Production Enhancement with Foamer in Wells Producing Above the Critical Rate

Transcription

1 Gas Well Deliquification Workshop Sheraton Hotel, Denver, Colorado February 27 March 2, 2011 Production Enhancement with Foamer in Wells Producing Above the Critical Rate Mark Embrey - Baker Hughes

2 Common Approach to Artificial Lift Don t mess with a well that is flowing fine on its own Wait until the well starts liquid loading before thinking about AL I only get a pat on the back for increasing production nobody notices if I just maintain the production Foamer can only help out wells that are producing below the critical rate

3 Problems with this Thinking Liquid hold up may cause permanent damage to the formation Production is being lost while waiting on artificial lift to be installed Getting the well unloaded and back on production can be very difficult

4 More Logical Approach to AL Install a capillary string before the well starts loading Avoids problems listed previously No extra capital expenditure required Could see an immediate increase in production Corrosion and scale inhibition as a side benefit

5 South TX Case Histories Capillary string installed soon after completion in approximate 25 wells 1/4-625 Inconel tubing Most wells had not yet reached critical rate Injecting foamer, corrosion inhibitor, scale inhibitor combination chemical

6 Well Conditions Horizontal multi stage fractured wells 2 3/8 tubing down to heel 4 ½ liner in horizontal section Surface pressure ranges psi typically Gas wells that produce some water and condensate avg LGR ~ 30 bbls / MMCF

7 Cap String Installed Well 2 Before 580 MCFD After 813 MCFD Time (Days) Gas (MCFD) TP (PSI)

8 Cap String Installed Well 3 Before 250 MCFD After 1465 MCFD Time (Days) Gas (MCFD) TP (PSI)

9 Cap String Well 4 Before 3081 MCFD After 4145 MCFD Time (Days) Gas (MCFD) TP (PSI)

10 Cap String Installed Well 5 Before 3106 MCFD After 3649 MCFD Time (Days) Gas (MCFD) TP (PSI)

11 Cap String Installed Well 6 Before 3190 MCFD After 3673 MCFD Time (Days) Gas (MCFD) TP (PSI)

12 Critical Rate vs Actual Rate WHP (psi) Critical SC (MSCFD) BHP (psi) Critical (MSCFD) Well WHP (psi) Actual Rate Before (MSCFD) Actual Rate After (MSCFD) Total

13 G a s V e l o c i t y [ f t / s ] C o m p a r e V e l o c i t i e s a t t h e C u r r e n t R e s e r v o i r P r o d u c t i o n R a t e M in im u m V e lo c it y G a s - L iq u id M in im u m V e lo c it y F o a m e d 40 C o m p le t io n G a s V e lo c it y M e a s u r e d D e p t h [ f t ] Company-Client: Field-Well: Project Title: New Project Scenario: New Scenario Analysis: Monday, February 07, :53:04 AM File: C:\Program Files\BJ Services\Circa 32\E645251D-CFEE8D6AB33D.tmp

14 Conclusions It appears that foamer can increase production in wells producing above the minimum critical rate The decline curve for the entire field was changed What is the mechanism for this rate increase? Does the potential upsides of installing a cap string early in a wells life out weigh the potential down sides?

15 Questions

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