial MSE correlation (Teale, R., 1965, "The Concept of Specific Energy in Rock Drilling," Int. J. Rock Mech. Min. Sci., 2, pp. 57-73.) was modified to accommodate the new hydraulic term. This paper attempts to better model downhole drilling by introducing the hydraulic energy term in the MSE cor relation by defining it as HMSE. While the majority of the drilling occurs because of the bit, it is a well-known fact that some drilling occurs due to the "jet impact impingement" caused by the drilling fluid as well. Experimental and field data presented in this papershow that HMSE can identify inefficient drilling conditions. The new hydraulic term included in the specific energy correlation is the key to correctly match the amount of energy required to drill and overcome the strength and stresses of formation being drilled. Also, this new term illustrates how much hydraulic energy is needed to drill faster when the mechanical energy (axial and torsional) is increased. The results also show the importance of including the bit hydraulic energy term into any specific energy analysis for drilling optimization. Field results reveal specific patterns for inefficient drilling con ditions and also reveal a good correlation between calculated HMSE and the expected requirements for rock removal under existent conditions of stress at the bit face (Mohan,

Over the last few years, different types of bits have been introduced to meet the challenges of steerable as well as rotary steerable systems; and it is imperative that bits be utilized optimally in these systems. As challenges increase with increasing depths, it becomes even more important for one to efficiently utilize the available energy. A new correlation identifying inefficient drilling conditions is presented in this paper. Mechanical Specific Energy (MSE) has been used to improve drilling rates, with mixed results. Hydro Mechanical Drilling Specific Energy (HMSE), which is introduced here, encompasses hydraulic as well as mechanical energy. HMSE quantifies the amount of energy required to drill a unit volume of rock and remove it from underneath the bit. HMSE includes axial, torsional, and hydraulic energy and is different from MSE because it includes a hydraulic term. The initial MSE correlation (Teale, 1964) was modified to accommodate the new hydraulic term. This paper attempts to better model downhole drilling by introducing the hydraulic energy term in the MSE correlation by defining it as hydro mechanical specific energy. While the majority of the drilling occurs because of the bit, it is a well known fact that some drilling occurs due to the "jet impact impingement" caused by the drilling fluid as well.A comprehensive set of equations have also been developed and introduced here for hole opening scenarios. Experimental and field data presented in this paper show that HMSE can identify inefficient drilling conditions. The new hydraulic term included in the specific energy correlation is the key to correctly match the amount of energy required to drill and overcome the strength and stresses of formation being drilled. Also, this new term illustrates how much hydraulic energy is needed to drill faster when the mechanical energy (axial and torsional) is increased. The results also show the importance of including the bit hydraulic energy term into any specific energy analysis for drilling optimization. The pump-off force for weight on the bit due to the fluid force is also included in the calculation. Field results reveal specific patterns for inefficient drilling conditions and also reveal a good correlation between calculated HMSE and the expected requirements for rock removal under existent conditions of stress at the bit face.

This paper discusses the hydraulic fracturing (HF) treatment of a tight gas well owned by a major power service company in India. The objective was to perform a HF treatment on the openhole (OH) section to assess the reservoir potential for future development work. The success of this treatment could unlock the oil and gas reserves in this area of the country, which are estimated to be massive. The fracturing treatment of the tight gas reservoir was to be performed under these conditions for the first time in the area, so there was no previous information to help design the treatment nor predict the result. Injectivity and mini-frac tests were performed to analyze the reservoir properties before designing the final fracturing design and execution. One of the major challenges was to perform the fracturing treatment on an OH section under extremely strenuous operational deadlines, which eliminated the options of using any more suitable well completion methods. Thus, it was proposed to use a diverting agent in the fracturing treatment design to help maximize the stimulated reservoir volume (SRV) in the OH section. The objective was to create at least two to three multiple independent fractures in the OH section. The challenge was to manage the injection rates and deliver the diverter accurately to the bottomhole to create a bridge at the open fracture, isolate it, and initiate a new fracture. This paper discusses this process, and the the lessons learned during the treatment execution. In addition to the description above, the following issues had to be addressed before progressing to the primary fracturing treatment: heavy mud was in the wellbore and OH section, this was a low-permeability reservoir, operator's Christmas tree pressure rating was low, this was a deep well with a long OH interval, there was an extremely short operational execution deadline, and this well's close proximity to an adjacent well, leading to possible communication between the wells. This paper discusses the fracturing analyses performed to design the fracturing treatment, the ideologies used for performing the successful fracturing treatment using diverter technology, and the results achieved using this technique.

In 2009, a service company performed its first hydraulic fracturing treatment using a conventional hydraulic-fracturing technique in coalbed methane (CBM) wells in India. As progress was made, the potential for performing an extensive number of hydraulic-fracturing treatments in CBM wells was observed. From an operational standpoint, the advantages of recovering CBM wells are that they have more target coal seams at shallower depths that are candidates for stimulation, and the size of the treatments makes them ideal for multiple applications in a shorter period of time, reducing nonproductive time (NPT) for the operating company (Seldle and Arri 1990). The service company introduced a unique fracturing service that integrated two components—coiled-tubing (CT) deployed hydrajet perforating and then immediately performing hydraulic fracturing. By combining these two processes into one continuous service operation it eliminates the use of wireline for perforating and plug setting, making the new multistage technology economical for CBM wells. For the first time in India, this CT perforating/fracturing service was introduced to a CBM well operator. The observations and knowledge gained from the fracturing-service operations in India are discussed in this paper. This process employed hydrajetting technology through CT using a hydrajetting tool in the bottomhole assembly (BHA). Based on the casing specifications, cementing conditions, rock properties, and experience gained with each perforating experience, the jetting flow rates, differential pressures, and casing annulus backpressure requirements were optimized. This increased the life of the tool and improved the overall operations. The hydrajetting tool life was increased from 6 to 8 perforation sets to about 19 to 21 per tool, improving the operational efficiency. The advantages of jetting acid into the created perforations, pressure squeezing with acid, and using the many services of CT are examined. In addition, the BHA is also discussed. In some of the frac stages, the treatment screened out and experienced high concentrations of sand in the wellbore; therefore, the steps taken to help prevent sanding off the tool or getting the CT stuck are reviewed. Sand concentrations of 12 lbm/gal. were achieved for extended periods of time to pack the formations off. The need for using wellbore sand plugs was eliminated for many frac stages in these wells as a result of successfully packing the proppant into the fractures with higher sand concentrations. This helped eliminate concerns of losing fluid and sand into previous fractures when performing new frac stages uphole. As more treatments were executed and experience was gained, fluid usage was optimized and the fluid consumption was reduced by approximately 30 to 40%, providing further value to the operator. Finally, the lessons learned from a project- management viewpoint are also examined, discussing streamlining operations based on the various field and reservoir conditions experienced in India. The knowledge gained from this project could be directly applicable to the fracturing-service operations in other regions with CBM wells. The operational learnings during the course of this project could also serve as a guide to operations in this region where similar challenges are encountered.

Background: Rhesus incompatibility is a preventable cause for severe neonatal hyperbilirubinemia, hydrops fetalis and still births. The prevalence of the Rh-negative blood group among Indian woman varies from 2% -10%. Despite declining the incidence of Rhesus incompatibility, due to availability of anti-D immunoglobulin, and improved antenatal care of the Rh-negative pregnant woman, it still accounts for a significant proportion of neonatal hyperbilirubinemia and neuro-morbidity. The prevalence of Rh-negative women having Rh-positive neonates is 60%. Objectives: This study aimed to estimate the incidence of Rh iso-immunization and evaluate the outcomes of Rh iso-immunized neonates. Methods: This prospective observational study was conducted in a tertiary level neonatal intensive care unit, Princess Esra hospital, Deccan college of medical sciences, Hyderabad, Telangana, India. Consecutive intramural and extramural neonates admitted to neonatal intensive care unit with the Rh-negative mother's blood group and hyperbilirubinemia were enrolled. Neonates born to Rh+ve mothers were excluded. Neonatal gestational age, birth weight, age at admission, duration of phototherapy, duration of hospitalization, neonatal examination and investigations were recorded in a predesigned, pretested performa. Results: A total of 90 neonates were born to Rh-negative mothers, of which 70% (63) had the Rh-positive blood group and 30% had the Rh-negative blood group. Of these 63 neonates, 48 (76.2%) had hyperbilirubinemia and 43 neonates (68.3%) had significant hyperbilirubinemia (total serum bilirubin > 15mg/dL). Among them, 2%, 75% and 23% were born to primi, multi and grandmutli, respectively. Also, 14.5% of the neonates were large for dates (LFD), 75% appropriate for dates (AFD) and 10.5% were small for dates (SFD). Premature and SFD neonates had higher incidence of hyperbilirubinemia. Significantly higher incidence of jaundice occurred