4. chemical sand consolidation trials (shell)

8/9/2019 4. Chemical Sand Consolidation Trials (Shell)

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Copyright of Sarawak Shell Berhad

Contents

04 September 2012 2

SandAidNon Resin based Chemical Treatment, SC2020SandTrap ABC


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SandAid Trial

Zone 1 reservoir produced highsand (>1000pptb) D(50) 120-130micron Well test (August 2008):

- Gross 1400bb/d, Net1000bopdLast sand production record: 6Feb09 with

- 9084.2 pptb

- 1854.8 pptb- 2060.7 pptb

SandAid was pumped (May 2010)into Zone 1 to consolidate the sand

Well-A

Perf:65ft


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SandAid Chemical

Inner Salt of Very low Molecular weight Polymer that when added toaqueous solutions coats rapidly any metal oxide or anionic substratelike proppant, sand or coal Alters the zeta potential of solid surfaces to the optimum range(between -20 & +20 mV)Creates an uneven or random charge distribution on the surface ofthe solid particles.

Locations with high attraction (Van der Waals and electrostatic)

Locations with high electrostatic repulsionProvides a strengthened attraction between the particles to optimallyalign proppant, sand particles, fines or coal fines


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SandAid Chemical


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SandAid Treatment

SandAid TreatmentInjectivity test was done with brine NH4CL up to 5 bpmSuccessfully pumped SandAid into the reservoirTotal brine pumped= 700bbls, total SandAid Pumped= 21.5bbls.Spearhead (140bbls NH4CL), main treatment (261bbls NH4CL, 20bbls SandAid), Overflush (139bblsNH4CL,1.5bbls SandAid), Final displacement (160bbls NH4CL)


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Results

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KN 110L Flow Back

Water Oil Sand up stream

Initial Brine flowed back was normal since this was the liquid that was pumped during the treatment process

Sand spike of 10,000 pptb reading was observed with unknown reason

Well A


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Learning

The well was closed in due to sand production exceeding 15pptb

observed in more than 3 samples for the duration of 10 hours.The Sand Aid clearly has done its job as was observed from thesand that was produced. However, even at very low flow rates, stillmassive amounts of sand were produced, so the sand free rate was

not increased.HUD check on the LS show 120ft of sand accumulated after 3daysof flow back after SandAid treatment


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Learning

According to vendor, this is one of the few wells they treated that thihappened. They do not have a good understanding why it happenedand they are not able to find out the root cause why it did not work. Vendor did not see any value in laboratory testing or other studies toconfirm the root cause.The interval length was only 65 ft and that was short enough for theproduct to work, but unfortunately it did not.Likely the sand has conglomerated (looking at the sand that comesback), but even at low flow rates, the forces on the conglomeratedsand are too high and therefore the sand still comes to surface.


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SC2020 Trial

04 September 2012 10

Well B Zone 1 sanded up due to ESS

failure and it was closed in since2007Perforations interval of 486ftEstimated locked in potential of

~150bopdSC2020 was pumped (April 2010)into Zone 1 to consolidate the sand

Well-B

SC2020


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SC2020 Chemical


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SC2020 Treatment

Diesel spearhead reduces near well-bore region to residual SwShut-in: reaction and polymerisationInjection of Main Pill and placement

Controlled return to production


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SC2020 Treatment

SC2 2 TreatmentInjectivity test was tested with brine NH4CL up to 5 bpmTotal Pre-flush pumped (diesel) = 307 bbls to reduce Swi (dewater near wellbore) .Total Main Pill Pumpe(6% of SC2020) = 329 bbls via LAS pump which have average rate of~5gal/min. Total Displacementpumped = 30 bbls, Total Overall Fluid pumped = 666 bbls

After the treatment, the well was shut in for 24 hours.


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Learning

04 September 2012 14

April 2010Some initial startup fluctuations, adjustments needed to find acceptable rateProduction of 500BPD reportedHistoric PSD analysis from the well showed that 93% of the sand is larger than 100micron.

After trial all sand passes through a 100 micron filter.Positive response as it suggests bigger sand particles stopped

May 2010Some sand peaks but production still at ~500BPD

July 2010Gross production -315 bpdNett production -300 bpd, water cut 5-10%

Well is choked back, sand production below 15 pptb.


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Learning

December 2010Some shift in HUD but well flowing about 150bopdNow (August 2012)

Well still flowing about 260bopd

Successfully ExecutedThe well is producing since treatment but under controlled bean sizeto keep sand production on surface


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SandTrap ABC Trial

Well C Zone 1 was closed indue to high sand productionas ESS failed.The objective was to performsand consolidation treatmenton Zone 1, shut in for curing,and flow back after minimum72 hours curing time. Well C 1st Treatment (NoFoam), 31st May 2011 Well C 2nd Treatment (with50Q Nitrogen), 14th June2011

Well-C

Perf:455ft


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SandTrap ABC Trial

Well D Zone 1 was closed indue to high sand productionas ESS failed.Perforation interval~ 819ft

Well D Zone 1 SandTrap ABC Treatment, 5 th June2011

Well-D


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SandTrap ABC Chemical

SandTrap ABC is a dispersion of the internally catalyzed resin in aaqueous based carrier. It requires only a preflush to displacereservoir fluids and condition the formation. The properties of tsystem cause the consolidating material to be placed very effectiveat contact sand grain points to provide significant improvements mechanical properties with minimal loss in permeability


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SandTrap ABC Treatment

The SandTrap ABC treatments consisted of the following:- Workstring PickleInjection TestSandTrap ABC Treatment

- SandTrap ABC was bullheaded down the tubing in the stages ofPreflush I, Preflush II, SandTrap ABC main treatment, postflush anddisplaced by Nitrogen. Well was shut in for 72-96 hours before openup the well for flowback.


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Well C Treatment Summary-1stTreatment, 31stMay 2011

Injectivity Test- Filled up tubing 3% KCL, 28 bbls- Step up rate to 3 bpm, max WH press observed 138 psi- Start pump 5 bbls of SandTrap ABC

- Overflush& Displace with 3% KCL, 42 bblsSandTrapABC Main Treatment

- Bullheaded treatment in below stages with no foam:- 19 bblsof PreflushI (Solvent)- 62 bblsof PreflushII (3% KCL)- 62 bblsof SandTrap ABC- 19 bblsof Postflush(3% KCL)

- 12,800 scf of Nitrogen displacement


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Well C Zone-1 1 st SandTrap ABC Treatment

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Annulus Pressure, psi

Wellhead Pressure, psi

Liquid Volume pumped,bbl

Nitrogen Rate,scf/min

MATP,psi

Pump Rate, bpm

SF-31 SandTrap ABC Main Treatment31st May 2011

PreFlush I,19 bbls

PreFlush II, 62 bbls SandTrap ABC, 62 bbls

Displace withNitrogen, 12800 scf

PostFlush,19 bbls

P u m p R a t e

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b p m

P r e s s u r e

, p s i

/ N i t r o g e n R a t e

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PreFlush I @formation

PreFlush II @formation

SandTrapABC @formatio

Postflush @formation

Well C


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Well C Treatment Summary-2ndTreatment, 11thJune 2011

InjectivtityTestFilled up tubing 3% KCL, 28 bblsStart injectivitytest, step up rate to 5 bpm, max WH press 361 psiStart pump 15 bbls of foam 3% KCL with 50Q Nitrogen

Overflush& Displace with 3% KCL, 42 bblsSandTrapABC Main Treatment

- Bullheaded treatment in below stages:- 33 bblsof PreflushI (Solvent)- 50 bblsof PreflushII (3% KCL) with 50Q foam (50%N2-50%liquid)- 50 bblsof SandTrap ABC with 50Q foam- 30 bblsof Postflush(3% KCL) with 50Q foam

- 17,700 scfof Nitrogen displacement


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Well C Zone-1 2 nd SandTrap ABC Main Treatment

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0:00 0:12 0:160:180:250:300:35 1:02 1:05 1:10 1:131:161:201:221:25 1:29 1:341:391:441:491:55 2:00 2:04 2:09 2:11

Wellhead Pressure,psi

Pump Pressure,psi

Nitrogen Rate, scf/min

MATP,psi

Pump Rate,bpm

Elapsed Time (hr: min)

SF-31 Zone 1 SandTrap ABC Treatment with 50Q Nitrogen14 June 2011 SFJKT-B Otto-3

PreFlush I(33 bbls)

PreFlush II(50 bbls)

SandTrap ABC(50 bbls)

Postflush(30 bbls)

N2Displacement(17,700scf)

SandTrap ABC reachedformation

Pump Stop.compressor down.

Pump Stop.compressordown.

PreFlush Ireachedformation

PreFlush IIreachedformation

Postflushreachedformation

L i q u i d P u m p R a t e

, b

p m

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, p s i

N i t r o g e n r a t e

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/ m i n

Well C


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Well D Treatment Summary

Injectivity Test- Filled up tubing 3% KCL, 31 bbls- Start injectivity test, step up rate to 1 bpm, max WH press observed

570 psi- Start pump 5 bbls of SandTrap ABC

- Overflush & Displace with 3% KCLSandTrap ABC Main TreatmentBullheaded treatment in below stages with no foam:- 10 bbls of Preflush I (Solvent)- 26 bbls of Preflush II (3% KCL)

- 13 bbls of SandTrap ABC- 8 bbls of Postflush (3% KCL)- 13,240 scf of Nitrogen displacement


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Well D Zone-1 Main Treatment

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Annulus Pressure.psi

Wellhead Pressure,psi

Pump Pressure, psi

Total fluid pumped, bbls

MATP, psi

Liquid Pump Rate, bpm

PreFlush I,10 bbls

PreFlush II, 26 bbls SandTrapABC, 13 bbls

Displace withNitrogen, 13240 scf

PostFlush,

8 bbls

PreFlush I @formation

PreFlush II @formation

ST ABC @Formation

PostFlush @Formation

SF-33SandTrap ABC Main Treatment5th June 2011

P r e s s u r e

, p s i

P u m p R a t e

, b p m

Time, min

Stop NitrogenPump

Well D


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Post Job Well Test Monitoring

Date 21/06/2011 22/06/2011 25/06/2011 26/06/2011 27/06/2011 27/06/2011

Choke (/64") 10 10 10 10 10 10Gross (bpd) 94THP (psi) 292 418 357 405 427 416FLP (psi) 94 93 100 96 101 102CHP (psi) 475 514 477 466 455 453GL rate (Mscfd) 0Watercut (%) 16 55 22 45Net (bopd) 78.96GOR (scf/stb) 128Sand pptb 217 15 271 175 700

Date 25/06/2011 26/06/2011 28/06/2011 28/06/2011 29/06/2011 01/07/2011 02/07/2011 03/07/2011 04/07/2011Choke (/64") 30 30 30 30 27 27 27 27 27Gross (bpd)THP (psi) 240 108 316 470 300 242 255 248FLP (psi) 98 95 108 103 82 75 83 84

CHP (psi) 512 533 565 566 527 464 488 469GL rate (Mscfd)Watercut (%) 65 gas 52 gas gas 0 0 0Net (bopd)GOR (scf/stb)Sand pptb 3 251 113 2 2 2

Well C

Well D


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Learning Well C

Well C1) Well C: Well shut in for 3 days. Sanding out at choke size of

10/64.

2) Sand fill log indicated that minimal sand fill material from3115 3432 ft (upper Zone 1).

3) The pre-job injectivity test also point towards goodconnectivity with the formation.

4) Due to the nature of long perforated interval (~455ft) or

various permeability distribution, the placement of ST ABCcould be unevenly distributed (even though foamed), causingsand production from untreated interval.


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Learning Well C

Possible Cause1) Production of sand from the leak point at 3262ft and or 3761

ft.

2) Treatment may only flow through SSD which has larger IDthan the leak points

3) Sand fill behind the leak point, especially the compact sandzone (>3668 ft) which may not be treated adequately by ST

ABC and thus flow back to surface during the flowback test.


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Learning Well D

Well D Zone-1

1) Initial well test shows no sand produce on surface after thecuring period of 3 days.

2) Sand produced at bean size of 30/60.

3) Minimal sand production observed after bean down to 27/60.4) The compacted sand fill (indicated by low injectivity) receive

little or no resin treatment when the production rateincreases, some sand was dragged by the production tosurface.

5) HUD check found that sand HUD covering the SSD.


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Well C Flowback Sand sample after 1st treatment

XRD MINERALOGY RESULT

Lost on ignition Test (LOI) RESULT

Samples were divided into 3 portion for testing.Percentage of wt loss observed were, 0.925%, 0.900%, 0.913%.

Average Weight Loss obtained = 0.9126%-typical 3% loss if is coated with SandTrap ABC

Test was conducted at 1000C (SandTrap burnt off point).

Post Job Investigation


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X-ray diffraction indicated presence of dolomite.Observed weight loss was due to decomposition of dolomite duringLOI test. Dolomite degradation happens at about 800 deg.C.It can be concluded that the tested sand sample produced did notcome in contact with SandTrap ABC.Review candidate selection:

- preferably cased and perforated completion at the end of LS

- Moderate sand production rate tubing is not filled with sand

- Target treatment interval length:- Short preferred- Long (>10ft) foam treatment recommended for better placementof resin treatment through diversion

Summary of SandTrap ABC Application


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Q & A


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4. chemical sand consolidation trials (shell)

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