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Treasure Island Royalty Trust Message Board

esanto2 6 posts  |  Last Activity: Nov 8, 2014 2:18 PM Member since: Dec 21, 1999
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  • esanto2 esanto2 Nov 8, 2014 2:18 PM Flag


  • esanto2 esanto2 Nov 6, 2014 6:40 PM Flag

    Correct but any success on the SUD would have a huge positive influence on TISDZ

  • esanto2 esanto2 Nov 4, 2014 1:08 AM Flag

    38. Pressure test the CT system to 12,500 psi against the 4¹⁄₁₆” 15K manual valve.
     The CT test pressure of 12,500 psi is 500 psi more than 12,000 psi, 80% of the operational limit for 15K coiled tubing system.
     If surface pressure reaches 7,000 psi, plan to pull CT out of the hole.
     If wellhead pressure reaches 12,000 psi, shear the CT using the 13⅝” 25K BOP blind shear ram. Pick-up the CT and close the 2⁹⁄₁₆” 25K MWV. Then, close the 5⅛” 15K blind/shear rams on the coiled tubing Combi BOP and 5⅛” 15K blind rams on the coiled tubing Quad BOP. Secure the well.
    39. RIH with CT to 27,786’, 100 ft below the bottom perforations, while displacing the well with 14.0 ppg calcium bromide (CaBr2). Circulate bottoms up.
    40. POOH with CT.
    41. If needed, RIH with CT and displace 14.0 ppg CaBr2 from surface to 10,000 ft with nitrogen. POOH with CT.
    42. Close 2⁹⁄₁₆” 25K MWV and 2⁹⁄₁₆” 25K MCV.
    43. Unload and flow test well for 2-3 days. Take fluid and gas samples.
    44. RD 15K CT equipment. RD 13⅝” 25K BOP blind shear ram.
    45. Shut in well and record SITP. Close and test each SCSSV.
    46. RD and offload equipment. Prepare rig for move. Jack down to water and pull legs free. Move rig off location.

    Since they drilled with OBM, there is some #$%$ to clean out. If they had flowed a lot of water, they wouldn't be on the well doing a coiled tubing clean out or nitrogen jetting. It would be a P&A. They have debris to clean out to attempt to flow at commercial rates, which mean they must have something to poke at. They won't give up too quickly, nor should they. CT clean out, n2 lift, maybe another CT clean out with some chemical treatment, maybe one round of addition perfs.

    Maybe you can buy back your GULTU where you sold it? No blood, no foul.

  • esanto2 esanto2 Nov 4, 2014 1:06 AM Flag

    Re: New DJ2 Permit to Modify

    They are still working on cleaning the well for a production flow test.

    10/23/14 - Cetco fine tuning equipment. BSEE arrived on location for inspection and verbal approval to perform well test was granted at 1225 hours 10/23/14. Opened well for test at 1412 hours.
    10/24/14 - Shut well in for build-up. Monitored SITP. Opened well at 0924 hours for test. Shut well in at 1208 hours, monitored SITP. Opened well at 1450 hours for test. Shut well in at 1603 hours. Opened well at 1908 hours for test. Shut well in at 2042 hours. Monitoring SITP.
    10/25/14 - Monitoring SITP. Opened well at 0921 hours and flowed well.

    From their updated procedure posted today, they appear to be somewhere after step 31.

    29. Prepare to test well.
    30. Unload and flow test well for 2-3 days. Take fluid and gas samples.
    31. RU 13⅝” 25K BOP blind shear ram (BSR) on top of the 2⁹⁄₁₆” 25K production tree manual crown valve (MCV). RU wedgelock control system on the 25K BOP.
    32. Pressure test the 13⅝” 25K BOP BSR to 250 psi and 23,100 psi; record time to close the BSR.
    33. RU a 2⁹⁄₁₆” 25K manual working valve (MWV) on top of the 13⅝” 25K BSR. Pressure test the 25K MWV to 250 psi and 23,100 psi against the 2⁹⁄₁₆” 25K production tree MCV.
    34. Using coiled tubing (CT) BOP test stump, pressure test the blind rams of the 5⅛” 15K CT Quad BOP and blind/shear rams of the 5⅛” 15K CT Combi BOP to 12,500 psi for 5 min. Install test bar and pressure test the pipe rams of the 5⅛” 15K CT Quad BOP and slip/pipe rams of the 5⅛” 15K CT Combi BOP to 12,500 psi for 5 min.
    35. RU 4¹⁄₁₆” 15K manual valve on top of the 2⁹⁄₁₆” 25K MWV. On top of the 4¹⁄₁₆” 15K manual valve, nipple up (NU) 5⅛” 15K coiled tubing BOPs, dual 15K strippers, and coiled tubing unit (CTU).
    36. Install 1.75” 0.134” WT coil connector on 1¾” OD CT. Pull the connector to 10,000 lbs, and pressure test to 5,000 psi.
    37. MU CT BHA with nozzle, dual flapper check valve and weight bars.
    38. Pressure test the CT

  • From IV MMR Board;

    BBE Completion/Test

    They are not completing the lower sections (Sparta, Vicksburg) - completing/testing the middle miocene section first:

    "The well is presently Temporarily Plugged and Abandoned. The plan is to complete the well as a gas producer in the Middle Miocene 24,200’ Sand and 24,600’ Sand as follows: Move rig on location and jack up. Install 18¾" 15K BOP stack. Clean out well to 25,600' (top of 6⅝" liner). Polish 6⅝" liner top lower tieback receptacle. Run and cement 9" x 7" tieback casing. Clean out tieback and 6⅝" liner to 32,500'. Spot cement plug at 32,500’ – 32,100’ and set bridge on top at 32,100’. Displace to kill weight completion fluid. Perforate overbalanced using eline perforating guns. Run isolation packer. Run production packer and 3½" production tubing with 3½" 20M SCSSV. Install and land tubing hanger. Install and test 2-9/16" 20K tree. Displace annulus with inhibited 12.5 ppg sodium bromide packer fluid and tubing with 8.9 ppg glycol/water mixture. Set the production packer. Install and test temporary flow line to lift boat with well test equipment. Unload and flow test well for 2-3 days. Close and test SCSSV. Jack down and move rig off location."

  • Reply to

    So, is there any value here?

    by goape4now Oct 24, 2014 8:20 PM
    esanto2 esanto2 Oct 29, 2014 7:11 PM Flag

    This has gone from an investment to a lottery ticket. However it sounds to me that they will be going back to attempt a completion on BBW2 later in the higher section. Any good news from the SUD....including DJ2 currently testing....will give this new life.

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