Facilities Design Shift Horizontal Equipment in Oklahoma Scott King

Facilities Review in Oklahoma

•  Identified areas for improvement –  Design criteria is outdated for play types –  Vertical separation, cannot sustain a varied, nimble, and adaptable

process flow –  Criteria for justifying vertical equipment

•  What are we going to solve? –  Liquids rich plays demand alternative solutions

•  Do we need to change?

2

Current Design: Vertical Separation

•  Most commonly used in mid-continent

•  Historically relevant in Mid Continent due to gas plays

•  Footprint was of design importance •  Readily available with fabricators •  Sub-optimal with higher liquid

volumes

3

Change in Design

•  Horizontal Heater Treater –  Heating element in oil

phase –  Efficient emulsion control

•  Horizontal Separation –  Increase liquid handling –  Efficient and longer retention time –  Sufficient gas handling with pressure

control –  With proper controls and operation,

rental flowback equipment can be minimalized

–  Reduced separator sizing

4

Basic Horizontal Separator

Design Criteria •  Flowback Elimination •  500 PSIG MAWP •  Mechanical Dumps •  Sand Pan •  Multiple Solid Drains •  Clean Out Ports •  Weir (18” height) •  Direct inlet

5

Basic Horizontal Heater Treater

Design Criteria •  Mechanical Dump •  No adjustable water leg •  125 PSIG MAWP •  Multi-stage separation

capabilities •  Additional oil residence time •  Sales/Tank/VRU gas flow •  Volume specific

6

Flowback System – Engineered

Design Ideals •  Minimal fittings and

elevation changes downstream of choke

•  Utilize swab choke for repairs

•  Minimal rental iron

7

Equipment Layout

Perpendicular Layout •  Simplified piping •  Spacing requirements •  Construction Efficiencies

in cost and time

50ft.

65ft.

Meters

10ft.

7ft.

8

Change in Construction

•  Horizontal Process Equipment –  Larger footprint –  All devices at ground level –  Spacing still important –  Need at least 15 psig to push fluids to storage –  Develop strategies of equipment placement

•  Parallel or Perpendicular

9

Change in Flowback

•  Chokes at equipment •  30 days of flowback rental equipment

–  Only utilize plug catcher, sand separator, frac tank, and minimal piping •  Multiple flow regimes through process equipment

–  Frac tank hookup in swab line –  Ability to move all flow through either swab choke

10

Full Process Flow Diagram (PFD)

3"  Sch.  160Welded  Flowline

Buried

2"  Sch.  402"  Sch

.  40

2"  Sch.  40

1"  Sch.  40

Kimray  330  SGT-­‐BP  3"  BPV

4"  Sch.  40

¼”  NPT  Piping

To  Heat  Trace

To  SSV

To  Flare  Supply

500  BBLOil  Tank

500  BBLOil  Tank

Vent

Kimray212  SGT-­‐BP

500  BBLWater  Tank

Recirc  lineFitting

Recirc  lineFit ting

1"  PSV125  PSIG

Blowdown

To  VRU  Supply

3"  Sch.  40MRO  Chk  Meter  Skid

Custody  Transfer

2"  Sch.  40

2"  Sch.  40

1"  Sch.  40

1"  Sch.  40

2"  Sch.  40

To  Heater  Treater  Scrubber

To  VRT  or  Tanks

From  Heater  Treater  /  VRT

From  Supply  Dump

8  oz./-­‐0.4  oz. 8  oz./-­‐0.4  oz. 8  oz./-­‐0.4  oz.

4"  Pressure  (6  oz.)  /Vacuum  Relief  (-­‐0.4  oz)  

Valve  (Enardo)

2"  Sch.  40

From  Compressor  

Dump

 

From  VRU  Compressor  

Dump

SSV1-­‐13/16"  

10,000  PSIG

3/8"  SSTubing

To  VRTFrom  VRT

Midstream  Meter  Skid

From  VRU

Rev.  0:  Create  PFD  

Horizontal  EQ  (Flowback)Initial  Process  Flow  Diagram  (PFD)

2"  Sch.  40

3/8"  SSTubing To  LPS  Oil  Dump

To  Compressor From  Compressor

From  Flare  Dump

To  Flare

2"  Sch.  40 2"  Sch.  40 2"  Sch.  40

2"  Sch.  40

2"  Sch.  40

3"  Sch.  40FlowbackChoke

SwabChoke

Frac  TankFi tting

KimrayCBA  250  SOA

3"  PSV250  PSIG

Kimray  850  HUTA

KimrayCBA  250  SOA

Which  Valve?

KimrayCBA  250  SOA

Kimray  850  HUTA

KimrayCBA  250  SOA

48"x20'

125  MD  (H)HT

From  Supply

Drain

2"  PSV125  PSIG

Blowdown

Make  4"  Sch.  40  for  H2s  Treating?

Move  scrubber  here  to  take  advantage  of  pressure  drop,  cool  gas,  and  possibly  

remove  excess  chemical?Straddle  BPV?

Install  a  “P”  Trap?

36"x10'

500  MD  (H)LPS

Can  run  line  to  sales  with  BPV  set  to  open  to  tanks  /  VRT  @  100  psig

• Inlets  and  gas  outlets  are  planned  to  be  4"  threaded  couplings• Liquid  dumps/drains  are  2"  threaded  couplings• Dump  controllers  are  planned  to  be  mechanical• Heater  treater  will  be  125  psig  to  possibly  sell  gas  if  line  pressure  is  low  enough• Move  fuel  scrubber  to  downstream  of  BPV?  Or  straddle  BPV  with  two  1"  fittings• Flow-­‐back  operations:  Utilize  flow-­‐back  choke,  divert  through  swab  choke  to  

repair  flow-­‐back  choke,  routinely  drain  LPS.• 4"  or  6"  Clean  out  flanges  will  be  placed  in  LPS  to  assist  in  cleaning  potential  solids  

from  separator.

Clean  out  flange

“P”  trap  with  BPV  StraddleIf  LP  is  low,  can  take  gas  from  upstream  

of  BPV

11

Initial Layout and Piping

12

Flowback - Current Set Up

•  Equipment Requirements –  (1) 2" Double Buster Flowback Tank –  (245') 2" 1502 Piping –  (27) 2" Plug Valves –  (2) 15K Choke Manifolds –  (65) Hobbles –  (30’) 3" 1502 Piping –  (1) 3" Double Plug Catcher w/ screen

(15K; ¼” holes) –  (1) Safety Valve –  (1) 1440 PSGI 3-Phase Test

Separator

13

 

1440  PSIG  Test  Separator

Plug  Catcher

Choke  Manifold  1

Choke  Manifold  2

Sand  Separator  Hookups

2"  Double  BusterFlowback  Tank

GB GB

Flowback  Setup  (A)

Safety  Valve

3"  15022"  1502MRO  Owned

Piping  Legend

Spill  Mats  (Separate  Bid)

Flowback - New Set Up

•  Equipment Requirements –  (50') 2" 1502 Piping –  (12) 2" Plug Valves –  (50) Hobbles –  (30’) 3" 1502 Piping –  (1) 3" Double Plug Catcher w/ screen

(15K; ¼” holes) –  (2) 3" Gate or Plug Valves –  (1) 2” Double Buster Flowback Tank

14

 

Plug  Catcher

3"  15022"  1502MRO  Owned

Piping  Legend

Plumb  to  Swab  Line

Swab  Choke

Flowback  Choke

500  psig  MD  Horizontal  Sep.

3"  Sch.  160 2"  Sch.  40

Plumb  to  Frac  Tank

2"  Double  BusterFlowback  Tank

Questions

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