Facilities Design Shift Horizontal Equipment in Oklahoma Scott King

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Facilities Review in Oklahoma Identified areas for improvement Design criteria is outdated for play types Vertical separation, cannot sustain a varied, nimble, and adaptable process flow Criteria for justifying vertical equipment What are we going to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 midcontinent 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 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 Horizontal Heater Treater Heating element in oil phase Efficient emulsion control 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 10ft. 7ft. 50ft. 65ft. Perpendicular Layout Simplified piping Spacing requirements Construction Efficiencies in cost and time Meters 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

Fra c T ank Fi tting Full Process Flow Diagram (PFD) Horizontal EQ (Flowback) Initial Process Flow Diagram (PFD) Move scrubber here to take advantage of pressure drop, cool gas, and possibly remove excess chemical? Straddle BPV? Install a P Trap? P trap with BPV Straddle If LP is low, can take gas from upstream of BPV 3/8" SS Tubing To SSV To Flare Supply ¼ NPT Piping To VRU Supply 1" Sch. 40 To Heat Trace 1" Sch. 40 To Heater Treater Scrubber 1" PSV 125 PSIG Blowdown 3" Sch. 40 Make 4" Sch. 40 for H2s Treating? Kimray 330 SGT- BP MRO Chk Meter Skid 3" BPV Midstream Meter Skid To Compressor From Compressor From VRU Custody Transfer 3/8" SS Tubing To LPS Oil Dump 1" Sch. 40 SSV 1-13/16" 10,000 PSIG 3" Sch. 160 Welded Flowline Buried Flowback Choke Swab Choke Which Valve? 3" Sch. 40 36"x10' 500 MD (H)LPS Clean out flange 3" PSV 250 PSIG Kimray 850 HUTA Kimray Kimray CBA 250 CBA 250 SOA SOA Recirc line Fitting From Supply Can run line to sales with BPV set to open to tanks / VRT @ 100 psig To VRT or Tanks 48"x20' 125 MD (H)HT Kimray 212 SGT- BP Blowdown 2" PSV 125 PSIG Kimray 850 HUTA From Supply Dump From From VRU Compressor Compressor Dump Dump Drain Kimray CBA 250 SOA Kimray CBA 250 SOA From VRT To VRT 4" Pressure (6 oz.) / Vacuum Relief (- 0.4 oz) Valve (Enardo) 8 oz./- 0.4 oz. 8 oz./- 0.4 oz. 8 oz./- 0.4 oz. 4" Sch. 40 Vent From Heater Treater / VRT 500 BBL Water Tank 500 BBL Oil Tank 500 BBL Oil Tank To Flare 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. Recirc line Fitting From Flare Dump Rev. 0: Create PFD 11

Initial Layout and Piping 12

Flowback - Current Set Up Flowback Setup (A) Equipment Requirements (1) 2" Double Buster Flowback Tank (245') 2" 1502 Piping Sand Separator Hookups Choke Manifold 1 (27) 2" Plug Valves (2) 15K Choke Manifolds (65) Hobbles Piping Legend 3" 1502 2" 1502 Plug Catcher Choke Manifold 2 1440 PSIG Test Separator Safety Valve GB GB 2" Double Buster Flowback Tank (30 ) 3" 1502 Piping (1) 3" Double Plug Catcher w/ screen (15K; ¼ holes) (1) Safety Valve (1) 1440 PSGI 3-Phase Test Separator MRO Owned Spill Mats (Separate Bid) 13

Flowback - New Set Up Equipment Requirements (50') 2" 1502 Piping (12) 2" Plug Valves Piping Legend 3" 1502 2" 1502 MRO Owned 3" Sch. 160 Flowback Choke Plumb to Swab Line 500 psig MD Horizontal Sep. (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 Plumb to Frac Tank Plug Catcher Swab Choke 2" Double Buster Flowback Tank 14

Questions? 15