The information was submitted for publication, through the agency of the contact person set out below, at 21:45 CET on 21 October, 2021. This information is such information that Maha Energy AB (publ) is obliged to make public pursuant to the EU Market Abuse Regulation. Jonas Lindvall continues, “On the other hand the immediate impact of the deferred production is cushioned by the current strong oil market and we still continue to build our cash balance despite the delay of bringing Tie-4 on production.”ġ Barrels of oil equivalent ("BOE") conversion ratio of 6,000 scf: 1 bbl is used. We now aim to have the Tie-4 horizontal on production by the end of the year.” The delay is now significant and will impact our 2021 production guidance. Jonas Lindvall, CEO of Maha Energy AB comments: “The Agua Grande (AG) reservoir was encountered higher than anticipated in the Tie-4 horizontal, which is positive, but whilst pulling out of hole to run production casing, the bottom hole assembly became stuck. The delay in Tie-4 has resulted in the deferral of 171,000 BOE, or 469 BOEPD of production on an annualized basis. The new completion date of Tie-4 is anticipated to be around the end of the year. Stuck pipe in the hole now requires a sidetrack which is being initiated.
#HAMPSON RUSSELL WELL TIE SOFTWARE#
Seismic to Well tie confirm the hydrocarbon Hampson-Russell seismic and well log data processing software was used to generate synthetic seismogram with the use of density and sonic log data. The Tie-4 horizontal well suffered an additional setback whilst getting ready to run production casing. time of 1714 ms and at inline calculated from the well location, the reservoir zone was evaluated and is shown in Fig -2. The average production rate for the third quarter of 2021 was 3,610 BOEPD Production for the year is down 12.5% compared to prior guidance - however offsetting the deferred volumes is a robust oil market that dampens the impact on the estimated revenue for 2021. The 2021 exit rate estimate of 5,000 BOEPD and 5,500 BOEPD remains unchanged provided Tie-4 is hooked up and placed on production before the end of the year. A class III AVO anomaly observed in the soft event above the reservoir may have been the same event analyzed pre-drill if the original 3D data comprised the same effect as observed in the available 2D data.The range for 2021 annual average production is now 3,500 - 4,000 BOEPD 1 In the 2D seismic data, the whole reservoir is represented by one strong reflector probably caused by tuning, that changes appearance at about 2400 m offset. The base has the strongest influence, and the observed spikes do not seem to contribute. The refracted energy is probably set up by siderite cemented zones at top and base of the reservoir. Modeling results show that refracted energy occurs at offsets of about 2500 m – 3000 m. study was a volumetric characterization of Quissamã Formation by means of an adapted classical workflow composed of. The events have been flattened out one by one and in combination. Flow Chart for Hampson-Russell (H-R) Software for Model Based Inversion 27).
The response from the separate events observed in the well logs has been studied by modification of the logs. It was desired to assess the capability of the modeling algorithms and to examine how the response changed by the application of different wavelets and target zones for modeling.
Gathers from NSR09-41155 2D line and a sub-cube of the TO06R06M1 3D cube, which the original interpretation was done on, have been available.Ī separate study on the response of cemented stringers of various thicknesses and numbers was performed. The synthetic gathers have also been compared to real seismic in the area.
Experimental studies on cutting data have been combined with the modeling in order to tie the seismic response to the true geology. The AVO modeling has been performed by use of the Hampson-Russell AVO software and the well data has been received from Lundin Norway AS, operator for the Mon well. In processing, normal moveout (NMO) stretch and the breaking down of the travel time equation at far offsets need to be accounted for. As the offset in the data increases, the seismic signal changes as offset-dependent tuning and refractions may occur. Long offsets is becoming more common as the information obtained at far offset is valuable in the process of quantitative interpretation. The objective of the present work is to obtain an understanding of what the seismic data represents and possibly be able to use this knowledge in future projects. The well was drilled on the Mon prospect in 2009 and encountered water-bearing sandstones in Paleocene Hermod Mbr. Amplitude variation with offset (AVO) modeling has been performed on well logs from exploration well 25/5-6.
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