burst and pressure - full report

8/12/2019 Burst and Pressure - Full Report

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MEDCO

Simulation Results for Well Kalvin Douglas 15H-01

ENCANA

Simulation made using

Tubing Analysis System (TAS) software

by

Modelling Engineering & Development Company

www.medcotas.com

Copyright 2011


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Kalvin Douglas 15H-1 (Red)

Kalvin Douglas 15H-2 (Blue)

RED RIVER PARISH

AFE: 10147851& 10147853

PREPARED BY: Steve Koszewski

ENCANA OIL & GAS (USA) INC.NLA COIL TUBING DRILL-OUT PROCEDURE


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Coil Tubing Drill-Out Procedure

Objectives To safely and efficientl y clean-out the wellbore of any composi te bridge plugsor fill that would assist in commingling all fracd zones.

Kalvin Douglas 15H-1Stages MD TVD BHP BHT Plugs

19 17,214 (FC) 12,293 10,695 psi 330 18

Notes: Well is XP frac design (>100K lbs proppant/cluster). Expect large amounts of sandin lateral. Proceed with caution especially in second half of lateral.

Kalvin Douglas 15H-2Stages MD TVD BHP BHT Plugs

17 16,770 (FC) 12,309 10,709 psi 330 16

Notes: Well is XP frac design (>100K lbs proppant/cluster). Expect large amounts of sandin lateral. Proceed with caution especially in second half of lateral.

Safety Concerns

Safety is the highest priorit y

Hold wellsite safety meetings prior to each significant operation.

Review critical parameters and objectives as well as emergency action plans.

Perform JSAs daily for all operations. All contractors are to meet together to discussJSAs and coordinate work. Each contractor shall have a copy of the JSA on location andshall review with other contractors as they show up on location.

Perform location inspections each day that work is performed on the location. Payparticular attention to the reserve pit to assure that there are no leaks.

Retain a gate guard at the location entrance until all operations have been completed.

Furnish cooling trailers during operations if weather necessitates. Supply drinking waterand approved electrolytes at the trailers.

Release and remove all necessary equipment at the end of the operation and clean-upthe location.

Verify that all production tanks are grounded, and anchors, if necessary, are in place. 48hours is required for One Call (Louisiana 1-800-584-4274). One call must becompleted by vendor prior to any type of flowback/completion operations.

All incidents are to be reported to supervisor and Encana supervisor immediately.

Ensure cement blocks and cages are secured on additional wells on pad.

Environmental Concerns

Use Mineral oil/Vegetable oil to flush chemical lines NOT DIESEL

Ensure all equipment is set up properly and checked for leaks. Tighten any leakingequipment.

Field Flowback Coordinator or flowback company is responsible for checking tank levelson all open top and frac tanks used during the flowback operations. Have the fluidremoved by an approved vacuum service as needed.

Use fresh water when performing pressure tests on flowback treating lines. Bleed off intothe open top tanks, alleviating any water from contacting the ground.

Encana has a NO FLARE policy. If flaring is REQUIRED, Completions Engineer mustnotify the Environmental Coordinator supporting NLA. The Environmental Coordinatorwill determine whether a permit is needed.


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Field Flowback Coordinator or flowback company is responsible for notifying CompletionsEngineer if any type of wildlife is found in a reserve pit. The Completions Engineer isrequired to notify his/her supervisor and the NLA Environmental Coordinator.

Make sure spill containment is in proper location to contain any leaks/spill. Report ALLspills, anywhere on location.

Continue throughout the completions operation to check the reserve pits to verify there is

a minimum of 2 ft of freeboard. Field Flowback Coordinator, or flowback company areresponsible to have free water removed from pit if necessary.

Verify all MSDS sheets are on location and easily accessible (i.e., company rep trailer)

During any point during the flowback where gas is being vented to the atmosphere, theestimated volumes need to be captured and noted on the flowback report.

Rig Up & Test

1. MIRU crew and equipment to dress-off location. Make sure rat-hole is filled andcompacted before location is dressed off and rock is laid.

2. A post frac wellbore schematic and directional survey must be provided to coil company,and consultants. Have coil company perform a torque and drag model for the CT DO.

Review the torque and drag modeling to make sure no limitations have been overlooked.Also review the fatigue data of the tubing and have an understanding of the tubingshistory, storage maintenance, etc. Note that Encana does not allow any high fatiguepoints (>60%) or butt welds. Ensure that the coil supervisor and operator are checkingthe fatigue software periodically throughout the job.

3. Review the fatigue data and compare the plug depths to determine if any CT needs to becut prior to RIH.

4. All equipment used on location will need to be rated to 15K psi, 375 F, 25 ppm H2S and10% CO2 compatible. Confirm 90k yield strength coil or higher.

5. Spot and RU the followingo 1.75 CT unit: Ensure that the coil is not fatigued more than 60% in any portion

of the string. The tubing reel needs to be a minimum of 30 from the injector asto not exceed 5 of the fleet angle. The distance should be ~60 from the reel tothe gooseneck, and the gooseneck should have a minimum 90 radius. CTUmust be rigged up so the operator can visually see the gas buster and fluidsreturning to surface. Ensure the anchor points are ~50 apart and 18 from thewellhead. The anchor lines should cross each other.

o Pump truck: 2 Pumps or Double Pump (Capable of 2.5 bpm @ 12,000 psicirculating pressure on one side of double pump)

Ensure coil company and/or tool company have at least 1 inline filter inplace.

Do not start in the hole unless both sides of the double pumpare in good working condi tion so that there will always beone on backup. DO NOT RIH using both sides to make uptotal rate. Only one side will be used with the other forbackup.

o Crane: 80 ton, with 110 boom length Minimum crane should be 70 ton with 100 boom length Crane should be positioned at a 90

o

o 250 BBL open top tank: Tank must be spotted a minimum of 100 downwind ofany ignition source, i.e. CT unit.

angle between wellhead and coilunit.

o Gas buster: Must be anchored and set high enough to view fluids returning.


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6. All connections from the top of the tree to the stripper must be flanged (Figure 1).

7. Two 2 flow lines will be NU to either side of the frac stack 2-9/16 flowcross.o The primary line will connect to a hydraulic choke manifold, anchored gas buster,

and then dump into the 250 bbl open top tank.o The secondary line will tie into a manual choke manifold, anchored gas buster

and then dump directly into the 250 bbl open top tank.

o Note: If at any time the primary circulation line becomesplugged off due to large sand slug, be prepared to open thebackup line to the manual choke manifold as needed tocontinue flow.

8. RU CT Quad BOP stack on top of flow cross and install flanged riser. Install injectorhead on riser. Ensure that there is no bending load on the riser and that the craneoperator is constantly monitoring his weight so that there is sufficient tension. Enoughriser joints will be necessary to house the BHA (~ 25 BHA, each lubricator joint is 8-10).

o The Quad BOP includes (See Figure 1):

Blind Ram

Shear Ram Slip Ram

Pipe Ramo There should be 2 sets of safety rams below the quad BOP and below the flow

cross. These should include (See Figure 1):

Blind/Shear Combies

Slip/Pipe Combieso Double check the rams are the proper size for the coil prior to RU on treeo The flow coil tubing flow cross rig up should allow kill weight to be circulated

down the coiled tubing/tubing annulus at any point during the job.o Each side of the flow cross is equipped with a manual and a hydraulic or

pneumatic remote operated valve. (Manual on the inside closest to flow cross,hydraulic outside)

o All of the BOP function should be cycled and visually observed functioning.Check for hydraulic leaks. Test and record the amount of time necessary toopen and close the valves.

o Check the pre-charge in the accumulators and ensure there is enough pressureand hydraulic fluid in the system to operate in a well control situation

9. RU fluid companys mixing plant (2 - 40 bbl) and associated equipment including filterpods and pumps if necessary.

o Sweeps:

Have double the amount of sweep fluid necessary on location.

All sweeps must be pumped with a colorful dye to recognize return.

2 sweeps/plug (One when plug is tagged and one when plug sets free)

1 sweep at PBTD

Sweeps can also be broken into a 5 bbl Xanthan sweep followed by a 5bbl water wash sweep, and then the second 5 bbl Xanthan sweep.These will all be pumped back to back.

Well wash sweeps work better when cleaning propants, however a 10-15bbl heavy sweep (80-100 vis) will have better lift properties for plug parts.

The sweep viscosity will have a minimum of 80 cp. If this is an issue, donot continue to mill plugs until fluids are brought back to acceptablelevels.

o Friction Reducer:


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1.5 gal FR/10 BBL of fresh water.

The CTDO will require roughly 3,000-4,000 bbls of fresh watero Pipe On Pipe/Liquid Beads:

P.O.P - No more than 1% treatment per 40 bbl pumped

Liquid Beads - 16 lbs per 40 bbl pumped

Have the fluids hand monitor and coordinate with coil operator to see

how pipe conditions are behaving and treat accordingly.

10. PU 2.875 External coil connector w ith pump thru th read protecto r. Load coil withFresh Water and pressure test the well cont rol stack in the follow ing order.

a. Open BOPs and Riser (against closed 4-1/16 crown valve)b. Blind Ram (test from bottom through kill port)c. Pipe Ram (closed on coil t ubing/test from bottom through kill port)

Note: Each segment of the test should consist of:o low (must be between 200 psi and 300 psi held fo r 5 min stabalized)o high pressure 10,000 psi(must be held at the Maximum Ant icipated

Operating Pressure (MAOP) of the component for 10 min stabili zed)

11. RU & PU BHA (Motor / Mill Run, Figure 4)o 2.875 External Coil Connectoro 2.875 Dual flapper valveso 2.875 Haley Jarso 2.875 Hydraulic disconnect (0.9375 ball)o 2.875 DualCirculation Subo 2.875 Vibrational Toolo 2.875 High Torque Motoro 3.75 5-Blade Reverse Clutch Mill

12. Run a ball through the hydraulic disconnect and circ sub to determine the proper ballsize.

o Ensure the tool company has drifted their circ sub and disconnect prior to arriving

on location. These are below the dual flapper in motorhead assembly and arevery difficult to drift on location and retrieve once dropped. Drift largest ball sizethrough jars before M/U

13. Pull test coil connector to 20K lbs and pressure test connector to ensure O Ring holds.

14. Spin the motor at surface to confirm that it is working properly. Do not drill a pilot hole onlocation.

15. Set depth counter to 0 at bottom flange of the lubricator. Visually inspect the rotor wheelon the counter for any ware or debris. Replace if necessary (1/32 groove in wheel cancause 100 inaccuracy at depth). Reset all data acquisition systems to reflect properdepth.

16. If necessary, equalize pressure across the wellhead by pressuring up on the lubricator.Open and close crown valve. Record number of turns to fully open and close. Flowbackcompany should operate all wellhead valves.

o Encana rep must be present at wellhead during opening and closing well toensure proper valve function.

17. All hydraulic safety systems must be in place and functional prior to the operationcommencing.


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RIH and begin CTDO Operation

18. Open crown valve.

19. Calculate the snubbing force and get the drag force from the coil operator. Correlate thisvalue to the pipe light when initial snubbing operation commences. Make sure these

values are similar. If not, the wt indicator and load cell may not be working properly andwill need to be fixed.o CT OD^2 (in.) x 0.7854 x WHP (psig)

20. Flow will be through a single flowline at a time. In the event of a line plugging off, thesecondary flow line must be opened prior to the primary flowline being closed.

o Monitor dump line on sand trap and any other line not in use to ensure no leaksduring job so the BPM for returns are accurate. (Secondary lines may be tied intoauxiliary tanks)

21. While in the vertical section, perform the following:o Run in hole while pumping to maintain internal pressure on coiled tubing and

ensure nozzles are free of blockage. Run in hole at 80-100 fpm. Slow to 30 fpmwhen nearing restrictions (this rate should be maintained or reduced whenunsure of depth of wellbore obstructions and when approaching plugs or sand).

o The circulation rate should be 0.25 0.5 bpm and the flowback rate will also be0.25 0.5 bpm (15 30 bbl/hr). Have coil operator double check circulating rateby counting pump strokes.

o Perform a pick-up or pull test on coiled tubing every 4000 ft and record weight.Correlate the drag and slack off weights with the software predictions.

o Monitor circulating and wellhead pressures closely. Watch for a change in slopebetween the circ. and whp. This may indicate a poorly swept wellbore or otherissue.

o Monitor pipe fatigue.

22. If at any time an obstruction is tagged, immediately increase the circulation rate to 2.0bpm, keeping the flowback rate the same. Treat the obstruction like a plug. Maintain 2.0

bpm while obstruction is showing resistance, otherwise keep the circulating rate at ~2.0bpm. Do not begin short tripping for any of these sand plugs unless they are deemednecessary.

23. Re-check the fluid system, if pump pressure is higher than anticipated, have fluidoperator adjust appropriate friction reducer. Calculate the annular velocity to ensure it issufficient to lift plug cuttings and proppant.

o AV, fpm = (24.5*Pump Rate, GPM) / (CT OD^2 CSG ID^2) + Trip Vel.o AVs from Cerberus modeling in typical wellbore completion are shown at 123.4

ft/min in the 5.5 inch casing section and 166.7 ft/min in the 5 inch casing section.See prejob model for more detailed information including AVs and liquid bottomsup time.

24. While entering KOP for the first time perform the following:o The circulation rate and flowback rate will be 2.0 bpm (120 bbl/hr).o When entering a well that has been producing for several weeks stop at the end

of curve, pump 10 a bbl sweep and circulate 1 wellbore volume at 2.0 bpm. Thiswill ensure a properly circulated wellbore.

o Monitor circulating and wellhead pressures closely. Especially watch for achange in slope between the circ. and whp. This may indicate a poorly sweptwellbore.

o At EOC, as long as no obstructions were encountered, continue to the 1stplug at

a circulation rate of 2.0 bpm.


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o Continue to TIH at max rate of 35 fpm.o Monitor pipe fatigue.

25. Tag plug, pump 10 BBL sweep per design, decrease pump rate to 1 bpm and PU 3-5.Begin circulating at 2.0 bpm to wash any loose debris from plug. At this point beginflowing the well at 0.5 bpm above injection rate to increase your AV. Get a baselinepressure and wt. before tagging back on plug.

o If at any time the well begins to produce excessive amts of gas, choke the wellback to keep the well from flowing.

26. Set back down on plug and slack off enough weight to torque the motor, this will rangefrom 500 to 1200 lbs weight on mill. Continue slacking off just enough weight as plugmaterial is removed. If progress through the plug stops, then pick up 3 ft off plug and setweight back down on plug remembering to decrease pump rate to 1 bpm prior to PU.

Start out mi lling with the minimum amount of set-down weight as possible,this may lengthen the mill out time but will reduce the size of the plug partsand string out the cuttings being returned through the choke. Average milltime per plug should range from 15-30 min. If plugs are being milled in less

than 10 minutes, consider this too fast (apart from plugs blowing up). Ifplugs are blowing up or mill t ime is less than 10 minutes, short trip afterevery 3rd

plug. If pump pressure increases by more than 500 psi, then too muchweight is being stacked on plug and the motor will stall out. If a stall occurs, decreasepump rate to 1 bpm and pick up coil tubing to minimize pipe fatigue. The number ofpickups should be limited because of the number of cycles allowed on coil. (Roughly 20-30 cycles for 1.75 and 10-15 cycles for 2 coil in HP environments > 10,000psi)

When milling through a solid plug with differential pressure below that is substantiallygreater or less than the pressure above it, circulate bottoms up to remove all debris fromthe wellbore prior to milling on the plug. Then proceed slowly through the top 6 - 8 in ofthe plug allowing the pressure to equalize. Periodically lift the BHA off the plug asprogress is made through these first six inches to insure pressure venting or equalizing.

This relieves the forces on the top slips and reduces the risk of sticking. Theseconditions could change when drilling a flow-through CBP.

Stacked Plugs: If the plug is not completely milled thru, a stump may cause spinning onthe following plug. Spinning will be noticed if no torque is applied to the motor, i.e.,circulating pressure doesnt rise when wt is stacked out on the plug. In this case, keepcirculating and flowback rates at 2.0 BPM and keep 2k-4k lbs WOB. PU every 15 min ifthere is no change in circulating pressure or pipe wt to change the milling pattern.Ensure pump rates are decreased to 1 bpm prior to any PU. Document the total numberof stalls for the motor.

Pump Problems: As stated above, we will not RIH unless both sides of thedouble pump are in good work ing condit ion. There should always be one

side running with the other as backup. If pump problems are encounteredwhile working in the horizontal part of the wellbore, activate other side asneeded to maintain optimum ci rculating rate. Once circulation is re-established, determine if pump wil l be able to continue to run on one sidewith the other as backup. If this is not possible (one side is down unti lmechanic can work on it) pull back into vertical to repair pumps. DO NOTcontinue milling plugs if problems persist and/or there is no backup pumpto go to (ie. Using both sides to maintain rate). If catastrophic pump


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problems occur or pump is completely lost , be prepared to adjust backsidepressure as needed to maintain optimum AVs.

27. Mill through plug.

28. Once plug sets free, perform the following:o

Pump a 10 BBL sweep per design.o The circulation rate should be 2.0 bpm, and the flowback rate will be 2.0 bpm.o If at any time the well begins to produce excessive amts of gas, choke the well

back to keep the well from flowing.o Monitor circulating and wellhead pressures closely. Watch for a change in slope

between the circ. and whp. This may indicate a poorly swept wellbore.o Calculate the bottoms-up time and monitor the flowback tanks for the sweeps to

ensure integrity.o Once the sweep has reached the distance between KOP and surface

decrease the pump rate to 1.3 bpm (AV=100 fpm) or 7500 psi circulatingpressure, whichever allows for higher circulating AVs.

o Continue to TIH at max rate of 35 fpm.o Monitor pipe fatigue.

29. Tag and mill through the next plug using the same procedure.

30. Short trip after every 4 plugs in fi rst half of lateral and after 3 plugs insecond half. If excessive amounts of sand is seen consider option ofgoing down 2 plugs in second half of plug network before short tripping.

o if you begin seeing set down weights while RIH and no action on motor, considershort trips more frequently and increase the number of sweeps being pumped

31. Perform the following short trip procedure once the plugs have been milled:o Pump a 20 BBL sweep per design.o Continue into the hole 3-5 fpm while the sweep is on its way, no more than 75.o Wait before the sweep reaches the surface before beginning a short trip into a

safe spot in the vertical section near KOP. Each short trip depth needs todecrease 100 as to not fatigue the tubing in the same spot.

o When in the lateral, the running speed should not exceed 35 fpm. Closelymonitor the weight indicator to make sure we are not pulling heavy.

o During short trip to vertical, maintain a pump rate of minimum 2 bpm.o If at any time the well begins to produce excessive amts of gas, choke the well

back to keep the well from flowing.o After reaching KOP, circulate for 30 min at 2.0 bpm.o If fluids are being mixed properly, you should still be able to stay around 2bpm

during RIH. If there is a sweep inside the coil, pressure will increase 300 - 500psi.

o Calculate the bottoms-up time and monitor the flowback tanks for the sweeps toensure integrity.

32. Repeat steps 24-30 for the remaining plugs.

33. After the last plug sets free, push to PBTD and follow step #30

34. When TOOH, ensure the depth counter is accurate. When tools bump up, record thedepth counter to determine how far off it actually is.


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Appendix

Figure 1: Proper RU of Coil Tubing Well Control Stack For NLA Operations .


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Figure 2: Encana Standard 5-1/8 Tree Assembly


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Figure 4: Standard BHA Configuration for Motor/Mill Run.


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Figure 5: Proper RU of Flowback Equipment for NLA CT High Pressure Operations (TypeII).


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MEDCODisclaimer: No Warranty implicit or explicit is implied by MEDCO as to the accuracy of the results.The use of these results are subject to End User License Agreement (EULA) of the TAS software.

Well Information

Well Name: Kalvin Douglas 15H-01

Maximum Depth: 17,276 feet

True Vertical Depth: 12,248 feet

Horizontal Distance - North: 5,214 feet

Horizontal Distance - East: 203 feet

Maximum Inclination: 92.3 @ 16,294 feet

Maximum DLS: 14.23 deg/100ft @ 12,255 feet

TAS version 3.69

Copyright MEDCO 2011


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MEDCOWeight Results

No Lock-up detected

Maximum Pull: 64,343 lbs at 17,238 feet

Maximum Bottom-Hole Pull: 13,368 lbs

Maximum WOB at TD: 451 lbs

Surface Weight At Maximum WOB: -522 lbs

TAS version 3.69



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MEDCOTension/Compression Results

Tri-Axial Stress Results

Pull-out stress at Max. DLS: 9,516 psi

Run-in stress at Max. DLS: 14,225 psi

TAS version 3.69



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MEDCOBurst/Collapse at Surface

Burst Pressure at no-load: 12,230 psi

Collapse Pressure at no-load: -11,367 psi

Maximum Load at no-pressure: 54,684 lbs

Maximum Load: 58,692 lbs at 4,768 psi

TAS version 3.69


burst and pressure - full report

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