bp short stories - alrdc · feb. 28 - mar. 2, 2005 2005 gas well de-liquification workshop denver,...

Gas Well De-Liquification WorkshopDenver, Colorado

February 28 - March 2, 2005

Deliquification Short StoriesGordon Gates – Deliquification Specialist Bp – HoustonAssisted By: Danny Patterson, Jess Babbitt, Tony Lott

Feb. 28 - Mar. 2, 2005 2005 Gas Well De-Liquification Workshop Denver, Colorado

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


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?


4

Typical IPR Curve for a Gas Well

050

100150200250300350400

0

Flow

ing

Pres

sure

, psi

a

Normal Flow

Choke back to increase BHP

Does everyone agree with this?

Then why do some people choke back wells?

50 100 150 200 250 300Rate, mcfd


5

Shot Gun Duals have Cement Bond Problems on the 2 7/8

Communication because of poor Cement Bonding


6

Results of Holding back pressure on Tubing

Well is graveyard dead at the age of 500 MCFD


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


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?


9

Video of Multi Stage Plunger


10

Soape 9 Results

Installed Multi Stage Plunger

Changed bottom Plunger from bar to Pad


11

CGU – 9-5

Installed Multi Stage Plunger


12

Glaspie 4 Flowing up Casing and Tubing

4 PSIG

Old EOT @ 6141

Perfs @ 6157 6197

Perfs @ 6240 - 6248

5.5” Casing

2.375’ Tubing

105 PSIG SIBP

4 PSIG Line Pressure

6 Bbls Condensate /MMCF

2 Bbls H2O/MMCF


13

Using tools to understand options

Casing & Tubing Flow

Casing Flow Only


14

Glaspie 4 flowing up Tubing


Old EOT @ 6141

Perfs @ 6157 6197

Perfs @ 6240 - 6248

5.5” Casing

2.375’ Tubing

105 PSIG SIBP



2 Bbls H2O/MMCF

New EOT @ 6190

74 PSIG Casing


15

Using ProdOp to understand your well


16

Glaspie 4 after injecting gas in the tubing

Old EOT @ 6141

Perfs @ 6157 6197

Perfs @ 6240 - 6248

5.5” Casing

2.375’ Tubing

105 PSIG SIBP



2 Bbls H2O/MMCF

New EOT @ 6190

Total Gas Out 1260 MCFD @

29 PSIG

Question:

What is FBHP?

Inject 380 MCFD @ 77 PSIG


17

After gas lift---Net gas today 880 MCF


18

What type of gas should you expect if you lower line pressure from 100# to 30#

1966 1970 1974 1978 1982 1986 1990 1994 1998 2002 200610

100

1,000

10,000PET SUD;S H COX 002

Time

Oil Production (bbl)

Gas Production (mcf)

Water Production (bbl)

170310019500005,408,845 mcfSLIGO


19

This is what happens when you lower line pressure


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


21

What is this well capable of?


22

What are the issues?

• It had 2.375 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


23

Results after optimizing facilities


24

www.texjetpump.com


25

Tex Jet Pump

Gas entry point from annuls


26

End View


27

Brown 2 with Tex-Jet

Tex-Jet Installed


28

Vortex Flow


29

Wireline Set Tool


30

www.vortexflowllc.com

Vortex tool installed


31

Vortex installed


32

Vortex installed (SOAP)


33

This tight gas well makes less than 10 Bbls a day into 650 Psig with 2.375 tubing at 8000’. Can we run a plunger on this well?


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#


35

Nipple Failure between valves


36

Pacemaker with Hydrate


37

Pacemakers in 600 PSIG line press.

Two Piece Installed


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 2.375 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


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

bp short stories - alrdc · feb. 28 - mar. 2, 2005 2005 gas well de-liquification workshop denver,...

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