CT Reverse Circulating - Basics

Transcription

1 CT Reverse Circulating - Basics Reverse circulating with aqueous fluid to unload frac sand from large wellbores If sufficient annular velocities are possible with normal circulation, usually don t use reverse circulating. Hydraulics for lift are the critical issue Low shear support fluids 2.5 to 3.5 ppb biopolymer Ability to quickly shift from reverse to normal circulation Hydrocarbons are never intentionally reversed up the coil extreme care is required. Data from Alaska and North Sea Sources Charlie Michel, Rodney Stephens, Walter Crow. 3/14/2009 1

2 Normal Path Circulation Rate and ability to lift depends on CT capacity. 3/14/2009 2

3 Solids Transport in Annuli (Conventional Jetting) Difficult to unload sand from 7 casing even with 1-3/4 CT Very difficult over 20 o deviation and Boycott setting range of 30 to 60 o is most difficult. Low reservoir pressure and dense particles (bauxite and BaSO 4 ) are an added problem. Example Well North Sea 60 o deviation, 9-5/8 casing and 3-1/2 tailpipe, very low pressure well how to unload several meters of fill???? 3/14/2009 3

4 1.5 bpm 1.5 bpm Reverse Circulating Above the reservoir with no losses. 3/14/2009 4

5 3/14/2009 5

6 Reverse Circulating Above Reservoir (no losses) 4800 psi PRV 1.5 bpm 1.5 bpm 1.5 bpm 10 psi 1500 psi 2200 psi PRVs 10 psi 1500 psi 1.5 bpm Disposal 3/14/2009 6

7 Reverse Circulating 2 bpm losses 4800 psi PRV 3.5 bpm 3.5 bpm 1.5 bpm 10 psi 1500 psi 2200 psi PRVs 2.0 bpm 10 psi 1500 psi 1.5 bpm Disposal 3/14/2009 7

8 Reverse Circulating 10 bpm losses 4800 psi PRV 11.5 bpm 10 psi 1500 psi 2200 psi PRVs 11.5 bpm 1.5 bpm 10 psi 1500 psi 10 bpm 1.5 bpm Disposal 3/14/2009 8

9 Jetting Bridge 4800 psi PRV 2.5 bpm 2.5 bpm 2.5 bpm 4000 psi 4000 psi 2200 psi PRVs 10 psi 10 psi 2.5 bpm Disposal 3/14/2009 9

10 Baker Oil Tools Reversing/Jetting Nozzle 3/14/

11 Nozzle converts from a single large port for reversing to multiple ports for normal jetting. Clear string before switch from reverse to normal jetting (prevents erosion of the ports). 3/14/

12 RC&J Tool Captured Ball Concept 3/14/

13 Barriers Two Barriers Required: Mechanical Stuffing box Contingent BOP (CT BOP and/or Drilling BOP depends on set-up) Others? Circulating fluid (kill weight?) 3/14/

14 Risks Elimination of the CT flapper valve small risk, still two barriers Sticking the coil reduced because of higher velocities around solids and clean fluid in the annulus. Bridging in the coil just not seen - minimized by: Control rate of bridge entry - control of particles entering the coil Control of type of particles that are reversed High velocities in the coil Fluid with high support at low shear Can quickly move from reverse to forward circulation 3/14/

15 Coil Collapse Risks Coil far weaker under collapse than burst. Precautions and relief considerations needed to keep outside pressure minimized. Consider increasing pickup weight on the coil (weight of solids) Collapse is function of OD, ID, material strength, ovality, pickup loads (weights and frictions), buoyancy, coil condition, rate of load increase, etc. The collapse tables are for round pipe, not oval CT 3/14/

16 Typical fluid density increase with sand at 1 lb/gal is about 9%. Sand is 6% of coil volume at 1 lb/gal. At 10,000 ft, weight difference between 0.43 and 0.47 psi/ft (1 lb sand) is 0.77 lb/gal or extra 500 lb 3/14/

17 Higher Risks (Poor Candidates) Multi-zone oil wells with cross flow Wells not killed by column of water Wells that produce but cannot inject Deep or bad dog leg wells where pick-up near the max allowable for the coil. HPHT wells no experience. 3/14/

18 Coil Requirements Less than than 40% fatigue wear. Less than 4% oval. No corrosion, pits, welds or damage. Pressure relief valves on backside to prevent coil collapse. No more than 10% (volume of coil) solids in the coil at any time. Model the job. 3/14/

19 Formation/Well Requirements All hydrocarbons push out of pipe (3x pipe volume) All zones kept overbalanced. Contingency plans for well flow. Consider type, shape, density and size of solids lifted. 3/14/

20 Selection of Equipment CT largest possible with > ½ clearance between CT and tubing. Large OD nozzle helps prevent bypassing solids in deviated wells. Single large hole in nozzle for reversing (hole smaller than minimum anywhere else in the system). Where frac sand is only fill, nozzle design is simple. No sharp shoulders on tool oval shape preferred. Venturi junk baskets for large pieces. 3/14/

21 CT Reverse Circulating Conclusions 1. Must have pressure differentials and hydraulics under control. 2. Frac sand removal is most common target, but other materials are possible with the right equipment. 3. Circulating fluid must have low shear support. 4. Must limit the amount of sand in the coil at any time. 3/14/