Preparations Underway for Production Test at Cambay-77H Well in Gujarat

Oilex Ltd disclosed Monday that Cambay-77H well in Cambay Production Sharing Contract in Cambay Basin, Gujarat, India continues to recover water, light oil and gas on a steady flowing tubing head pressure (FTHP) of around 220 psi on a 24/64th inch choke. The relatively steady FTHP is interpreted to indicate that the well has reached its long term stable production curve. Subsequent to completion of all coiled tubing (CT) operations, Oilex now estimates that around 5,400 barrels of Operations (CT and Frac) water remains in the well and continues to be recovered at surface.

Analysis of flowback data for around 85 days has been completed by RISC, a specialist oil & gas consulting company, with reservoir engineering personnel experienced in the Canadian Montney tight/shale gas play. The Montney Formation is a major productive unit and possible analogue for the Y Zone reservoir of the Cambay Field due to its hybrid siltstone and shale content.

Cambay-77H is a proof of concept well with a very short horizontal lateral (1,148 feet or 350 meters) having 8 fracs in 4 stages. Typical North American wells can have 3,281-4,921 feet (1,000-1,500 meters) laterals with 20 to 30 or more fracture treatments. As Cambay-77H is the first well of this type in India and no formation water has been recovered to date, the duration required to complete flow back operations is not known as there is no other reference for this reservoir.

Given the strong gas demand in India, the Cambay JV is currently investigating the opportunity to sell gas concurrently with the ongoing water recovery operations after completion of the production test. Gas production commenced immediately after opening the well to start flowback and Oilex proposes to include gas sales as part of flowback operations in future wells to capture early revenue in a manner similar to North American operations.

Key observations from the RISC analysis are:

  1. Cambay-77H is likely to flow at around 0.5-1 million standard cubic feet per day (MMscf/d) with associated hydrocarbon liquids for a sustained period of time during the stable production phase in the absence of vertical flow performance issues related to higher hydrocarbon liquid to gas ratio (LGR) and water recovery
  2. The 4.5 inch production casing, designed for a LGR of 40 barrels/MMscf appears to be oversized for a well flowing reservoir fluids currently interpreted to have an LGR of around 100 barrels/MMscf as was observed for most of the flowback period, 250 percent higher than the original design
  3. Numerical modelling of Cambay-77H, using the Oilex reservoir parameters indicates possible competition between the fractures. If confirmed by ongoing analysis of production and test data, future wells with longer horizontals could be designed using increased fracture spacing leading to significant cost savings

Given the duration of flowback, Oilex requested RISC to consider the feasibility of production testing the well prior to complete recovery of the Operations water. Based upon the analysis of the flowback data, RISC has designed a production test that should achieve the technical objectives of a longer test.

Field preparation for this testing procedure has started and the test duration is expected to be around 30 days. Due to ongoing recovery of Operations water and the number of flowback days, the upcoming production test is not designed to assess the maximum deliverability from Cambay-77H. The test incorporates downhole instrumentation designed to provide data which allows a more accurate prediction of future performance and crucial information for planning the next drilling campaign, without waiting for the recovered water to be less than 10 percent of the total well flow.


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