Bhardwaj, Charu (Cairn Oil & Gas, Vedanta Limited) | Ranjan, Vishal (Cairn Oil & Gas, Vedanta Limited) | Jetley, Shailendra Kumar (Cairn Oil & Gas, Vedanta Limited) | Tiwari, Shobhit (Cairn Oil & Gas, Vedanta Limited) | Ghosh, Anirban (Cairn Oil & Gas, Vedanta Limited) | Sharma, Swapnil (Cairn Oil & Gas, Vedanta Limited) | Bohra, Avinash (Cairn Oil & Gas, Vedanta Limited) | Kumar, Abhishek (Cairn Oil & Gas, Vedanta Limited) | Beohar, Abhudai (Cairn Oil & Gas, Vedanta Limited) | Sharma, Sidharth (Cairn Oil & Gas, Vedanta Limited)
The Raageshwari Deep Gas (RDG) field, situated within Barmer Basin in the State of Rajasthan, India, was discovered in 2003. The field is a tight gas condensate reservoir, with excellent gas quality of approximately 80% methane, low CO2 and no H2S. Since the permeability (0.01 - 1 md) is low in this reservoir, hydraulic fracturing is required to get substantial recovery from the wells. The field has been under production since 2010. The development of this field has been carried out in three phases and more than 150 fracturing treatments have been pumped in this reservoir till date to achieve sustained economical production. This paper deals with the lessons learnt and changes implemented in choke design through various development phases of the field.
In the initial phase of field development, chokes with a low Flow Coefficient (Cv) were installed to meet the requirement of controlling the wells at low flow rates and high differential pressure. Later as the surface handling capacity increased, the chokes had to be de-bottlenecked, requiring additional Capex for new chokes. To avoid a similar scenario in the future, a comprehensive approach has been followed to envisage Cv requirement, considering well wise production profiles and surface handling capacities throughout the life of field. Since a single trim can't operate over the complete life-cycle of a well, trim interchangeability has been included in the choke design such that low and high Cv trims are interchangeable.
Pre-mature failures of trims were observed in initial phase and a root cause analysis was done to ascertain the reason. Based on the analysis, trim metallurgy has been changed from Tungsten Carbide to ASTM A276 Specific Stainless Steel Grade 440C. Trims with newly selected mettalurgy have been installed in the existing chokes.
The introduction of trim interchangeability has saved MMUSD 0.3 in the future Opex as the requirement of procuring altogether new chokes for late life period of wells is avoided. Initially failures in the trim bodies were observed as early as two months of commissioning but with the change in metallurgy zero failures have been observed with operational life of chokes being higher than four years. This has avoided significant downtime on wells and expenditure on regular trim changeovers.
Although Tungsten Carbide is one of the most common materials used for constructing trims world over, there could be specific cases where-in other metallurgy may add better value. The workflow followed in this paper will help select a suitable metallurgy and can impart a significant value to the industry.
Bhardwaj, Charu (Cairn Oil & Gas, a vertical of Vedanta Limited) | Ranjan, Vishal (Cairn Oil & Gas, a vertical of Vedanta Limited) | Pathak, Shashank (Cairn Oil & Gas, a vertical of Vedanta Limited) | Tiwari, Shobhit (Cairn Oil & Gas, a vertical of Vedanta Limited) | Tripathi, Archit (Cairn Oil & Gas, a vertical of Vedanta Limited) | Beohar, Abhudai (Cairn Oil & Gas, a vertical of Vedanta Limited)
Raageshwari Deep Gas field situated in southern Barmer Basin of India is a retrograde gas condensate volcanic reservoir. More than 150 fracturing treatments have been pumped in this reservoir to achieve sustained economical production. The paper describes the results of a statistical analysis done to find correlations between production data and fracturing design parameters including petrophysical and geo-mechanical properties of the rock, pre-frac diagnostic tests, and fracturing treatment data including both pumping data and pressure matched parameters.
This paper uses the data from multiple production logs to generate stage wise Productivity Index (PI). This PI data was then cross plotted against various parameters and combinations of parameters such as In-situ proppant concentration, formation porosity, net pay, average stress, proppant mass pumped per stage, fracturing fluid recovery rate and percentage, and fracture dimensions. One interesting line of investigation looked at the rate of pressure decline post Step Rate Test (SRT). A method was developed to evaluate the SRT declines even though they were too short to analyze for permeability using post closure analysis.
This paper presents the results of these statistical analysis and where reasonable correlations were obtained. It also shows that for this volcanic formation, the rate of pressure decline after the SRT is a better indicator of Reservoir Quality (RQ) and future stage performance than the log derived porosity and permeability. While the use of short term fall-off data is only qualitative, it does appear to be an effective tool for evaluating the potential of a stage just before fracturing which would allow improved onsite treatment optimization.
Since the quality of a reservoir generally varies across the areal extent of a field, it is very important to ascertain the same either qualitatively or quantitatively. This paper presents a technique for qualitatively defining RQ, which can be useful to validate the pre-existing workflows used for defining RQ.
Bhardwaj, Charu (Cairn, Oil & Gas Vertical of Vedanta Limited) | Godiyal, Preeti (Cairn, Oil & Gas Vertical of Vedanta Limited) | Mathur, Mohit (Cairn, Oil & Gas Vertical of Vedanta Limited) | Ranjan, Amit (Cairn, Oil & Gas Vertical of Vedanta Limited) | Verma, Saurabh K. (Cairn, Oil & Gas Vertical of Vedanta Limited)
The Raageshwari field is situated within the RJ-ON-90/1 Contract Area. Of the seven producers which have been completed, six flow naturally and one is on artificial lift. A network model was created to verify the maximum producing potential of the field as well as identify any bottlenecks in the system. The model could then be used to evaluate de-bottlenecking options before going into full field implementation. The production potential of each well was categorized into three parameters: Reservoir Maximum Production Potential (RMPP) i.e. the maximum theoretical production that the reservoir can deliver at the sand-face, Well Maximum Production Potential (WMPP) i.e. the maximum production that well can deliver from sand-face to choke valve, and Plant Maximum Production Potential (PMPP) i.e. the maximum production that the surface facilities downstream of choke valve can handle.