Deliquification Short Stories

Transcription

1 Gas Well De-Liquification Workshop February 28 - March 2, 2005 Deliquification Short Stories Gordon Gates Deliquification Specialist Bp Houston Assisted By: Danny Patterson, Jess Babbitt, Tony Lott

2 Does a well load up while Shut In? Not usually There are exceptions to most statements Don t base most of your decisions on exceptions I have seen it with cross flow. 700# zone co-mingled with 110# shallow zone. This particular plunger well takes about 90 minutes of shut in time to load up 2

3 The Myth of Choking Gas Wells to Keep them producing How many people have heard that you have to hold back pressure on a well to keep it producing? How many agree with that conclusion? If you agree would you hold it on all gas wells? How many of you agree with IPR curves? 3

4 Typical IPR Curve for a Gas Well Normal Flow Flowing Pressure, psia Choke back to increase BHP Does everyone agree with this? Then why do some people choke back wells? Rate, mcfd 4

5 Shot Gun Duals have Cement Bond Problems on the 2 7/8 Communication because of poor Cement Bonding 5

6 Results of Holding back pressure on Tubing Well is graveyard dead at the age of 500 MCFD 6

7 MULTI-STAGER TOOL The Multi-Stager creates bottom hole pressure by staging the well, moving part of your energy source under each stage By staging the well with the Multi-Stager tool you lift the fluid load to a shallower depth I like to call it an elevator 7

8 MULTI-STAGER TOOL CANDIDATES The Multi-Stager has been used in many different well configurations Packer Wells Slim hole Conventional Liner Wells Open Hole Tapered Strings Could it be used in offshore wells with SSSV? 8

9 Video of Multi Stage Plunger 9

10 oape 9 Results Installed Multi Stage Plunger Changed bottom Plunger from bar to Pad 10

11 CGU 9-5 Installed Multi Stage Plunger 11

12 laspie 4 Flowing up Casing and Tubing 4 PSIG 5.5 Casing Tubing 105 PSIG SIBP 4 PSIG Line Pressure 6 Bbls Condensate /MMCF 2 Bbls H2O/MMCF Old

13 Using tools to understand options Casing & Tubing Flow Casing Flow Only 13

14 Glaspie 4 flowing up Tubing 4 PSIG Line Pressure 5.5 Casing Tubing 105 PSIG SIBP 4 PSIG Line Pressure 6 Bbls Condensate /MMCF 2 Bbls H2O/MMCF 74 PSIG Casing Old 6141 New

15 Using ProdOp to understand your well 15

16 Glaspie 4 after injecting gas in the tubing Inject PSIG Total Gas Out PSIG 5.5 Casing Tubing 105 PSIG SIBP 4 PSIG Line Pressure 6 Bbls Condensate /MMCF 2 Bbls H2O/MMCF Old 6141 Question: What is FBHP? New

17 After gas lift---net gas today 880 MCF 17

18 What type of gas should you expect if you lower line pressure from 100# to 30# 10,000 PET SUD;S H COX ,408,845 mcf SLIGO 1,000 Gas Production (mcf) 100 Oil Production (bbl) Water Production (bbl) Time 18

19 This is what happens when you lower line pressure 19

20 Why is training and Networking important? You must be able to identify wells that are liquid loaded You must be able to understand why they are loaded Understand tubular limits Pressure limits Rate limits You should understand friction and gravity effects 20

21 What is this well capable of? 21

22 What are the issues? It had tubing 6000 No packer Less that 10 Bbls /MMCF 275# Build up A compressor that would move Maximum 250 MCFD 2 Flow line that would not get the tubing below 90# to tank 22

23 Results after optimizing facilities 23

24 24

25 Tex Jet Pump Gas entry point from annuls 25

26 End View 26

27 Brown 2 with Tex-Jet Tex-Jet Installed 27

28 Vortex Flow 28

29 Wireline Set Tool 29

30 Vortex tool installed 30

31 Vortex installed 31

32 Vortex installed (SOAP) 32

33 This tight gas well makes less than 10 Bbls a day into 650 Psig with tubing at Can we run a plunger on this well? 33

34 Safety was a concern Within Bp over the last 3-4 years we have launched around 10 plungers This was unacceptable from a Safety standpoint If we do not mitigate this hazard Management will not allow us to use plungers to de-liquefy our wells Working with Hydrates seemed to be one of the root causes of failure The prediction was that this was not possible with the high line pressures that exist in Jonah that range from 550# to 750# 34

35 Nipple Failure between valves 35

36 Pacemaker with Hydrate 36

37 Pacemakers in 600 PSIG line press. Two Piece Installed 37

38 Don t wait for a well to load up before you spring into action! Action plan for tight gas wells Drill well, frac and produce up 4.5 Casing Monitor flow rate and snubb tubing in well before you start to load If liquid rate is too large for plunger then inject surfactant, if not Monitor flow and run two piece plunger in well 100 to 200 MCF before loading Monitor well and lower line pressure when needed 38

39 Poor Boy Gas Lift and Plunger Assist As reservoirs declines we are installing more and more wellhead compressors This sometimes gives us options for either kicking off wells or sustaining production Basically we add just enough gas into the casing when there is no packer to get the combined flow above critical or just enough to help get a plunger started 39