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EXTENDED GAS ANALYSIS
V0008227- 1
CON1AINER IDENTITY
100/01-34-085-22W6/02
METER ID
ARC Resources Ltd.OPERATOR
ARCRes Hz N Red A2-4-86-22
29042WELL LICENSE NUMBER
52134-2015-3673LABORATORY FILE NUMBER
FAGE
LOCATION(UWI) WELL NAME
Red Montney MA2/MB
KB ELEV (m) GR ELEV (m)
Production TestingFIELD OR AREA POOL OR ZONE SAMPLER
TESTTYPE AND No
Separator Meter RunPOINT OF SAMPLE
TEST RECOVERY
SAMPLE POINT ID
PUMPING FLOWING GAS LIFT SWAB
I/I ATE R rrr/d OIL m'/d GAS rrr/d
TEST INTERVALor PERFS (meters)
SEFARATOR RESERVOIR OTHER
Pressures, kPa (gauge)
2015 11 15 2015 11 19 2015 11 25 MK
L20.0SEFARATOR OTHER
Temperatures, C
DATE SAMPLED (Y/M/D) CATE RECEIVED (Y/M/D) DATE ANALYZED (Y/M/D) ANALYST AMT AND TYPE CUSHION MUD RESISTIVITY
COMPONENTMOLE FRACTION
AIR FREE ASRECEIVED
MOLE FRACTIONAIR FREE
ACID GAS FREE
mumAIR FREE AS
RECEIVED
CALCULATEDGROSS HEATING LALUEMJ/m' 15 C & 101 325 kPa (aas )
46.76 46.96
CALCULATEDLAPOR PRESSURE
kPa(aas)@40 C
92.5
MOISTURE FREE MOISTURE Ik ACID GAS FREE PEN1ANES PLUS
Hz
He
Nz
COZ
HZS
Trace
0.0001
0.0153
0.0047
0.0000
Trace
0.0001
0.0153
0.0000
0.0000
CALCULATEDTO1ALSAMPLE PROPERTIES (AIR=I)@15 C & 101 325 kPa
MOISTURE FREE AS AMPLED
0.731 21.2
DENSIRY RELATIVE DENSITY RELATIVE MOLECULAR NABS
CT PROPERTIES @15 C & 101 325 kPa MOLE FRACTION LOCATION METHOD
CALCULATEDPSEUDOCRITICAL PROPERTIESAS SAMPLED ACID GAS FREE
Pc Tc Pc Tc
Cl
Cz
0.7798
0.1092
0.7836
0.1097 388.1
745.6 IN/m 97.1
DENSITY MOLECULARWEIGHT
0.0000000 Laboratory Chmmatograph
HYDROGEN SULPHIDE
CS 0.0562 0.0565 206.5
iC4 0.0069 0.0070 30.1
C4
iCB
Cs
c,
C74
Total
0.0163
0.0032
0.0039
0.0022
0.0022
1.0000
0.0164
0.0032
0.0039
0.0022
0.0021
1.0000
68.6
15.6
18.9
11.6
12.2
751.6
REMARKS:
Sample was air contaminated.
Results may be affected by air contamination.
Opening pressure does not ref lect field conditions
Duplicate cylinder was under vacuum upon arrival.
NOTE: THE GROSS HEATINGVALUEHAS BEEN CALCULATEDIN ACCORDANCETOAGAREPORT s5 ANDALLPROPERTIES HAVEBEEN CALCULATEDUTILIZING
PHYSICAL CONS1ANTS AND BOILING POINT GROUPING.
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OIL ANALYSIS
017- 3CONTAINER IDENTITY
100/01-34-085-22W6/02LOCATION (UINI)
RedFIELD OR AREA
METER ID
ARC Resources Ltd.OPERATOR
ARCRes Hz N Red A2-4-86-22INELL NAME
Montne)/ MA2/MBPOOL OR ZONE
29042INELL LICENSE NUMBER
521 34-2015-3673LABORATORY FILE NUMBER
FAG E
KB ELEV (m) GR ELEV (m)
Production TestingSAMPLER
TEST TYPE AND NO
Second Stage SeparatorPOINT OF SAMPLE
TEST RECOVERY
SAMPLE POINT ID
PUMPING FLOINING GAS LIFT SWAB
INATERLTEST INTERVALor PERFS (meters)
SEPARATOR RESERVOIR OTHER
Pressures, kPa (gauge)05:00 Hrs
2015 11 15 2015 11 19
m'ld
2015 11 24
OIL
IR
m'/d GASLSEPARATOR OTHER
Temperatures, 'C
m'ld
DATE SAMPLED (Y/M/D) DATE RECEIVED (Y/M/D) DATE ANALYZED (Y/MID) ANALYST AMT AND TYPE CUSHION MUD RESISTIVITY
SAMPLE PROPERTIES
LT.YELLOWAPPEARANCE OF CLEAN OIL
0.000WATER
0.000Bs
0.000TOTALBS 5 IN METHOD
kPa
BAROM PRESS
ABSOLUTE DENSITYkg/m'15'C
800.3
API [email protected]'C
45.2 ROOM TEMP INITIALBOIL PT
AS RECEIVED
SULPHUR
1.30grams/kg
AFTER CLEANING
SALT
kg/rrn
AS RECEIVED AFTER CLEANING
WAX CONTENT POUR POINT 'C
-27AS TM
DISTILLATIONSUMMARY
204'C NAPHTHA 274'C KEROSENE
REID VAPOUR PRESSURE FLASH POINT 'C343 '0 LIGHT GAS/OIL RECOVERED
kPa @ 37 9 'C Pensky-Martens Closed Cup(ASTM D-93)
Cleveland Open Cup(ASTM D-92) RESIDUE DISTILLATIONLOSS
VISCOSITYOrganic Chloride
Organic Chlonde in Naphtha Fraction TOTALACID NUMBER
mg/kgmg KOH/g
Naphtha Volume Fraction
Volume Fraction
Total Phosphorus Contentin Volatile Fraction
(CAPP, D86, D5185)
Organic Chlonde in Whole Samplemg/Kg
mg/kg
REMARKS:
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File: 52134-2015-3673
Page No: 4
Company Name: ARC Resources Ltd.
Well Name: ARCRes Hz N Red A2-4-86-22
Location:
Sampled From:
Sampling Date:
1 00/01-34-085-22W6/02
Second Stage Separator
2015 11 15
VISCOSITY - TEMPERATURE CHART
EE
I-40CIC240)C2I-
IuZ
10. 20. 40. 50.
TEMPERATURE (Degrees Celsius)
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$%�%�&'%�$�(*)�+�(*%�,�-�(*.�.�/10�&'%�. ���23����� �"'������ �����4� ��"'�4�.�%�$�- $�$�$-
57698:6 ��;=<!>@? 6 ��� 5A.�(*+�(*,�0�(*.�.5769816 ��;B�4C�� 23��;=D"'�4E8 ������4�F@?G�4�H�4�
/ ��� �B?!���7���D��2B��"I� �4���
-�.�$�)�+�(*.�%�$�-�(*)�0�J)+K ����� ?!���
��� � ���
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��������������������������
LNM ONLPM QNLNM RNLPM S3LNM TNLPM UNLNM
ONM U
ONM V
ONM WONM XQ
R
S
T
L
i(c
Company ARC RESOURCES LTD.
UWI
Well/Lease
Formation
Production Intervals
1 00/01-34-085-22W6/2
ARCRES HZ N RED A2-4-86-22
MONTNEY MA2/MB
2866.00 - 4211.00 m (KB)
Test Type FLOW
Start Monday October 26 2015
End Sunday November 15 2015
Production Teetinq, a Schlumberqer Compan>Job Number D4MC-00150
bpetroClass
D4MC-00150
ARC RESOURCES LTD.
100/01-34-085-22W6/2
ARCRES HZ N RED A2-4-86-22
MONTNEY MA2/MB
FLOW
Monday October 26 2015
Sunday November 15 2015
2866.00 - 4211.00 m (KB)
Production Testing, a Schlumberger Company
Company
UWI
Well/Lease
Formation
Test Type
Start
End
Production Intervals
Job Number
ARC RESOURCES LTD.100/01-34-085-22W6/22015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss
ARCRES HZ N RED A2-4-86-22MONTNEY MA2/MB
NORTH REDD4MC-00150
Test Information
OperatorRepresentative
ARC RESOURCES LTD.DOUG RYAN Phone 1-587-582-8033
Well NameSurface LocationDownhole LocationLicenseFormationFluid TypeTypeGround ElevationKelly Bushing ElevationDrill LegProducing Through:Tubing Size
Tubing WeightCasing SizeCasing Weight
ARCRES HZ N RED A2-4-86-22A2-4-86-22W6100/01-34-085-22W6/229042MONTNEY MA2/MBGasHorizontal
m (SL)m (SL)
1
Both
mm
kg/mmm
kg/m
Test TypeTest DurationService CompanyJob ¹Test Unit ¹Field ContactSupervisor Contact
Phone 1-403-597-1259Phone 1-780-296-3894
FLOWMon Oct 26 2015 - Sun Nov 15 2015Production Testing, a Schlumberger CompanyD4MC-00150PT-1003QUINN REBRYNAJASON GASKELL
Production Interval (Top)Production Interval (Base)
2866.00 m (KB)4211.00 m (KB)
Test Totals:Produced GasProduced OilRecovered Load Liquid
642.8910'm'86.25
m'703.70
m'ones/PerforatedIntervals:Formation
MONTNEY MA2/MB
Topm (KB)
2866.00
Basem (KB)
4211.00
Remarks:
PetroCless FlowTest Version 4 5 6.5C IDOL LCD WELL DATA- SOSApt IDOL LCD WELL DATAS ..lAwe5 2.4-66ne@WS Flow Test.soaeae 1
Production TestingA Soal moama Company
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA S...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 1
Test InformationOperator ARC RESOURCES LTD.Representative DOUG RYAN Phone 1-587-582-8033
Well Name ARCRES HZ N RED A2-4-86-22Surface Location A2-4-86-22W6Downhole Location 100/01-34-085-22W6/2License 29042Formation MONTNEY MA2/MBFluid Type GasType HorizontalGround Elevation m (SL)Kelly Bushing Elevation m (SL)Drill Leg 1Producing Through: BothTubing Size mmTubing Weight kg/mCasing Size mmCasing Weight kg/m
Test Type FLOWTest Duration Mon Oct 26 2015 - Sun Nov 15 2015Service Company Production Testing, a Schlumberger CompanyJob # D4MC-00150Test Unit # PT-1003Field Contact QUINN REBRYNA Phone 1-403-597-1259Supervisor Contact JASON GASKELL Phone 1-780-296-3894
Production Interval (Top) 2866.00 m (KB)Production Interval (Base) 4211.00 m (KB)
Test Totals:Produced Gas 642.89 10³m³Produced Oil 586.25 m³Recovered Load Liquid 2703.70 m³
Zones/Perforated Intervals:Formation Top Base
m (KB) m (KB)MONTNEY MA2/MB 2866.00 4211.00
Remarks:
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATA
15000 100 100
13500 90 90
12000 80 80
10500 70 70
9000 80
W Qlm wILIA
7500m mI Il
ILIA
W QlL C
n ; 8000
62 I-
07
050
3150
07m m
ID
3
40"
40
4500 30 30
3000 20 20
1500 10 10
IIII I I I I' I II II I' III I I I I I I I I I I I I I I I I' I I
PetroClessFlowTestVersiom4.5.6.5
C:IDOLLCOWELLDATASUSARIDOLLCOWELLDATASERVICESIPRODUCIIORTESTING,.IAweD246646OWSFlowTIIIID696sll8
ProdnctiontestingASrhlumhsrperCsmpsel
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 46
FLOW TEST DATA
0
1500
3000
4500
6000
7500
9000
10500
12000
13500
15000
Cas
ing
Pres
(kPa
g)Tu
bing
Pre
s (k
Pag)
0
10
20
30
40
50
60
70
80
90
100
Gas R
ate (10³m³/d)
0
10
20
30
40
50
60
70
80
90
100
Oil G
ain (m³)
Water G
ain (m³)
00:00 26/10/2015
01:24 28/10/2015
02:48 30/10/2015
04:12 01/11/2015
05:36 03/11/2015
07:00 05/11/2015
08:24 07/11/2015
09:48 09/11/2015
11:12 11/11/2015
12:36 13/11/2015
14:00 15/11/2015
15/11/2015 08:00:00Tubing Pres 2998kPagCasing Pres 6239kPagGas Rate 23.19310³m³/dOil Gain 0.891m³Water Gain 1.739m³
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Dale Time Cum Row Tubing
Pres
Well
OwingFlow
Pres Temp
OmksShdn
Sne Pms
OnficeDryRowMalar
Dg MIR Piste GasRateCumGasGas
Pres TempGze To
TotalGas
Flared
RdVdBSWOIGanOilRale
Rnid
01Cum Water
Gain
WaterGumleadLTRPH Salinily
dume
2
API Smd
Cd
WWlnmlddhhmmasHrs
I 2015HOI26200000 000
Hrs kPag kPag '0
a 1$640000penWellon )714mm
mm kPag kPa '0 mm IIFm'ld10'm'i)m'''Idm'API200500 008
201000 017
201500 025
203000 050
204500 075
210000 I 00
213000 I 50
220000 200
223000 250
230000 300
233000 350
14 2015HOI27000000 400
008 9334
017 9247
025 9214
050 9160
075 0031
100 8946
150 8799
200 8700
250 8612
300 8524
350 8464
400 8393
8950 13
8829 17
8797 18
8709 20
8506 25
8362 28
8019 34
7009 35
7823 37
7725 38
7669 39
7591 39
I14
I14
I14
714 0 0 0:R tl tloo 0otlo
0000
0000
0000
0000
0000
0000
0000
0000
0000
0000
0000
0000
15000 100 0000 0000 0000 15000360000 150001706882I 26000
10510 100 0otlo 0ootl tl tloo 18510 444240 33510 I705031 I 54000
16300 100 ootlo oootl tltloo16300391200 490101703401I 58000
17630 100 0000 0000 0 000 17630 423120 67440 I701630 I 62000
05
05
05
05
000000 400 40000OOnrsupdate
FTP=7591
SICP=0393kPag
Flowingtemperature=39'C
Chokesize=7 14mmIlol64)
GasRate=0 00ltPm'our
fluidrate=1763m'Ihr
HourCitrate=0m'Ihr
BSW=I00'I
API=NIA
Salinily=62000ppm
PH=I
Sand=O'I
InnalLoadFluid=1780382m'FLTR
=I701630
Oil(Condensate)Produced=0m'otal
WaterRecovered=6744
m'aily
hrsgnwed=400hrs
Cumhrsflowed=400hm
Gasproducedtolast24hrs=00010'rn'umm
GasTo=00010'm'ond
Producedlast24Hm=000m'um
CondProduced=000m'ater
Recoveredlast24Hrs=6744m'otal
WaterRecovered=6744
m'nnalLoadFluidtoRecover=1708382m'oad
FluidLetttoRecover=1781630
m'ercentageRecoveredfromInnalLoad=03TA
Chokeswashedin24houm=0
Totalchokeswashed=0
003000 450
010000 500
013000 550
020000 600
450 8273
500 8224
550 8151
600 8113
7482
7429
7353
7316
40
40 714
41
41 714
0000
0000 15720 100
0000
0000 13550 100
00tlo 000tl
00tlo 000tl
0 000 15720
tl tloo 13550
377280
325200
83160
96710
1700066
1778711
I 66000
I 66000
00
00
030000 700 Too 8005 7207 40 714 0000 15220 100 00tlo 000tl 0 000 15220 365280 1119301777189I 64000 00
PetroolassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTING,.IAweD2d804DOWSFlowTest.klglt3
ProdectiontestiegASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 3
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %1 2015/10/26 20:00:00 0.00 0.00 Open Well on a 18/64 (7.14mm)2 20:00:00 0.00 0.00 9744 9744 9 7.14 0 0 0 0.00 0.000 0.000 Other 0.000 0.000 0.000 0.000 17883.823 20:05:00 0.08 0.08 9334 8958 13 7.14 0.00 Other 0.0004 20:10:00 0.17 0.17 9247 8829 17 7.14 0.00 Other 0.0005 20:15:00 0.25 0.25 9214 8797 18 7.14 0.00 Other 0.0006 20:30:00 0.50 0.50 9160 8709 20 7.14 0.00 Other 0.0007 20:45:00 0.75 0.75 9031 8506 25 7.14 0.00 Other 0.0008 21:00:00 1.00 1.00 8946 8362 28 7.14 0.00 Other 0.000 15.000 100 0.000 0.000 0.000 15.000 360.000 15.000 17868.82 7 26000 0.59 21:30:00 1.50 1.50 8799 8019 34 7.14 0.00 Other 0.000 100 0.5
10 22:00:00 2.00 2.00 8700 7909 35 7.14 0.00 Other 0.000 18.510 100 0.000 0.000 0.000 18.510 444.240 33.510 17850.31 7 54000 0.511 22:30:00 2.50 2.50 8612 7823 37 7.14 0.00 Other 0.000 100 0.512 23:00:00 3.00 3.00 8524 7725 38 7.14 0.00 Other 0.000 16.300 100 0.000 0.000 0.000 16.300 391.200 49.810 17834.01 7 58000 0.513 23:30:00 3.50 3.50 8464 7669 39 7.14 0.00 Other 0.000 100 0.514 2015/10/27 00:00:00 4.00 4.00 8393 7591 39 7.14 0 0 0 0.00 0.000 0.000 Other 0.000 17.630 100 0.000 0.000 0.000 17.630 423.120 67.440 17816.38 7 62000 0.515 00:00:00 4.00 4.00 00:00 hrs Update
FTP= 7591SICP= 8393 kPagFlowing temperature = 39 °CChoke size = 7.14 mm ( 18/64 )Gas Rate = 0.00 10³m³Hour fluid rate = 17.63 m³/hrHour Oil rate = 0 m³/hrBSW=100%API=N/ASalinity = 62000 ppmPH =7Sand = 0%Initial Load Fluid = 17883.82 m³LFLTR = 17816.38Oil(Condensate) Produced =0m³Total Water Recovered = 67.44 m³ Daily hrs flowed = 4.00hrsCum hrs flowed = 4.00 hrsGas produced to last 24 hrs= 0.00 10³m³Cumm Gas To = 0.00 10³m³Cond Produced last 24 Hrs = 0.00 m³Cum Cond Produced = 0.00 m³Water Recovered Last 24 Hrs = 67.44 m³Total Water Recovered = 67.44 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 17816.38 m³Percentage Recovered from Initial Load = 0.37%Chokes washed in 24 hours =0Total chokes washed = 0
16 00:30:00 4.50 4.50 8273 7482 40 7.14 0.00 Other 0.000 100 0.517 01:00:00 5.00 5.00 8224 7429 40 7.14 0.00 Other 0.000 15.720 100 0.000 0.000 0.000 15.720 377.280 83.160 17800.66 7 66000 0.018 01:30:00 5.50 5.50 8151 7353 41 7.14 0.00 Other 0.000 100 0.019 02:00:00 6.00 6.00 8113 7316 41 7.14 0.00 Other 0.000 13.550 100 0.000 0.000 0.000 13.550 325.200 96.710 17787.11 7 66000 0.020 02:30:00 6.50 6.50 8060 7259 41 7.14 0.00 Other 0.000 100 0.021 03:00:00 7.00 7.00 8005 7207 40 7.14 0.00 Other 0.000 15.220 100 0.000 0.000 0.000 15.220 365.280 111.930 17771.89 7 64000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
TubingOwingFlow
Pres Pres Temp
ChdwShun
Sne Pms
OnficeDryRowMalar
Dg MIR Piste GasRate
Pres TempGze
CumGas Gas
To
TotalGas
Flared
RdVdBSWWIGanDilRale 01Cum
Rnid
Water WaterWaterGum
Gain Rate
inertLTRPH Salinily
dume
2
API Smd
Cd
WWfnmfddhhmmss Hrs kPag kPag '6 mm kPag kPa '6 mm IIFm'id (I)m''Idm'API034000
040000
043000
767
800
850
767Increasechoketo20)6 mm)4 (794
800 7904 7090 41
850 7891 7051 41 ct
0000
0000
17730 100 0Otlg 0Ogtl tltlgg17730425520 12966017754167 62000 00
050000
053000
060000
900
950
1000
900 7862 7029 41
950 7883 7056 41
1000 7919 7103 41
ct
794 0 0 0 tl tlgg 00tlg
0000
0000
0000
19300
18430
100 0Otlg
100 0Otlg
0Ogtl tltlgg
0Ogtl tltlgg
19300 463200 148960
18430 442320 167390
1773486
1771643
7 64000
7 64000
00
00
060000 1000 100006OOnrsupdate
FTP=7919
SICP=7103kPag
Flowingtemperature=41'C
Chokesize=794mm(20)64)
GasRate=0 00ltPm'our
fluidrate=1843m'Ihr
HourCitrate=0m'Ihr
BSW=I00'I
API=NIA
Salinily=64000ppm
PH=7
Sand=0'I
InnalLoadFluid=1788382m'FLTR
=1771643
Oil(Condensate)Produced=Om'otal
WaterRecovered=16740
m'aily
hrsgnwed=600hrs
Cumhrsflowed=1000hrs
Gasproducedtolast6ho=0 00ItPm'umm
GasTo=00010'm'ond
Producedlast6 Hrs= 0 00m'um
CondProduced=000m'ater
Recoveredlast6 Hrs=8423m'otal
WaterRecovered=16740
m'nnalLoadFluidtoRecover=1788382m'oad
FluidLetttoRecover=1771643
m'ercentageRecoveredfromInnalLoad=093'I
Chokeswashedin6 hours=0
Totalchokeswashed=0
063000
070000
073000
080000
083000
090000
093000
100000
1050
1100
115tl
1200
1250
1300
135tl
1400
1050
1100
1150
1200
1250
1300
1350
1400
7633
7421
6927
6814
6779
6683
6656
6626
7123
7156
7222
7224
7304
7354
7417
7396
41 794
41.ct
42 794
43.ct
44 794
44 794
45 ct
45 794
0 0 0 000 tl tlgg 00tlg
0000
0000 16120 100
0000
0000 15640 100
0000
0000 18120 100
0000
0000 12400
00tlg 000tl
00tlg 000tl
00tlg 000tl
00tlg 000tl
0 000 16120
0 000 15640
0 000 18120
0 000 12400
386880
375360
434880
297600
183510
199150
217270
229670
1770031 7 64000
1768467 7 64000
1766655 7 64000
1765415 7 68000
00
00
00
00
100700 1412 1412lncrm e to24)64(953mm)
103000
110000
113000
120000
1450
1500
155tl
1600
1450
1500
1550
1600
5626
5375
7035
6893
6781
6691
47 953
48 953
48 G J
47 953 0 0 0 000 tltlgg 0Otlg
0000
0000 19530 100
0000
0000 18490 100
00tlg 000tl
00tlg 000tl
tl tlgg 19530
0 000 18490
468720
443760
249200
267690
1763462 7 72000
1761613 7 72000
00
00
PetroClassFlowTestVersion4.5.0.5
6:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTING,.IAweD2d864DOWSFlowTest.klglt4
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 4
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %22 2015/10/27 03:30:00 7.50 7.50 7952 7139 41 7.14 0.00 Other 0.000 100 0.023 03:40:00 7.67 7.67 Increase choke to 20/64 (7.94mm)24 04:00:00 8.00 8.00 7904 7090 41 7.94 0.00 Other 0.000 17.730 100 0.000 0.000 0.000 17.730 425.520 129.660 17754.16 7 62000 0.025 04:30:00 8.50 8.50 7891 7051 41 7.94 0.00 Other 0.000 100 0.026 05:00:00 9.00 9.00 7862 7029 41 7.94 0.00 Other 0.000 19.300 100 0.000 0.000 0.000 19.300 463.200 148.960 17734.86 7 64000 0.027 05:30:00 9.50 9.50 7883 7056 41 7.94 0.00 Other 0.000 100 0.028 06:00:00 10.00 10.00 7919 7103 41 7.94 0 0 0 0.00 0.000 0.000 Other 0.000 18.430 100 0.000 0.000 0.000 18.430 442.320 167.390 17716.43 7 64000 0.029 06:00:00 10.00 10.00 06:00 hrs Update
FTP= 7919SICP= 7103 kPagFlowing temperature = 41 °CChoke size = 7.94 mm ( 20/64 )Gas Rate = 0.00 10³m³Hour fluid rate = 18.43 m³/hrHour Oil rate = 0 m³/hrBSW=100%API=N/ASalinity = 64000 ppmPH =7Sand = 0%Initial Load Fluid = 17883.82 m³LFLTR = 17716.43Oil(Condensate) Produced =0m³Total Water Recovered = 167.40 m³ Daily hrs flowed = 6.00hrsCum hrs flowed = 10.00 hrsGas produced to last 6 hrs= 0.00 10³m³Cumm Gas To = 0.00 10³m³Cond Produced last 6 Hrs = 0.00 m³Cum Cond Produced = 0.00 m³Water Recovered Last 6 Hrs = 84.23 m³Total Water Recovered = 167.40 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 17716.43 m³Percentage Recovered from Initial Load = 0.93%Chokes washed in 6 hours =0Total chokes washed = 0
30 06:30:00 10.50 10.50 7633 7123 41 7.94 0.00 Other 0.000 100 0.031 07:00:00 11.00 11.00 7421 7156 41 7.94 0.00 Other 0.000 16.120 100 0.000 0.000 0.000 16.120 386.880 183.510 17700.31 7 64000 0.032 07:30:00 11.50 11.50 6927 7222 42 7.94 0.00 Other 0.000 100 0.033 08:00:00 12.00 12.00 6814 7224 43 7.94 0.00 Other 0.000 15.640 100 0.000 0.000 0.000 15.640 375.360 199.150 17684.67 7 64000 0.034 08:30:00 12.50 12.50 6779 7304 44 7.94 0.00 Other 0.000 100 0.035 09:00:00 13.00 13.00 6683 7354 44 7.94 0 0 0 0.00 0.000 0.000 Other 0.000 18.120 100 0.000 0.000 0.000 18.120 434.880 217.270 17666.55 7 64000 0.036 09:30:00 13.50 13.50 6656 7417 45 7.94 0.00 Other 0.000 100 0.037 10:00:00 14.00 14.00 6626 7396 45 7.94 0.00 Other 0.000 12.400 100 0.000 0.000 0.000 12.400 297.600 229.670 17654.15 7 68000 0.038 10:07:00 14.12 14.12 Increase choke to 24/64(9.53mm)39 10:30:00 14.50 14.50 5626 7035 47 9.53 0.00 Other 0.000 100 0.040 11:00:00 15.00 15.00 5536 6893 48 9.53 0.00 Other 0.000 19.530 100 0.000 0.000 0.000 19.530 468.720 249.200 17634.62 7 72000 0.041 11:30:00 15.50 15.50 5446 6781 48 9.53 0.00 Other 0.000 100 0.042 12:00:00 16.00 16.00 5375 6691 47 9.53 0 0 0 0.00 0.000 0.000 Other 0.000 18.490 100 0.000 0.000 0.000 18.490 443.760 267.690 17616.13 7 72000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Dale Time Cum Row Tubing
Pres
Well
CasingFlowChoke
Pres TempSns
Bshe Dg
Pres Pres
DnficeDryRowMalar
MIR Piste GasRats
TempGze
CumGas Gas
To
TolalGasRdVHBSW
Flared
DgCmn OilRale
Rnid
01Cum Water Wafer
Gain Rate
WaterGum
dume
2
loadLTRPH SalinityAPI Smd
Dd
WWlmnlddhhmmasHrs Hrs kPag kPag '0 mm '0 mm 11Fm'ld ftyay (ljm''Idm'pm'API
43 2015HOI271200001600 16001200hrsreadmg
FlowingTubmgpressure=5375kPa
ShutmCasingpressure=6691kPa
Flowingtemperature=4TC
Chokesize=24I64f953mmi
GasRate=NIAfggy
Totalguidrate=1849m'Ihr
Waterrecoveryrate=1849mWr
Condensaterate=0m'Ihr
PH=7,Satrnrty=72000ppmBSSW=fgg'I
API=NIArDSO'7SeparnmrH'S=gppmSand=g'I
DailyhrsSowed=12hrs
Cumhrsflowed=16hrs
Gasproducedtopipelinelast12hrs=0001OVP
CummGasToPipeline=000fggy
CondProducedlast12HN=Oggm'um
CondProduced=000
m'aterRecoveredlast12Hrs=20025m'otal
WaterRecovered=26769
m'nnalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1761613
m'ercentageRecoveredfromInnalLoad= 15'I
Chokeswashedin12houm=g
Totalchokeswashed=0
1230001650 1650
1300001700 1700
1330001750 1750
1400001800 1800
1430001850 1850
1500001900 1900
1530001950 1950
1600002000 2000
1630002050 2050
170000 2100 2100
173000 2150 2150
180000 2200 2200
5285 6596
5221 6504
5172 6449
5131 6397
5095 6342
5032 6303
4993 6250
4945 6212
4881 6108
4854 6063
4819 6017
4803 6002
47 G J
47 953
47 G J
47 953
48 G J
48 953
47 G J
47 953
48 G J
48 953
48 G J
50 953
0 0
0 0
0 0
000 tltlgg 0Otlg
000 tl tlgg 00tlg
000 tl tlgg 00tlg
0000
0000
0000
0000
0000
0000
0000
0000
0000
0000
0000
0000
21480
18700
19800
20940
18930
18930
100 00tlg 000tl tl tlgg
100 00tlg 000tl tl tlgg
100 00tlg 000tl tl tlgg
100 00tlg 000tl tl tlgg
100 0Otlg 0Ogtl tltlgg
100 0Otlg 0Ogtl tltlgg
21480515520 289170
18700448800 307870
19800475200 327670
20940502560 348610
18930 454320 367540
18930 454320 386470
1759465
1757595
1755615
1753521
1751628
1749735
7 80000
7 80000
7 80000
7 80000
7 82000
7 82000
02
02
03
02
02
01
PetroClassFlowTestVersion4.5.0.5
0:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTING,.IAweD2A864DIWSFlowTest.klglt5
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 5
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %43 2015/10/27 12:00:00 16.00 16.00 12:00 hrs reading
Flowing Tubing pressure = 5375 kPaShut in Casing pressure = 6691 kPaFlowing temperature = 47°CChoke size = 24/64 (9.53mm)Gas Rate = N/A 10³m³Total fluid rate =18.49 m³/hrWater recovery rate =18.49 m³/hrCondensate rate = 0 m³/hrPH =7 , Salinity = 72000 ppm, BS&W =100 %API = N/A @ 60°F, Separator H²S = 0 ppm, Sand =0 %
Daily hrs flowed = 12 hrs Cum hrs flowed = 16 hrsGas produced to pipeline last 12 hrs= 0.00 10³m³Cumm Gas To Pipeline = 0.00 10³m³ Cond Produced last 12 Hrs = 0.00 m³Cum Cond Produced = 0.00 m³Water Recovered Last 12 Hrs = 200.25 m³Total Water Recovered = 267.69 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 17616.13 m³ Percentage Recovered from Initial Load = 1.5 %Chokes washed in 12 hours=0Total chokes washed =0
44 12:30:00 16.50 16.50 5285 6596 47 9.53 0 0 0 0.00 0.000 0.000 Other 0.000 100 0.045 13:00:00 17.00 17.00 5221 6504 47 9.53 0.00 Other 0.000 21.480 100 0.000 0.000 0.000 21.480 515.520 289.170 17594.65 7 80000 0.246 13:30:00 17.50 17.50 5172 6449 47 9.53 0.00 Other 0.000 100 0.247 14:00:00 18.00 18.00 5131 6397 47 9.53 0.00 Other 0.000 18.700 100 0.000 0.000 0.000 18.700 448.800 307.870 17575.95 7 80000 0.248 14:30:00 18.50 18.50 5095 6342 48 9.53 0.00 Other 0.000 100 0.249 15:00:00 19.00 19.00 5032 6303 48 9.53 0.00 Other 0.000 19.800 100 0.000 0.000 0.000 19.800 475.200 327.670 17556.15 7 80000 0.350 15:30:00 19.50 19.50 4993 6250 47 9.53 0.00 Other 0.000 100 0.351 16:00:00 20.00 20.00 4945 6212 47 9.53 0 0 0 0.00 0.000 0.000 Other 0.000 20.940 100 0.000 0.000 0.000 20.940 502.560 348.610 17535.21 7 80000 0.252 16:30:00 20.50 20.50 4881 6108 48 9.53 0.00 Other 0.000 100 0.253 17:00:00 21.00 21.00 4854 6063 48 9.53 0.00 Other 0.000 18.930 100 0.000 0.000 0.000 18.930 454.320 367.540 17516.28 7 82000 0.254 17:30:00 21.50 21.50 4819 6017 48 9.53 0.00 Other 0.000 100 0.255 18:00:00 22.00 22.00 4803 6002 50 9.53 0 0 0 0.00 0.000 0.000 Other 0.000 18.930 100 0.000 0.000 0.000 18.930 454.320 386.470 17497.35 7 82000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Dale Time Cum Row Tubing
Pres
Cming
Pres
FlowChokeBshe Dg
TempSns Pres Pres
MIR
Temp
GasRatsCumGasGas TolalGasRdVdBSW
To Flared
OIGanOilRale OlCum Water
Gain
WaterCumloarlLTRPH SalinilyAPI
WWfmnfddhhmmssHrs kPag kPag '0 mm kPag kPa mm ffynyid ffpm'tyay(ljm'''Idm'pm'API
2015HOI271800002200 22001800hrsreadmg
FlowingTubmgpressure=4803kPa
ShutmCasingpressure=6002kPa
Flowingtemperature=5tl'0
Chokesize=24I64I953mmi
GasRate=NIAfgVP
TotaHluidrate=1874 m'lhr
Waterrecoveryrate=1874 mWr
Condensaterate=0m'Ihr
PH=7, Satrnrty=120000ppmBSSW=f00%
API=NIArDSS'7SeparnmrH'S=gppmSand=g'I
DailyhrsSowed=lghrs
Cumhrsflowed=22hrs
Gasproducedtopipelinelast18hrs=0001SVP
CummGasToPipeline=000fgVP
CondProducedlastlBHN=gggm'um
CondProduced=000
m'aterRecoveredlast18Hrs=31903m'otal
WaterRecovered=38647
m'nnalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1749735
m'ercentageRecoveredfromInnalLoad= 2 17%
Chokeswashedin18bourn=g
Totalchokeswashed=0
183000 2250
190000 2300
193000 2350
200000 2400
203000 2450
210000 2500
213000 2550
220000 2600
223000 2650
230000 2700
233000 2750
2015HOI280000002800
000000 2800
2250 4777
2300 4837
2350 4676
2400 4637
2450 4596
2500 4556
2550 4516
2600 4494
2650 4463
2700 4437
2750 4398
2800 4436
2800H2Spullgppm
5975 48
5977 48
5904 47
5878 46
5855 47
5833 46
5807 46
5790 46
5769 45
5762 45
5743 45
5764 46
sir
sir
sir
sir
sir
sir
0000
0000 17800 100
0000
0000 18900 100
0000
0000 19080 100
0000
0000 17830 100
0000
0000 17810 100
0000
0000 17410 100
00tlg
00tlg
00tlg
00tlg
00tlg
00tlg
0ggtl
0ggtl
0ggtl
0ggtl
0ggtl
0ggtl
0 000 17800
0 000 18900
0 000 19080
0 000 17830
0000 17810
tl tlgg 17410
427200
453600
457920
427920
427440
417840
404270
423170
442250
460080
477890
495300
1747955 7 90000
1746065 7 90000
17441577 90000
1742374 7 90000
1740593 7 90000
1738852 7 90000
01
01
01
01
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSANIDOLLCOWELLDATASERVICESIPRODUCTIONTESTING,.IAweD2A864DIWSFlowTest.klglt6
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 6
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %56 2015/10/27 18:00:00 22.00 22.00 18:00 hrs reading
Flowing Tubing pressure = 4803 kPaShut in Casing pressure = 6002 kPaFlowing temperature = 50°CChoke size = 24/64 (9.53mm)Gas Rate = N/A 10³m³Total fluid rate =18.74 m³/hrWater recovery rate =18.74 m³/hrCondensate rate = 0 m³/hrPH =7 , Salinity = 120000 ppm, BS&W =100 %API = N/A @ 60°F, Separator H²S = 0 ppm, Sand =0 %
Daily hrs flowed = 18 hrs Cum hrs flowed = 22 hrsGas produced to pipeline last 18 hrs= 0.00 10³m³Cumm Gas To Pipeline = 0.00 10³m³ Cond Produced last 18 Hrs = 0.00 m³Cum Cond Produced = 0.00 m³Water Recovered Last 18 Hrs = 319.03 m³Total Water Recovered = 386.47 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 17497.35 m³ Percentage Recovered from Initial Load = 2.17%Chokes washed in 18 hours=0Total chokes washed =0
57 18:30:00 22.50 22.50 4777 5975 48 9.53 0.00 Other 0.000 100 0.158 19:00:00 23.00 23.00 4837 5977 48 9.53 0.00 Other 0.000 17.800 100 0.000 0.000 0.000 17.800 427.200 404.270 17479.55 7 90000 0.159 19:30:00 23.50 23.50 4676 5904 47 9.53 0.00 Other 0.000 100 0.160 20:00:00 24.00 24.00 4637 5878 46 9.53 0.00 Other 0.000 18.900 100 0.000 0.000 0.000 18.900 453.600 423.170 17460.65 7 90000 0.161 20:30:00 24.50 24.50 4596 5855 47 9.53 0.00 Other 0.000 100 0.162 21:00:00 25.00 25.00 4556 5833 46 9.53 0.00 Other 0.000 19.080 100 0.000 0.000 0.000 19.080 457.920 442.250 17441.57 7 90000 0.163 21:30:00 25.50 25.50 4516 5807 46 9.53 0.00 Other 0.000 100 0.164 22:00:00 26.00 26.00 4494 5790 46 9.53 0.00 Other 0.000 17.830 100 0.000 0.000 0.000 17.830 427.920 460.080 17423.74 7 90000 0.165 22:30:00 26.50 26.50 4463 5769 45 9.53 0.00 Other 0.000 100 0.166 23:00:00 27.00 27.00 4437 5762 45 9.53 0.00 Other 0.000 17.810 100 0.000 0.000 0.000 17.810 427.440 477.890 17405.93 7 90000 0.167 23:30:00 27.50 27.50 4398 5743 45 9.53 0.00 Other 0.000 100 0.168 2015/10/28 00:00:00 28.00 28.00 4436 5764 46 9.53 0.00 Other 0.000 17.410 100 0.000 0.000 0.000 17.410 417.840 495.300 17388.52 7 90000 0.169 00:00:00 28.00 28.00 H2S pull 0ppm.
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Dale Time Cum Row Tubing
Pres
Well
Owing
Pres
Flow
Temp
ChokeBabe Dg
Sws Pres Pres
DnficeDryRowMalar
WR We GasRats0 mGas
TempGze
Gas
To
TraaiGasRdydSSWDilgan
Flared
GilRale 01Cum
Rnid
Wstw
Gain
WaterGuminertLTRPH SalinilyAPI
dume
2
WWfamfddhhmmss
70 2015HOI28000000
Hrs Hrs kPag kPag
2800 28000000hrsreadmg
mm yPag kpe '0 mm Ryayid ffpay ftyay (I)m' m''Idm'pm'API
FlowingTubmgpressure=4436kPa
ShutmCasingpressure=5764kPa
Flowingtemperature=46'0
Chokesize=24I64 )953mm)
GasRate=NIAIOMP
TotaHluidrate=1741 m'Ihr
Waterrecoveryrate=1741 mWr
Condensaterate=0m'Ihr
PH=T,Salinity=900XppmBSBW=IOO'4
PPI=N)hrDSO'7SeparatorH'S=gppm,Sand=0'4
Dailyhrsgowed=24hrs
Cumhrsflowed=28hrs
Gasproducedtopipelinelast24hrs=00010577
CummGasToPipeline=000IOMP
CondProducedlast24HN=Oggm'um
CondProduced=000m'ater
Recoveredlast24Hrs=42786m'otal
WaterRecovered=49530
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1738852
m'ercentageRecoveredfromInmalLoad= 27Mb
Chokeswashedin24bourn=g
Totalchokeswashed=0
003000
010000
013000
020000
2850 2850 4330 5726 43
2900 2900 4309 5717 43
2950 2950 4284 5708 43
3000 3000 4258 5709 43
cBr
cBr
0000
0000 14320
0000
0000 16880
100 0Otlg 0Ogtl
100 0Otlg 0Ogtl
0 000 14320 343680 509620
0 000 16880 405120 526500
1737420 7
1735732 7
96000
96000
01
01rrrsrrr'r030000
033000
040000
043000
3100 3100 4203 5705 45
315tl 3150 4194 5713
3200 3200 4166 5722 45
3250 3250 4179 5711 46
cBr
cBr
0000 17620
0000
0000 14500
0000
100 0Otlg 0Ogtl
100 0Otlg 0Ogtl
tltlgg 17620 422880 544120
tltlgg 14500 348000 558620
1733970 7
1732520 7
96000
96000
01
01
043600 3260 3260Increasechoketo26)6mm)4)1032
050000
053000
060000
063000
070000
3300 3300 4152 5701 45
3350 3350 4178 5778 45
3400 3400 4169 5712 45
3450 3450 4130 5854 46
3500 3500 4226 5926 45
1032
1032
1032
0 0 0 000 tl tlgg 00tlg
0000 16050
0000
0000 17520
0000
0000 16320
100 0Otlg 0Ogtl
100 0Otlg 0Ogtl
100 0Otlg 0Ogtl
0 000 16050 385200 574670
0 000 17520 420480 592190
0 000 16320 391680 608510
173tl915 7
17291637
1727531 7
98000
98000
98000
01
01
070000 3500 3500Increasechoketo28)6 mm)4)1I 11
073000
080000
083000
090000
093000
100000
100100
103000
3550 3550 4308 5966 46
3600 3600 4313 6030 45
3650 3650 4283 6091 44
3700 3700 4296 6155 45
3750 3T50 4212 6218 45
3800 3800 4216 6279 44
3802 3802Increasechoketo30)64)1191mm)
3850 3850 4262 6243 45 1191
0 0 0 000 tltlgg 0Otlg
0000
0000 19130
0000
0000 15300
0000
0000 15890
0000
100 0Otlg 0Ogtl
100 0Otlg 0Ogtl
100 0Otlg 0Ogtl
0 000 19130 459120 627640
tltlgg 15300 367200 642940
tltlgg 15890 381360 658830
1725618 7
17240887
17224997
98000
IOOXO
IOOXO
01
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTING,.IAweD24864DIWBFlowTest.klglt7
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 7
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %70 2015/10/28 00:00:00 28.00 28.00 00:00 hrs reading
Flowing Tubing pressure = 4436 kPaShut in Casing pressure = 5764 kPaFlowing temperature = 46°CChoke size = 24/64 (9.53mm)Gas Rate = N/A 10³m³Total fluid rate =17.41 m³/hrWater recovery rate =17.41 m³/hrCondensate rate = 0 m³/hrPH =7 , Salinity = 90000 ppm, BS&W =100 %API = N/A @ 60°F, Separator H²S = 0 ppm, Sand =0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 28 hrsGas produced to pipeline last 24 hrs= 0.00 10³m³Cumm Gas To Pipeline = 0.00 10³m³ Cond Produced last 24 Hrs = 0.00 m³Cum Cond Produced = 0.00 m³Water Recovered Last 24 Hrs = 427.86 m³Total Water Recovered = 495.30 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 17388.52 m³ Percentage Recovered from Initial Load = 2.76%Chokes washed in 24 hours=0Total chokes washed =0
71 00:30:00 28.50 28.50 4330 5726 43 9.53 0.00 Other 0.000 100 0.172 01:00:00 29.00 29.00 4309 5717 43 9.53 0.00 Other 0.000 14.320 100 0.000 0.000 0.000 14.320 343.680 509.620 17374.20 7 96000 0.173 01:30:00 29.50 29.50 4284 5708 43 9.53 0.00 Other 0.000 100 0.174 02:00:00 30.00 30.00 4258 5709 43 9.53 0.00 Other 0.000 16.880 100 0.000 0.000 0.000 16.880 405.120 526.500 17357.32 7 96000 0.175 02:30:00 30.50 30.50 4219 5700 42 9.53 0.00 Other 0.000 100 0.176 03:00:00 31.00 31.00 4203 5705 45 9.53 0.00 Other 0.000 17.620 100 0.000 0.000 0.000 17.620 422.880 544.120 17339.70 7 96000 0.177 03:30:00 31.50 31.50 4184 5713 44 9.53 0.00 Other 0.000 100 0.178 04:00:00 32.00 32.00 4166 5722 45 9.53 0.00 Other 0.000 14.500 100 0.000 0.000 0.000 14.500 348.000 558.620 17325.20 7 96000 0.179 04:30:00 32.50 32.50 4179 5711 46 9.53 0.00 Other 0.000 100 0.180 04:36:00 32.60 32.60 Increase choke to 26/64(10.32mm)81 05:00:00 33.00 33.00 4152 5701 45 10.32 0.00 Other 0.000 16.050 100 0.000 0.000 0.000 16.050 385.200 574.670 17309.15 7 98000 0.182 05:30:00 33.50 33.50 4178 5778 45 10.32 0.00 Other 0.000 100 0.183 06:00:00 34.00 34.00 4169 5712 45 10.32 0 0 0 0.00 0.000 0.000 Other 0.000 17.520 100 0.000 0.000 0.000 17.520 420.480 592.190 17291.63 7 98000 0.184 06:30:00 34.50 34.50 4130 5854 46 10.32 0.00 Other 0.000 100 0.185 07:00:00 35.00 35.00 4226 5926 45 10.32 0.00 Other 0.000 16.320 100 0.000 0.000 0.000 16.320 391.680 608.510 17275.31 7 98000 0.186 07:00:00 35.00 35.00 Increase choke to 28/64(11.11mm)87 07:30:00 35.50 35.50 4308 5966 46 11.11 0.00 Other 0.000 100 0.188 08:00:00 36.00 36.00 4313 6030 45 11.11 0.00 Other 0.000 19.130 100 0.000 0.000 0.000 19.130 459.120 627.640 17256.18 7 98000 0.189 08:30:00 36.50 36.50 4283 6091 44 11.11 0.00 Other 0.000 100 0.190 09:00:00 37.00 37.00 4296 6155 45 11.11 0.00 Other 0.000 15.300 100 0.000 0.000 0.000 15.300 367.200 642.940 17240.88 7 100000 0.191 09:30:00 37.50 37.50 4212 6218 45 11.11 0.00 Other 0.000 100 0.192 10:00:00 38.00 38.00 4216 6279 44 11.11 0 0 0 0.00 0.000 0.000 Other 0.000 15.890 100 0.000 0.000 0.000 15.890 381.360 658.830 17224.99 7 100000 0.193 10:01:00 38.02 38.02 Increase choke to 30/64(11.91mm)94 10:30:00 38.50 38.50 4262 6243 45 11.91 0.00 Other 0.000 100 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Dale Time Cum Row Tubing
Pres
CmingFlow
Pres Temp
Qmks
Sws
Bshe Dg MIR Piste
Pres Pres TempGze
GasRats CumGas Gas
To
TotalGas RdVd
Flared
BSWDgCmn OilRale OiGum Water WaterWaterGumleadLTRPH
Gain Rate
SalinilyAPI Smd
CM
WWlmnlddhhmmss
95 2015HOI281100003900 3900
kPag
4215
kPag '0
6283 46
mm
1191
kPag kPa '0 mm flyayid I'm' tlap (I)m'
000 16260 100 00tlg
m'Id
0Ogtl
m'l
tlgg 16260390240 67509017208737
ppm 'API
IOOXO 01
110100 3902 3902Increasechoketo32)64)1270mm)
120000
120000
4000
4000
4000 3799 6284 46 1270 0 0 0 000 0000 0000 e 0000 20750 100 0000 0000 0000 20750498000 69584017187987 IOOXO 01
40001200hrsreadmg
FlowingTubmgpressure=3799kPa
ShutmCasingpressure=6284kPa
Flowingtemperature=44'0
Chokesize=33'64)1270mml
GasRate=NIAIghy
Totalguidrate=2075m'Ihr
Waterrecoveryrate=2075m'Ihr
Condensaterate=0m'Ihr
PH=t,Salinity=IOOXppmBSBW=IOO'I
API=N)hrDBO'FSeparatorH'S=gppm,Sand=glg
DailyhrsBowed=12hrs
Cumhrsflowed=40hrs
Dailygasproducedtoflarelast12hrs=00010'm'um
gasProducedtoflare=0 000
10'rn'ondProducedlast12hrs=
000m'um
CondProduced=000
m'aterRecoveredlast12Hrs=20054m'otal
WaterRecovered=69584
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 171St98
m'ercentageRecoveredfromInmalLoad= 39 'I
Chokeswashedin10bourn=g
Totalchokeswashed=0
101
107
123000
130000
133000
140000
143000
150000
153000
160000
4050
4100
4150
4200
4250
4300
4350
4400
4050 3780 6320
4100 3689 6388
4150 3633 6402
4200 3539 6432
4250 3523 6467
4300 3535 6507
4350 3502 6548
4400 3520 6576
45
45 1270
45
45 1270
46
45 1270
46 1270
0000
0000
0000
0000
0000
0000
0000
0000
16560
19390
17740
17310
0Otlg 0Ogtl tltlgg
100 0Otlg 0Ogtl tltlgg
100 00tlg 000tl tl tlgg
100 0Otlg 0Ogtl tltlgg
16560
19390
17740
1731tl
397440
465360
425760
415440
712400
731790
749530
766840
1717142
1715203
1713429
1711698
7 106XO
7 106XO
7 106XO
01
01
01
160100 4402 e toSHB4402Increasechok 4i1349mm)
110
163000
170000
4450
4500
4450 3428 6565
4500 3460 6583
45
46 1349
0000
0000 20020 100 00tlg 000tl tl tlgg 20020480480 786860 1709696 7 106XO439 01
170000 4500 tosurface4500Condensate API439@60 0 8065GravityFSpecdic
113
114
115
116
117
118
119
180000
183000
190000
193000
200000
203000
210000
4600
4650
4700
4750
4800
4850
4900
4600 3330 6638
4650 3310 6611
4700 3319 6621
4750 3301 6774
4800 3305 6809
4850 3310 6852
4900 3303 6811
45 1349
45
45 1349
46 1349
46
46 1349
0000
0000
0000
0000
0000
0000
0000
19800
17Img
18030
20350
98 0396 9504 0 396
98 0356 8544 0 752
97 0541 12982 I 293
97 0611 14652 I 903
19404
174M
17489
19739
465696
418656
419738
473748
806264
823708
841197
860937
1707756
1706011
1704262
1702288
7 106XO
7 106XO
7 108XO
7 108XO
01
01
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTING,.IAweD2XSSHIOWSFlowTest.RIQSIB
ProdoctionTestingASchlumbergerCtmpany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 8
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %95 2015/10/28 11:00:00 39.00 39.00 4215 6283 46 11.91 0.00 Other 0.000 16.260 100 0.000 0.000 0.000 16.260 390.240 675.090 17208.73 7 100000 0.196 11:01:00 39.02 39.02 Increase choke to 32/64(12.70mm)97 11:30:00 39.50 39.50 4030 6266 46 12.70 0.00 Other 0.000 100 0.198 12:00:00 40.00 40.00 3799 6284 46 12.70 0 0 0 0.00 0.000 0.000 Other 0.000 20.750 100 0.000 0.000 0.000 20.750 498.000 695.840 17187.98 7 100000 0.199 12:00:00 40.00 40.00 12:00 hrs reading
Flowing Tubing pressure = 3799 kPaShut in Casing pressure = 6284 kPaFlowing temperature = 44°CChoke size = 32/64 (12.70mm)Gas Rate = N/A 10³m³Total fluid rate =20.75 m³/hrWater recovery rate =20.75 m³/hrCondensate rate = 0 m³/hrPH =7 , Salinity = 10000 ppm, BS&W =100 %API = N/A @ 60°F, Separator H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 12 hrs Cum hrs flowed = 40 hrsDaily gas produced to flare last 12 hrs = 0.00 10³m³Cum gas Produced to flare= 0.000 10³m³Cond Produced last 12 hrs = 0.00 m³Cum Cond Produced = 0.00 m³Water Recovered Last 12 Hrs = 200.54 m³Total Water Recovered = 695.84 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 17187.98 m³ Percentage Recovered from Initial Load = 3.9 %Chokes washed in 10 hours=0Total chokes washed =0
100 12:30:00 40.50 40.50 3780 6320 45 12.70 0.00 Other 0.000 100 0.1101 13:00:00 41.00 41.00 3689 6388 45 12.70 0.00 Other 0.000 16.560 100 0.000 0.000 0.000 16.560 397.440 712.400 17171.42 0.1102 13:30:00 41.50 41.50 3633 6402 45 12.70 0.00 Other 0.000 100 0.1103 14:00:00 42.00 42.00 3539 6432 45 12.70 0.00 Other 0.000 19.390 100 0.000 0.000 0.000 19.390 465.360 731.790 17152.03 7 106000 0.1104 14:30:00 42.50 42.50 3523 6467 46 12.70 0.00 Other 0.000 100 0.1105 15:00:00 43.00 43.00 3535 6507 45 12.70 0.00 Other 0.000 17.740 100 0.000 0.000 0.000 17.740 425.760 749.530 17134.29 7 106000 0.1106 15:30:00 43.50 43.50 3502 6548 44 12.70 0.00 Other 0.000 100 0.1107 16:00:00 44.00 44.00 3520 6576 46 12.70 0.00 Other 0.000 17.310 100 0.000 0.000 0.000 17.310 415.440 766.840 17116.98 7 106000 0.1108 16:01:00 44.02 44.02 Increase choke to 34/64(13.49mm)109 16:30:00 44.50 44.50 3428 6565 45 12.70 0.00 Other 0.000 100 0.1110 17:00:00 45.00 45.00 3460 6583 46 13.49 0.00 Other 0.000 20.020 100 0.000 0.000 0.000 20.020 480.480 786.860 17096.96 7 106000 43.9 0.1111 17:00:00 45.00 45.00 Condensate to surface, API 43.9 @ 60°F Specific Gravity 0.8065112 17:30:00 45.50 45.50 3430 6601 44 13.49 0.00 Other 0.000 100 0.1113 18:00:00 46.00 46.00 3330 6638 45 13.49 0.00 Other 0.000 19.800 98 0.396 9.504 0.396 19.404 465.696 806.264 17077.56 7 106000 0.1114 18:30:00 46.50 46.50 3310 6611 45 13.49 0.00 Other 0.000 98 0.1115 19:00:00 47.00 47.00 3319 6621 45 13.49 0.00 Other 0.000 17.800 98 0.356 8.544 0.752 17.444 418.656 823.708 17060.11 7 106000 0.1116 19:30:00 47.50 47.50 3301 6774 44 13.49 0.00 Other 0.000 98 0.1117 20:00:00 48.00 48.00 3305 6809 46 13.49 0.00 Other 0.000 18.030 97 0.541 12.982 1.293 17.489 419.738 841.197 17042.62 7 108000 0.1118 20:30:00 48.50 48.50 3310 6852 46 13.49 0.00 Other 0.000 97 0.1119 21:00:00 49.00 49.00 3303 6811 46 13.49 0.00 Other 0.000 20.350 97 0.611 14.652 1.903 19.739 473.748 860.937 17022.88 7 108000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well DnficeDryRowMalar Rnid dume
2
Time Cum Row Tubing0 ming
Pres Pres
FlowChokeBshe Dg MIR
TempSws Pres Pres Temp
GasRats CumGas Gas TolalGasRdVHBSW
To Flared
WIGanOilRale OlCum Water
Gain
WaterCumloarlLTRPH SalinilyAPI
121
WWfmnfdd
2015HOI28
hhmmss
213000
220000
Hrs Hrs
4950 4950
5000 5000
kPag kPag
3292 6931
3316 6960
'0 mm kPag kPa '0
46
43 1349
mm IIFm'ld tipm'tyap(ljm'
000
0000 18490 98
m''Id
0370 8875
m'
273 18120 434885 879057 1700476 7
ppm 'API
108XO451 01
220000
223000
5000 5000
5050 5050
APIofcoeds n API=45I rg60'6SpeoficGnsatetake ravily
3310 6912
08013
0000
124
2015HOI29
230000
233000
000000
000000
5100 5100
515tl 5150
5200 5200
5200 5200
3294 7027
3293 7061
3219 7078
2400Irmmsdiilg
43 1349
44 1349 0 0 0 000 tl tlgg 0gtlg
0000 21400 97
0000
0000 20560 97
0642 15408
0617 14803
2 915 20758
3532 19943
498192
478637
899815 1698401 7
91975816964067
108XO
108XO
01
01
FlowingTubmgpressure=3219kPa
ShutmCasingpressure=7078kPa
Flowingtemperature=44'0
Chokesize=34I64i1349mml
GasRate=NIAIOVF
Totalguidrate=2056 m'Ihr
Waterrecoveryrate=2056m'Ihr
Condensaterate=062m'Ihr
PH=T,Salinity=IOBXOppm868W=IOOH
Apl=451@60'7,SeparatorH'S=gppmSand=01 'I
Dailyhrsgowed=24hrs
Cumhrsflowed=52hrs
Dailygasproducedtoflarelast24hrs=00010'm'um
gasProducedtoflare=0 00010'rn'ond
Producedlast24hrs= 353m'um
CondProduced=353m'ater
Recoveredlast24Hrs=42446m'otal
WaterRecovered=91976
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1696406
m'ercentageRecoveredfromInmalLoad= 5 14'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
003000
010000
5250 5250
5300 5300
3267 7123 45
3466 7144 44 1349
0000
0000 19450 95 0972 23340 4 504 18478443460 938236 1694558 108XO 01
131 020000
020000
5400 5400
5400 5400
3418 7195
APIofcondensatetakenAPI
1349
ificG60'FSpec451rg ravily08013H28pullOppmbydraeger
0000 18820 95 0941 22584 5445 17879429096 956115 1692771 108XO451 01
030000 5500 5500 3392 7267 43 1349 0000 19680 95 0984 23616 6430 18696 448704 974810 1690901 108XO 01
137
040000
043000
5600 5600
5650 5650
3410 7329 43
3448 7416 44
1349 0000
0000
17890 95 0895 21468 7324 16996 407892 991806 1689201 108XO 01
141
050000
052400
060000
5700 5700
5740 5740
5800 5800
3442 7436 44 1349 345
3439 7449 44 1349
UreOrlSe tumdrDWeathertordPVTHighPlass mplecap
0000
0524hrs-Cytinder¹X04
tl tlgg
8Cylinde
00tlg
r¹00029
0000
0000
18920
19100
95 0946
95 0955
22704 8270
22920 9225
17974 431376 1009780 1687404
18145435480 1027925 1685590
118XO
110XO
01
451 01
142 060000 5800 5800APIofcondensatetakenAPI=45I rg60'FSpeoficGravity=0 8013H28pullOppmbydraeger
PetroClassFlowTestVersion4.5.0.5
0:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTING,.IAweD24864DIWSFlowTest.klglt9
ProdnctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 9
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %120 2015/10/28 21:30:00 49.50 49.50 3292 6931 46 13.49 0.00 Other 0.000 97 0.1121 22:00:00 50.00 50.00 3316 6960 43 13.49 0.00 Other 0.000 18.490 98 0.370 8.875 2.273 18.120 434.885 879.057 17004.76 7 108000 45.1 0.1122 22:00:00 50.00 50.00 API of condensate taken. API = 45.1 @ 60°F , Specific Gravity = 0.8013.123 22:30:00 50.50 50.50 3310 6912 44 13.49 0.00 Other 0.000 98 0.1124 23:00:00 51.00 51.00 3294 7027 43 13.49 0.00 Other 0.000 21.400 97 0.642 15.408 2.915 20.758 498.192 899.815 16984.01 7 108000 0.1125 23:30:00 51.50 51.50 3293 7061 44 13.49 0.00 Other 0.000 97 0.1126 2015/10/29 00:00:00 52.00 52.00 3219 7078 44 13.49 0 0 0 0.00 0.000 0.000 Other 0.000 20.560 97 0.617 14.803 3.532 19.943 478.637 919.758 16964.06 7 108000 0.1127 00:00:00 52.00 52.00 24:00 hrs reading
Flowing Tubing pressure = 3219 kPaShut in Casing pressure = 7078 kPaFlowing temperature = 44°CChoke size = 34/64 (13.49mm)Gas Rate = N/A 10³m³Total fluid rate =20.56 m³/hrWater recovery rate =20.56 m³/hrCondensate rate = 0.62 m³/hrPH =7 , Salinity = 108000 ppm, BS&W =100 %API = 45.1 @ 60°F, Separator H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 52 hrsDaily gas produced to flare last 24 hrs = 0.00 10³m³Cum gas Produced to flare= 0.000 10³m³Cond Produced last 24 hrs = 3.53 m³Cum Cond Produced = 3.53 m³Water Recovered Last 24 Hrs = 424.46 m³Total Water Recovered = 919.76 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16964.06 m³ Percentage Recovered from Initial Load = 5.14 %Chokes washed in 24 hours=0Total chokes washed =0
128 00:30:00 52.50 52.50 3267 7123 45 13.49 0.00 Other 0.000 97 0.1129 01:00:00 53.00 53.00 3466 7144 44 13.49 0.00 Other 0.000 19.450 95 0.972 23.340 4.504 18.478 443.460 938.236 16945.58 7 108000 0.1130 01:30:00 53.50 53.50 3442 7156 44 13.49 0.00 Other 0.000 95 0.1131 02:00:00 54.00 54.00 3418 7195 44 13.49 0.00 Other 0.000 18.820 95 0.941 22.584 5.445 17.879 429.096 956.115 16927.71 7 108000 45.1 0.1132 02:00:00 54.00 54.00 API of condensate taken. API = 45.1 @ 60°F , Specific Gravity = 0.8013, H2S pull 0ppm by draeger.133 02:30:00 54.50 54.50 3453 7231 42 13.49 0.00 Other 0.000 95 0.1134 03:00:00 55.00 55.00 3392 7267 43 13.49 0.00 Other 0.000 19.680 95 0.984 23.616 6.430 18.696 448.704 974.810 16909.01 7 108000 0.1135 03:30:00 55.50 55.50 3423 7317 43 13.49 0.00 Other 0.000 95 0.1136 04:00:00 56.00 56.00 3410 7329 43 13.49 0.00 Other 0.000 17.890 95 0.895 21.468 7.324 16.996 407.892 991.806 16892.01 7 108000 0.1137 04:30:00 56.50 56.50 3448 7416 44 13.49 0.00 Other 0.000 95 0.1138 05:00:00 57.00 57.00 3442 7436 44 13.49 345 0.00 Other 0.000 18.920 95 0.946 22.704 8.270 17.974 431.376 1009.780 16874.04 7 118000 0.1139 05:24:00 57.40 57.40 “Weatherford PVT High Pressure Oil Sample captured @ 05:24 hrs – Cylinder # 0004 & Cylinder # 00029140 05:30:00 57.50 57.50 3416 7446 44 13.49 0.00 Other 0.000 95 0.1141 06:00:00 58.00 58.00 3439 7449 44 13.49 0 0 0 0.00 0.000 0.000 Other 0.000 19.100 95 0.955 22.920 9.225 18.145 435.480 1027.925 16855.90 7 110000 45.1 0.1142 06:00:00 58.00 58.00 API of condensate taken. API = 45.1 @ 60°F , Specific Gravity = 0.8013, H2S pull 0ppm by draeger.
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
TubingOwing
Pres Pres
FlowChokeGabe
TempSwe Pres
Dg
Pres
OnficeDryRowMelar
MIR
Temp
CumGas Gas
To
TotalGas
Flared
RdVdBSWOIGanOilRale OIGum
Rnid
Watw
Gain
WahuWaterGum
IMH
inertLTRPH SellrsV
dume
2
API Smd
Cd
WW)amfdd
f¹3 2015IIOI29
hhmmasHrs Hrs
0600005800 5800
kPag kPag
600hrsrenting
'0 mm kPart mm lipm'id ii)m'''Idm'APIFlowingTubmgpressure=3439kPa
ShutmCasingpressure=7449kPa
Flowingtemperature=44'0
Chokesize=34I64 )1349mm)
GasRate=NIAIOVP
TotaHluidrate=1910 m'Ihr
Waterrecoveryrate=1 910mWr
Condensaterate=092m'Ihr
PH=t,Salinity=IIOXOppmBSBW=95S
Apl=451@60'F,SeparatorH'S=gppmSand=01 'I
DailyhrsBowed=6 hrs
Cumhrsflowed=58hrs
Dailygasproducedtoflarelast6 hrs=000IOVP
CumgasProducedtoflare=0 00010'rn'ond
Producedlast6 hrs= 569m'um
CondProduced=923m'ater
Recoveredlast6 Hrs= 10817
m'otal
WaterRecovered=102t92
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLetttoRecover= 1685590
m'ercentageRecoveredfromInmalLoad= 574'I
Chokeswashedin6 hours=g
Totalchokeswashed=0
147
0630005850 5850
0700005900 5900
0730005950 5950
080000 6000 6000
0830006050 6050
090000 6100 6100
BN4 7501
3443 7602
3481 7664
31X 7718
3212 7771
3428 7792
1349
1349
1349 0 0 000 tl tlgg 00tlg
0000
0000 18920
0000
0000 19100
0000
Flare 0000 20790
95 0946 22704
95 0955 22920
95 I 040 24948
10171
11 126
12166
17974 431376
18145435480
19750474012
1045899 1683792 110XO
1064044 1681978 110XO
10837941680003 110XO
01
01
01
151
157
093000 6150 6150
100000 6200 6200
103000 6250 6250
1100006300 6300
1130006350 6350
120000 6400 6400
123000 6450 6450
130000 6500 6500
3670 7846
3890 7859
3497 7913
3339 7975
3428 8021
3581 8046
3560 8121
3502 8174
2206 4
1349 1993 7
1931 6
1349 1800 4
1931 4
1349 2068 4
2193 4
1349 2255 3
1905
1905
1905
1905
1905
6 390
8281
7838
6 132
6 385
6 357
6 005
0133
0286
0454
0599
0725
0854
0987
1116
Flze 0133 19360
Flare 0286
Flee 0454 19950
Flare 0599
Flee 0725 18540
Flare 0854
Ftze 098T 16010
Flare 1116
95 0968 Ri464
95 0998 23940
95 0927 22248
92 1 281 X739
13134
14131
15058
16339
18392 882816
18952 454860
17613422712
14729353501
110218616781637 116XO
11211391676268 7 118XO
1138752 1674507 7 120XO
1153481 1673034 7 120XO
01
01
01
01
161
133000 6550 6550
133000 6550 6550
133100 6552 6552
3570 8206 2296 4 6510 1246Ftze 1 246 6950
HighPressureOilSamplescaptured@1330hm-Cylinder¹15001164088Cylinder¹1500116410
Increasechoketo36I64)1429mm)
72 I 946 Ri704 18285 5004120096115848516725337 120XO 01
162 133100 6552 6552 60'FSpeoficGravity=0 t905APIofcondensatetakenAPI=475@
167
1400006600 6600
1430006650 6650
150000 6700 6T00
153000 6750 6T50
160000 6800 6800
3735
3927
3500
3222
3276
8232 44
8259 43
8314 44
8357 44
8413 44
1429
1429
1429
1917 10 37 1905
2068 10 37
1931 9 37 1905
2082 I 37
2013 2 37 1905
9521 1 413Ftze 1 413
10146 1 618Flare 1 618
9308 1 820Flee 1 820
3 189 1 951Flare 1 951
4 952 2035Flee 2035
6610
6100
6820
I 586
1 647
1 705
76147 19871 5024
39528 21518 4453
X920 23223 5 115
241133
106872
122760
1163509
1167962
1173077
1672031 7
1671586 7
1671074 7
120XO
120XO
120XO
01
02
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTING,.IAweD24864DOWBFlowTestlgbggat)0
ProdoctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 10
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %143 2015/10/29 06:00:00 58.00 58.00 6:00 hrs reading
Flowing Tubing pressure = 3439 kPaShut in Casing pressure = 7449 kPaFlowing temperature = 44°CChoke size = 34/64 (13.49mm)Gas Rate = N/A 10³m³Total fluid rate = 19.10 m³/hrWater recovery rate = 19.10 m³/hrCondensate rate = 0.92 m³/hrPH =7 , Salinity = 110000 ppm, BS&W = 95 %API = 45.1 @ 60°F, Separator H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 6 hrs Cum hrs flowed = 58 hrsDaily gas produced to flare last 6 hrs = 0.00 10³m³Cum gas Produced to flare= 0.000 10³m³Cond Produced last 6 hrs = 5.69 m³Cum Cond Produced = 9.23 m³Water Recovered Last 6 Hrs = 108.17 m³Total Water Recovered = 1027.92 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16855.90 m³ Percentage Recovered from Initial Load = 5.74 %Chokes washed in 6 hours=0Total chokes washed =0
144 06:30:00 58.50 58.50 3444 7501 45 13.49 0.00 Other 0.000 95 0.1145 07:00:00 59.00 59.00 3443 7602 45 13.49 0.00 Other 0.000 18.920 95 0.946 22.704 10.171 17.974 431.376 1045.899 16837.92 110000 0.1146 07:30:00 59.50 59.50 3481 7664 44 13.49 0.00 Other 0.000 95 0.1147 08:00:00 60.00 60.00 3196 7718 45 13.49 0.00 Other 0.000 19.100 95 0.955 22.920 11.126 18.145 435.480 1064.044 16819.78 110000 0.1148 08:30:00 60.50 60.50 3212 7771 44 13.49 0.00 Other 0.000 95 0.1149 09:00:00 61.00 61.00 3428 7792 45 13.49 0 0 0 0.00 0.000 0.000 Flare 0.000 20.790 95 1.040 24.948 12.166 19.750 474.012 1083.794 16800.03 110000 0.1150 09:30:00 61.50 61.50 Meter in service 0.750151 09:30:00 61.50 61.50 3670 7846 45 13.49 2206 4 34 19.05 6.390 0.133 Flare 0.133 19.360 95 0.968 46.464 13.134 18.392 882.816 1102.186 16781.63 7 116000 0.1152 10:00:00 62.00 62.00 3890 7859 45 13.49 1993 7 34 19.05 8.281 0.286 Flare 0.286 95 0.1153 10:30:00 62.50 62.50 3497 7913 46 13.49 1931 6 35 19.05 7.838 0.454 Flare 0.454 19.950 95 0.998 23.940 14.131 18.952 454.860 1121.139 16762.68 7 118000 0.1154 11:00:00 63.00 63.00 3339 7975 46 13.49 1800 4 34 19.05 6.132 0.599 Flare 0.599 95 0.1155 11:30:00 63.50 63.50 3428 8021 46 13.49 1931 4 34 19.05 5.969 0.725 Flare 0.725 18.540 95 0.927 22.248 15.058 17.613 422.712 1138.752 16745.07 7 120000 0.1156 12:00:00 64.00 64.00 3581 8046 45 13.49 2068 4 34 19.05 6.385 0.854 Flare 0.854 95 0.1157 12:30:00 64.50 64.50 3560 8121 44 13.49 2193 4 35 19.05 6.357 0.987 Flare 0.987 16.010 92 1.281 30.739 16.339 14.729 353.501 1153.481 16730.34 7 120000 0.1158 13:00:00 65.00 65.00 3502 8174 44 13.49 2255 3 35 19.05 6.005 1.116 Flare 1.116 92 0.1159 13:30:00 65.50 65.50 3570 8206 44 13.49 2296 4 35 19.05 6.510 1.246 Flare 1.246 6.950 72 1.946 46.704 18.285 5.004 120.096 1158.485 16725.33 7 120000 0.1160 13:30:00 65.50 65.50 High Pressure Oil Samples captured @ 1330 hrs – Cylinder # 1500116408& Cylinder #1500116410161 13:31:00 65.52 65.52 Increase choke to 36/64(14.29mm)162 13:31:00 65.52 65.52 API of condensate taken. API = 47.5 @ 60°F , Specific Gravity = 0.7905163 14:00:00 66.00 66.00 3735 8232 44 14.29 1917 10 37 19.05 9.521 1.413 Flare 1.413 6.610 76 1.586 76.147 19.871 5.024 241.133 1163.509 16720.31 7 120000 0.1164 14:30:00 66.50 66.50 3927 8259 43 14.29 2068 10 37 19.05 10.146 1.618 Flare 1.618 76 0.1165 15:00:00 67.00 67.00 3500 8314 44 14.29 1931 9 37 19.05 9.308 1.820 Flare 1.820 6.100 73 1.647 39.528 21.518 4.453 106.872 1167.962 16715.86 7 120000 0.2166 15:30:00 67.50 67.50 3222 8357 44 14.29 2082 1 37 19.05 3.189 1.951 Flare 1.951 73 0.2167 16:00:00 68.00 68.00 3276 8413 44 14.29 2013 2 37 19.05 4.952 2.035 Flare 2.035 6.820 75 1.705 40.920 23.223 5.115 122.760 1173.077 16710.74 7 120000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row Tubing
Pres
Well
Owing
Pres
Flow
Temp
Omks
Sas
OnficeDryRowMalar
Dg MIR Piste GasRats
Pres TempGze
CumGas Gas TolalGasRdVdBSWOIGan
To Flared
OilRale
Rnid
OICumWater WaterWaterCumloadLTRPH Salinily
Gain Rate
API
dume
2
WWlumlddhhmmasHrs kPag kPag mm kPa '0 mm IIFm'ld ftyup Ojm' m''Idm'API168 2015HOI29163000 6850 6850 3619 8474 2068 4 37 6 731 2157Flare 2 157
ITO
170000 6900
173000 6950
6900
6950
3810
3730
8501
8530
1429 1999
1937 12 37 10615
7 37 1905 8535 2316
2516
Ftze 2316 7 180 74 I 867
Flare 2516
44803 25090 5313 127517 1178390 1670543 7 I22XO 01
ITI
IT4
180000 7000
180000 7000
180000 7000
180000 7000
7000
7000
7000
7000
LowPressumOilSamplescaptured@1800hrs
APIofcondensatetakenAPI=475 @60'FSpeaficGravity=0 t905
3723 8549 44 1429 1931 II 37 1905 10374 2734Flee 2734 6770 77 I 557 37370 26647 5213 125110 1183603 1670022 7 I20XO475 0I
1800Irmmsdiiig
FlowingTubmgpressure=3723kPa
ShutmCasingpressure=8549kPa
Flowingtemperature=44'0
Chokesize=36I64f1429mml
GasRate=II01IOVF
TotaHluidrate=677 m'Ihr
Waterrecoveryrate=521m'Ihr
Condensaterate= 1 56m'Ihr
PH=7, Salinity=120XOppmBSSW=77'A
Apl=475@60'F,SeparatorH'S=gppmSand=01 'A
DailyhrsBowed=lghrs
Cumhrsflowed=70hrs
Dailygasproducedtoflarelast18hrs=27310'm'um
gasProducedtoflare=2 t3410'rn'ond
Producedlast18hrs= 2312m'um
CondProduced=2665
m'aterRecoveredlast18Hrs=26384m'otal
WaterRecovered=118360
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1670022
m'ercentageRecoveredfromInmalLoad= 662'A
Chokeswashedin18bourn=g
Totalchokeswashed=0
IT5
176
178
183000 7050
190000 7100
193000 7150
200000 7200
203000 7250
210000 7300
7050
7100
7150
7200
7250
7300
3640 8655 44 llig 1793 12 38
3795 8685 44 1429 2068 30 35 1905
3800 8687 44 llig 2068 12 36
3730 8769 44 1429 2034 11 37 1905
3681 8816 43 llig 2034 11 38
3762 8864 43 1429 2034 12 38 1905
10292
17370
10997
10653
Itl517
10860
2950Flze
3238Flare
3533Flze
3759Flare
3979Ftze
4202Flare
2950
3238
3533
3759
3979
4202
6070 70
6520 73
7080 72
1 821 43704 28468
I 760 42250 30229
I 982 47578 32211
4249
4760
5098
101976
114230
122342
1187852
1192611
1197709
1669597
1669121
1668611
122XO
122XO
122XO
01
01
01
181 213000 7350
213000 7350
220000 7400
7350
7350
7400
riedel¹X3WeathertordPVTHighPressureOilSamplecaptumdrD2130hrs-Cy
3784 8417 45 llig 1999 12 38
3819 8952 46 1429 1965 12 38 1905
10766
10671
78Cylinder¹0020
4427Ftze 442T
4650Flare 4650 6160 71 1786 42874 33997 4374104966120208316681747 130XO538 01
220000 7400
223000 7450
230000 7500
7400
7450
7500
APIofcondensatetakenAPI=538@60'FSpeaficGravity=0 t635
9240
9170
11 38
11 38
3537 1999
1429 1999 1905
H26pullOppmbydraeger
10540
10540
4871Ftze 4871
5091Flare 5091 6050 61 2359 56628 36357 3691 88572 1205773 1667805 7 130XO 01
187
IX2015HOI30
233000 7550
000000 7600
7550
7600 3319
9121
9099
1999
1429 1999
12 38
11 38 1905
10654
10426
5312Ftze 5312
5531Flare 5531 6240 72 I 747 41933 38104 4493 107827 1210266 1667355 7 130XO 01
PetroClassFlowTestVersion4.5.0.5
0iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD2XSBHDOWBFlowTestllbQIMII'l
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 11
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %168 2015/10/29 16:30:00 68.50 68.50 3619 8474 43 14.29 2068 4 37 19.05 6.731 2.157 Flare 2.157 75 0.1169 17:00:00 69.00 69.00 3810 8501 44 14.29 1999 7 37 19.05 8.535 2.316 Flare 2.316 7.180 74 1.867 44.803 25.090 5.313 127.517 1178.390 16705.43 7 122000 0.1170 17:30:00 69.50 69.50 3730 8530 44 14.29 1937 12 37 19.05 10.615 2.516 Flare 2.516 74 0.1171 18:00:00 70.00 70.00 Low Pressure Oil Samples captured @ 1800 hrs172 18:00:00 70.00 70.00 API of condensate taken. API = 47.5 @ 60°F , Specific Gravity = 0.7905173 18:00:00 70.00 70.00 3723 8549 44 14.29 1931 11 37 19.05 10.374 2.734 Flare 2.734 6.770 77 1.557 37.370 26.647 5.213 125.110 1183.603 16700.22 7 120000 47.5 0.1174 18:00:00 70.00 70.00 18:00 hrs reading
Flowing Tubing pressure = 3723 kPaShut in Casing pressure = 8549 kPaFlowing temperature = 44°CChoke size = 36/64 (14.29mm)Gas Rate = 11.01 10³m³Total fluid rate = 6.77 m³/hrWater recovery rate = 5.21 m³/hrCondensate rate = 1.56 m³/hrPH =7 , Salinity = 120000 ppm, BS&W = 77 %API = 47.5 @ 60°F, Separator H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 18 hrs Cum hrs flowed = 70 hrsDaily gas produced to flare last 18 hrs = 2.73 10³m³Cum gas Produced to flare= 2.734 10³m³Cond Produced last 18 hrs = 23.12 m³Cum Cond Produced = 26.65 m³Water Recovered Last 18 Hrs = 263.84 m³Total Water Recovered = 1183.60 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16700.22 m³ Percentage Recovered from Initial Load = 6.62 %Chokes washed in 18 hours=0Total chokes washed =0
175 18:30:00 70.50 70.50 3640 8655 44 14.29 1793 12 38 19.05 10.292 2.950 Flare 2.950 77 0.1176 19:00:00 71.00 71.00 3795 8685 44 14.29 2068 30 35 19.05 17.370 3.238 Flare 3.238 6.070 70 1.821 43.704 28.468 4.249 101.976 1187.852 16695.97 7 122000 0.1177 19:30:00 71.50 71.50 3800 8687 44 14.29 2068 12 36 19.05 10.997 3.533 Flare 3.533 70 0.1178 20:00:00 72.00 72.00 3730 8769 44 14.29 2034 11 37 19.05 10.653 3.759 Flare 3.759 6.520 73 1.760 42.250 30.229 4.760 114.230 1192.611 16691.21 7 122000 0.1179 20:30:00 72.50 72.50 3681 8816 43 14.29 2034 11 38 19.05 10.517 3.979 Flare 3.979 73 0.1180 21:00:00 73.00 73.00 3762 8864 43 14.29 2034 12 38 19.05 10.860 4.202 Flare 4.202 7.080 72 1.982 47.578 32.211 5.098 122.342 1197.709 16686.11 7 122000 0.1181 21:30:00 73.50 73.50 “Weatherford PVT High Pressure Oil Sample captured @ 21:30 hrs – Cylinder # 0037 & Cylinder # 0020182 21:30:00 73.50 73.50 3784 8417 45 14.29 1999 12 38 19.05 10.766 4.427 Flare 4.427 72 0.1183 22:00:00 74.00 74.00 3819 8952 46 14.29 1965 12 38 19.05 10.671 4.650 Flare 4.650 6.160 71 1.786 42.874 33.997 4.374 104.966 1202.083 16681.74 7 130000 53.8 0.1184 22:00:00 74.00 74.00 API of condensate taken. API = 53.8 @ 60°F , Specific Gravity = 0.7635, H2S pull 0ppm by draeger.185 22:30:00 74.50 74.50 3537 9240 43 14.29 1999 11 38 19.05 10.540 4.871 Flare 4.871 71 0.1186 23:00:00 75.00 75.00 3388 9170 42 14.29 1999 11 38 19.05 10.540 5.091 Flare 5.091 6.050 61 2.359 56.628 36.357 3.691 88.572 1205.773 16678.05 7 130000 0.1187 23:30:00 75.50 75.50 3396 9121 42 14.29 1999 12 38 19.05 10.654 5.312 Flare 5.312 61 0.1188 2015/10/30 00:00:00 76.00 76.00 3319 9099 42 14.29 1999 11 38 19.05 10.426 5.531 Flare 5.531 6.240 72 1.747 41.933 38.104 4.493 107.827 1210.266 16673.55 7 130000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row Tubing
Pres
Well
Owing
Pres
Flow
Temp
Omks
Bas
Bshe Dg
Pres Pres
OnficeDryRowMalar
MIR Piste GasRats
TempGze
CumGas Gas
To
TotalGas
Flared
RdVdBSWOlFmn OilRale OlCum
Rnid
Water WaterWaterGum
Gain Rate
leadLTRPH SalinilyAPI
dume
2
WWlamlddhhmmssHrs Hrs kPag kPag mm '0 mm 1tym'Id ii)m''Idm'API189 2015HOI30000000 7600 76000000Irmmsdiiig
FlowingTubmgpressure=3319kPa
ShutmCasingpressure=9099kPa
Flowingtemperature=42'0
Chokesize=36I64 )1429mm)
GasRate=II01IOVP
TotaHluidrate=624 m'Ihr
Waterrecoveryrate=449m'Ihr
Condensaterate= 1 75m'Ihr
PH=t,Salinity=130XOppmBSSW=72S
Apl=538@60'F,SeparatorH'S=gppmSand=01 'A
Dailyhrsgowed=24hrs
Cumhrsflowed=76hrs
Dailygasproducedtoflarelast24hrs=55310'm'um
gasProducedtoflare=553110'rn'ond
Producedlast24hrs= 345tm'um
CondProduced=3810m'ater
Recoveredlast24Hrs=29051
m'otal
WaterRecovered=121027
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLetttoRecover= 1667355
m'ercentageRecoveredfromInmalLoad= 676'A
Chokeswashedin24bourn=g
Totalchokeswashed=0
191
003000
010000
010500
013000
020000
020000
023000
7650 7650
7700 7700
7708 7708
7750 7750
7800 7800
7800 7800
7850 7850
3813 9279 44 Il79 1999 13 37 G:5 11438 5759Flze 5759
3712 9331 44 1429 2034 15 36 1905 12081 6004Flare 6004 6610 73 1785 42833 39889 4825115807121509116668737 130XO 01
Increasechoketo36I64)1508mm)
3743 9360 42 1508 2034 17 36 G:5 13153 6267Flee 626T
3814 9397 42 1 508 2034 20 36 1905 14056 6550Flare 6550 7 180 69 2226 53419 42115 4954 118901 1220045 1666377 7 I30XO40t 0I
APIotcondensatetakenApl=407 @60'FSpeaficGravity=0 8217H26pullOppmbydraeger
3713 36 G:5 13339 6836Flee 6836W55 45 15:5 2034
197 030000
033000
040000
043000
050000
053000
7900 7900
7950 7950
8000 8000
8050 8050
8100 8100
8150 8150
3881
3775
3736
3761
3759
9512
9562
9609
9670
9720
9734
45 1508 2034
44 15:5 2055
43 1508 2034
44 15:5 2034
44 1508 2034
44 15:5 2034
36 1905 12965 7110Flare 7110
36 G:5 13222 7383Flee 7383
36 1905 13968 7666Flare 7666
37 G:5 13675 7954Flee 7954
37 1905 13765 8240Flare 8240
37 G:5 13765 8526Ftze 8526
6760
7270
7720
2231
2326
2625
53539 44345
55834 46672
62995 49297
4529 108701 1224575 1665925 7
4944 118646 1229518 1665430 7
5095 122285 1234613 1664921 7
130XO
132XO
130XO
01
01
01
053000
060000
8150 8150
8200 8200
WeathertordPVTHighPressureOilSamplecaptumdrD0530hrs-Cylinder¹X258Cylinder¹0030
3769 9756 44 1 508 2034 19 37 1905 13853 8814Flare 8814 7240 68 2317 55603 51613 4923 118157 1239537 1664428 7 I30XO40t 0I
060000
060000
063000
8200 8200
8200 8200
8250 8250
LowPressumOilSamplescaptured@0600hrs
APIofcondensatetakenAPI=407@60'FSpeaficGravity=0 8217H26pullOppm
15:5 1999 20 139333827 9867 44 9103Ftze 9 103
210
211
212
213
070000
073000
080000
083000
090000
093000
8300 8300
8350 8350
8400 8400
8450 8450
8500 8500
8550 8550
3827 9930 44
3904 9968 44
3856 10027 44
3794 10071 44
3853 10119 44
3959 10171 45
1508 2068 25
15:5 1744 39
1508 1827 36
15:5 1855 33
1508 2130 38
15:5 1937 34
37 1905
37 1905
37 1905
15885
18137
17710
17153
19812
17831
9414
9768
10142
10505
10890
11282
Flare
Ftze
Flare
Ftze
Flare
Ftze
9414 7670 60 3068 73632
9768
10142 7920 60 3 168 76032
10505
10890 8 120 70 2436 58464
11282
54681 4602
57849 4752
60285 5684
110448
114048
136416
1244139
1248891
1254575
1663968
1663493
1662925
7 132XO
7 132XO
7 132XO
01
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD24864DOWBFlowTestlibggsll2
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 12
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %189 2015/10/30 00:00:00 76.00 76.00 00:00 hrs reading
Flowing Tubing pressure = 3319 kPaShut in Casing pressure = 9099 kPaFlowing temperature = 42°CChoke size = 36/64 (14.29mm)Gas Rate = 11.01 10³m³Total fluid rate = 6.24 m³/hrWater recovery rate = 4.49 m³/hrCondensate rate = 1.75 m³/hrPH =7 , Salinity = 130000 ppm, BS&W = 72 %API = 53.8 @ 60°F, Separator H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 76 hrsDaily gas produced to flare last 24 hrs = 5.53 10³m³Cum gas Produced to flare= 5.531 10³m³Cond Produced last 24 hrs = 34.57 m³Cum Cond Produced = 38.10 m³Water Recovered Last 24 Hrs = 290.51 m³Total Water Recovered = 1210.27 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16673.55 m³ Percentage Recovered from Initial Load = 6.76 %Chokes washed in 24 hours=0Total chokes washed =0
190 00:30:00 76.50 76.50 3813 9279 44 14.29 1999 13 37 19.05 11.438 5.759 Flare 5.759 72 0.1191 01:00:00 77.00 77.00 3712 9331 44 14.29 2034 15 36 19.05 12.081 6.004 Flare 6.004 6.610 73 1.785 42.833 39.889 4.825 115.807 1215.091 16668.73 7 130000 0.1192 01:05:00 77.08 77.08 Increase choke to 38/64 (15.08mm)193 01:30:00 77.50 77.50 3743 9360 42 15.08 2034 17 36 19.05 13.153 6.267 Flare 6.267 73 0.1194 02:00:00 78.00 78.00 3814 9397 42 15.08 2034 20 36 19.05 14.056 6.550 Flare 6.550 7.180 69 2.226 53.419 42.115 4.954 118.901 1220.045 16663.77 7 130000 40.7 0.1195 02:00:00 78.00 78.00 API of condensate taken. API = 40.7 @ 60°F , Specific Gravity = 0.8217, H2S pull 0ppm by draeger.196 02:30:00 78.50 78.50 3713 9455 45 15.08 2034 18 36 19.05 13.339 6.836 Flare 6.836 69 0.1197 03:00:00 79.00 79.00 3648 9512 45 15.08 2034 17 36 19.05 12.965 7.110 Flare 7.110 6.760 67 2.231 53.539 44.345 4.529 108.701 1224.575 16659.25 7 130000 0.1198 03:30:00 79.50 79.50 3881 9562 44 15.08 2055 17 36 19.05 13.222 7.383 Flare 7.383 67 0.1199 04:00:00 80.00 80.00 3775 9609 43 15.08 2034 20 36 19.05 13.968 7.666 Flare 7.666 7.270 68 2.326 55.834 46.672 4.944 118.646 1229.518 16654.30 7 132000 0.1200 04:30:00 80.50 80.50 3736 9670 44 15.08 2034 19 37 19.05 13.675 7.954 Flare 7.954 68 0.1201 05:00:00 81.00 81.00 3761 9720 44 15.08 2034 19 37 19.05 13.765 8.240 Flare 8.240 7.720 66 2.625 62.995 49.297 5.095 122.285 1234.613 16649.21 7 130000 0.1202 05:30:00 81.50 81.50 3759 9734 44 15.08 2034 19 37 19.05 13.765 8.526 Flare 8.526 66 0.1203 05:30:00 81.50 81.50 “Weatherford PVT High Pressure Oil Sample captured @ 05:30 hrs – Cylinder # 0025 & Cylinder # 0030204 06:00:00 82.00 82.00 3769 9756 44 15.08 2034 19 37 19.05 13.853 8.814 Flare 8.814 7.240 68 2.317 55.603 51.613 4.923 118.157 1239.537 16644.28 7 130000 40.7 0.1205 06:00:00 82.00 82.00 Low Pressure Oil Samples captured @ 06:00 hrs206 06:00:00 82.00 82.00 API of condensate taken. API = 40.7 @ 60°F , Specific Gravity = 0.8217, H2S pull 0ppm.207 06:30:00 82.50 82.50 3827 9867 44 15.08 1999 20 36 19.05 13.933 9.103 Flare 9.103 68 0.1208 07:00:00 83.00 83.00 3827 9930 44 15.08 2068 25 37 19.05 15.885 9.414 Flare 9.414 7.670 60 3.068 73.632 54.681 4.602 110.448 1244.139 16639.68 7 132000 0.1209 07:30:00 83.50 83.50 3904 9968 44 15.08 1744 39 38 19.05 18.137 9.768 Flare 9.768 60 0.1210 08:00:00 84.00 84.00 3856 10027 44 15.08 1827 36 37 19.05 17.710 10.142 Flare 10.142 7.920 60 3.168 76.032 57.849 4.752 114.048 1248.891 16634.93 7 132000 0.1211 08:30:00 84.50 84.50 3794 10071 44 15.08 1855 33 39 19.05 17.153 10.505 Flare 10.505 60 0.1212 09:00:00 85.00 85.00 3853 10119 44 15.08 2130 38 37 19.05 19.812 10.890 Flare 10.890 8.120 70 2.436 58.464 60.285 5.684 136.416 1254.575 16629.25 7 132000 0.1213 09:30:00 85.50 85.50 3959 10171 45 15.08 1937 34 38 19.05 17.831 11.282 Flare 11.282 70 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMelar Rnid dume
2
Time Cum Row Tubing
Pres
CmingFlowChokeGabe Dg MIR Plate
Pres TempSwe Pres Pres TempGze
CumGas Gas
To
TotalGas
Flared
RdVHBSWOIGanOilRale OICumWater WaterWaterGumleadLTR
Gain Rate
PH SelrrrrVAPI Smd
Dd
214
215
216
217
218
WWfamfdd
2015HOI30
hhmmasHrs
100000 8600
103000 8650
110000 8700
113000 8750
120000 8800
8600
8650
8700
8750
8800
kPag
3953
3868
3917
3968
3936
kPeg'0 mm kPan kPa '0 mm
10225 45 1508 2013 37 38 1905
10268 45 15:5 1903 35 39
10319 45 1 508 1917 35 40 1905
10379 45 15:5 1965 36 40
10413 45 1508 1972 36 38 1905
1tym'ld
18893
17MIB
17982
18401
18568
1 1 665Flare
12048Flae
12422Flare
12800Ftae
131INiFlare
11665
12048
12422
12800
13186
ii)m'460
8510
8470
m''Id2707 64973
2638 63314
2033 48787
m'2
993
65631
67663
575313806712603271662349
5872 140926 1266199 1661762
6437 154493 1272637 1 6611 18
132XO
134XO
134XO
'API
01
01
01
219 123000 8850
130000 8900
133000 8950
140000 9000
140000 9000
140000 9000
8850
8900
8950
9000
9000
9000
3944
3992
3963
10493 45 15:5 1965 36 39
10526 45 1 508 1965 38 39 1905
10551 45 15:5 1999 37 39
Increasechoketo40I64(1588mm)
Changeordiceplate1 250Plate(3175mm)
3961 10601 46 1588 2020 6 25 3175
18373
18809
IIIX3
13570Ftae
13958Flare
14350Flae
Flare21551 14771
13570
13958
14350
14771
7690 2538 60905 70201 5 152 123655 1277789 1660603 IMXO
1284023 1659980 7 134XO8780 71 2546 61109 72747 6234 149611
01
01
143000 9050
150000 9100
153000 9150
160000 9200
163000 9250
170000 9300
9050
9100
9150
9200
9250
9300
4202 10583 46 1585
3958 10591 46 1588
3937 10622 45 1585
3774 10675 45 1588
3843 10712 45 1585
3851 10733 45 15Ml
2013 5 39
1882 6 39 3175
1579 6 39
2013 5 39 3175
2075 6 40
X13 5 39 3175
20461 15208
21tl77 15Bit
19303 16062
20461 16476
21204 16910
20461 17344
Ftae
Flare
Ftae
Flare
Ftae
Flare
15208
15641
16062
16476
16910
17344
9340 70 2802 67248 75549 6538156912
10300 75 2575 61800 78124 7725 185400
10350 74 2691 64584 80815 7659 183816
129056116593267 134XO
1298286 1658553 7 134XO
1305945 1657788 7 134XO
01
01
01
231 173000 9350
180000 9400
9350
9400
3812 10749 46 1585 2075 6 40 21204 17778
APlotcondensatetakenApl=472@60'6SpeoficGravily=07918H28pullgppm
Ftae 17778 472
180000 9400
180000 9400
9400
9400
3805 10782 46 1588 173t 8 39 3175 22896 18237Flare18237 10440 73 2819 67651 83634 7621182909131356616570257 134XO 01
1800Irmmsdiilg
FlowingTubmgpressure=3805kPa
ShutmCasingpressure=10782kPa
Flowingtemperature=46'0
Chokesize=40I64 )1588mml
GasRate=2420IOVP
Totalguidrate=1044m'Ihr
Waterrecoveryrate=762m'Ihr
Condensaterate=282m'Ihr
PH=t,Salinity=134XOppmBSBW=73S
Apl=472@60'6,SeparatorH'S=gppmSand=01 'A
DailyhrsBowed=lghrs
Cumhrsflowed=94hrs
Dailygasproducedtoflarelast18hrs=12tlItPm'um
gasProducedtoflare=18237
10'm'ondProducedlast18hrs=
4553m'um
CondProduced=8363
m'aterRecoveredlast18Hrs=10330m'otal
WaterRecovered=131357
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1657025
m'ercentageRecoveredfromInmalLoad= 735'A
Chokeswashedin18bourn=g
Totalchokeswashed=0
237
183000 9450
190000 9500
193000 9550
200000 9600
9450
9500
9550
9600
3883 10877
3874 10931
3884 10982
38INi 11tl37
1585
1585
1896
1924
1896
1917
23168 18717Flee 18717
3175 23338 19202Flare 19202 9090
23168 19686Flae 19686
3175 23295 20170Flare 20170 10220
2454
2862
58903
68678
86088
88950
6636
7358
159257 1320202
176602 1327560
1656362
1655626
IMXO
IMXO
00
00
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTING,.IAweD2XSBHDOWBFlowTestllbQIM))3
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 13
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %214 2015/10/30 10:00:00 86.00 86.00 3953 10225 45 15.08 2013 37 38 19.05 18.893 11.665 Flare 11.665 8.460 68 2.707 64.973 62.993 5.753 138.067 1260.327 16623.49 7 132000 0.1215 10:30:00 86.50 86.50 3868 10268 45 15.08 1903 35 39 19.05 17.888 12.048 Flare 12.048 68 0.1216 11:00:00 87.00 87.00 3917 10319 45 15.08 1917 35 40 19.05 17.982 12.422 Flare 12.422 8.510 69 2.638 63.314 65.631 5.872 140.926 1266.199 16617.62 7 134000 0.1217 11:30:00 87.50 87.50 3968 10379 45 15.08 1965 36 40 19.05 18.401 12.800 Flare 12.800 69 0.1218 12:00:00 88.00 88.00 3936 10413 45 15.08 1972 36 38 19.05 18.568 13.186 Flare 13.186 8.470 76 2.033 48.787 67.663 6.437 154.493 1272.637 16611.18 7 134000 0.1219 12:30:00 88.50 88.50 3944 10493 45 15.08 1965 36 39 19.05 18.373 13.570 Flare 13.570 76 0.1220 13:00:00 89.00 89.00 3992 10526 45 15.08 1965 38 39 19.05 18.809 13.958 Flare 13.958 7.690 67 2.538 60.905 70.201 5.152 123.655 1277.789 16606.03 7 134000 0.1221 13:30:00 89.50 89.50 3963 10551 45 15.08 1999 37 39 19.05 18.853 14.350 Flare 14.350 67 0.1222 14:00:00 90.00 90.00 Increase choke to 40/64 (15.88mm)223 14:00:00 90.00 90.00 Change orifice plate1.250 Plate (31.75mm).224 14:00:00 90.00 90.00 3961 10601 46 15.88 2020 6 25 31.75 21.551 14.771 Flare 14.771 8.780 71 2.546 61.109 72.747 6.234 149.611 1284.023 16599.80 7 134000 0.1225 14:30:00 90.50 90.50 4202 10583 46 15.88 2013 5 39 31.75 20.461 15.208 Flare 15.208 71 0.1226 15:00:00 91.00 91.00 3958 10591 46 15.88 1882 6 39 31.75 21.077 15.641 Flare 15.641 9.340 70 2.802 67.248 75.549 6.538 156.912 1290.561 16593.26 7 134000 0.1227 15:30:00 91.50 91.50 3937 10622 45 15.88 1579 6 39 31.75 19.303 16.062 Flare 16.062 70 0.1228 16:00:00 92.00 92.00 3774 10675 45 15.88 2013 5 39 31.75 20.461 16.476 Flare 16.476 10.300 75 2.575 61.800 78.124 7.725 185.400 1298.286 16585.53 7 134000 0.1229 16:30:00 92.50 92.50 3843 10712 45 15.88 2075 6 40 31.75 21.204 16.910 Flare 16.910 75 0.1230 17:00:00 93.00 93.00 3851 10733 45 15.88 2013 5 39 31.75 20.461 17.344 Flare 17.344 10.350 74 2.691 64.584 80.815 7.659 183.816 1305.945 16577.88 7 134000 0.1231 17:30:00 93.50 93.50 3812 10749 46 15.88 2075 6 40 31.75 21.204 17.778 Flare 17.778 74 47.2 0.1232 18:00:00 94.00 94.00 API of condensate taken. API = 47.2 @ 60°F , Specific Gravity = 0.7918, H2S pull 0ppm.233 18:00:00 94.00 94.00 3805 10782 46 15.88 1737 8 39 31.75 22.896 18.237 Flare 18.237 10.440 73 2.819 67.651 83.634 7.621 182.909 1313.566 16570.25 7 134000 0.1234 18:00:00 94.00 94.00 18:00 hrs reading
Flowing Tubing pressure = 3805 kPaShut in Casing pressure = 10782 kPaFlowing temperature = 46°CChoke size = 40/64 (15.88mm)Gas Rate = 24.20 10³m³Total fluid rate = 10.44 m³/hrWater recovery rate = 7.62 m³/hrCondensate rate = 2.82 m³/hrPH =7 , Salinity = 134000 ppm, BS&W = 73 %API = 47.2 @ 60°F, Separator H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 18 hrs Cum hrs flowed = 94 hrsDaily gas produced to flare last 18 hrs = 12.71 10³m³Cum gas Produced to flare= 18.237 10³m³Cond Produced last 18 hrs = 45.53 m³Cum Cond Produced = 83.63 m³Water Recovered Last 18 Hrs = 103.30 m³Total Water Recovered = 1313.57 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16570.25 m³ Percentage Recovered from Initial Load = 7.35 %Chokes washed in 18 hours=0Total chokes washed =0
235 18:30:00 94.50 94.50 3883 10877 46 15.88 1896 7 39 31.75 23.168 18.717 Flare 18.717 73 0.1236 19:00:00 95.00 95.00 3874 10931 44 15.88 1924 7 39 31.75 23.338 19.202 Flare 19.202 9.090 73 2.454 58.903 86.088 6.636 159.257 1320.202 16563.62 7 134000 0.0237 19:30:00 95.50 95.50 3884 10982 45 15.88 1896 7 39 31.75 23.168 19.686 Flare 19.686 73 0.0238 20:00:00 96.00 96.00 3886 11037 43 15.88 1917 7 39 31.75 23.295 20.170 Flare 20.170 10.220 72 2.862 68.678 88.950 7.358 176.602 1327.560 16556.26 7 134000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
TubingOwingFlow
Pres Pres Temp
OmkaSkdw
$we Pma
OnficeDryRowMelar
Dg MIR
Pres Temp
CumGas Gas TolalGasRdVHBSW
To Flared
OIGanOilRale
Rnid
OlCum Water
Gain
WaterGuminertLTRPH SelrrrrV
dume
2
API Smd
Od
WWlamldd
239 2015HOI30
hhmmss
203000
210000
Hrs Hrs kPag kPag 'C
9650 9650 3892 11109 44
9700 9T00 3904 11196 44
mm kPwl
1585 1931
15Ml 1931
kPa 'C
7 39
8 39
mm
3175
Ityapid
23380
23765
ftyap(ljm'0
656Ftze 20656
Flare 21147 10560 7421147
m''Id
2746 65894
m'1
696 7814 187546 1335374 1654845 134XO
'API
00
241
242
213000
220000
9750 9T50 3909 11262 44
9800 9800 3912 11368 42
1585 1965
1588 1965
8 39
8 39 3175
24362
24362
21649
22156
Ftze 21649
Flare 22156 10390 73 2805 67327 BI501 7585 18203313429591654086 IMXO444 00
220000 9800 9800APlotcondensatetakenAPI ificG60'FSpec444@ ravily H2$pullOppmbydraeg
247 2015HOI31
223000
230000
233000
000000
000000
9850 9850 3910 11412 42
9900 9900 3913 11539 44
9950 9950 3911 11579 44
10000 10000 3914 11610 44
10000 100000000hrsreadmg
1585 1999
1588 1999
1585 1999
1588 1999
8 38
8 38
8 38
8 38
3175
3175
24625
24625
25005
25005
22667
23180
23697
24217
Ftze 2266T
Flare 23180 9520 71
Ftze 2369T
Flare 24217 10360 72
2761 66259
2901 69619
97262 6759
100163 7459
162221
179021
1349718 1653410
1357177 1652664
134XO
134XO
00
00
FlowingTubmgpressure=3914kPa
ShutmCasingpressure=11610kPa
Flowingtemperature=44'0
Chokesize=40I64I1588mmi
GasRate=2640IOVF
Totalguidrate=1036m'Ihr
Waterrecoveryrate=7Rim'Ihr
Condensaterate=290m'Ihr
PH=t,Salinity=134XOppmBSSW=72$API=444@60'F,SeparatorH'S=gppmSand=gg'I
Dailyhrsgowed=24hrs
Cumhrsflowed=100hrs
Dailygasproducedtoflarelast24hrs=186910'm'um
gasProducedtoflare=2421710'm'ond
Producedlast24hrs= 6206m'um
CondProduced= 10016
m'ater
Recoveredlast24Hrs=14691
m'otal
WaterRecovered=135t18
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1652664
m'ercentageRecoveredfromInmalLoad= 758'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
251
003000
010000
013000
020000
10050 10050 3875 11839 43
10100 10100 3836 12025 43
10150 10150 3823 12224 43
10200 10200 3818 12389 43
1585 1999
1588 1999
1585 1999
1588 1965
8 38
8 38
8 38
7 38
3175
3175
24238 24730Flee 24730
24238 25235Flare 25235
24238 25740Ftze 25740
23636 26239Flare 26239
9680
10250
71 2807
72 2870
67373 102970
68880 105840
687316494713640501651977
738017712013714301651239
7 136XO
7 136XO
00
461 00
020000
023000
10200 10200APIofcondensatetakenAPI
10250 10250 3768 12576 43
ificG60'FSpec461@ ravily
7 371585 1965
0 79RIH2$pullgppm
23681 26732Ftze 26732
257
030000
033000
040000
043000
050000
053000
060000
10300 10300 3776 12744 43
10350 10350 3883 12916 43
10400 10400 3812 13106 43
10450 10450 4106 12819 40
10500 10500 4114 12810 40
10550 10550 4102 12812 40
10600 10600 4116 12806 40
15Ml 1931
1585 1965
1588 1999
1585 1999
1588 2068
1585 2068
1588 2068
7 37
8 37
8 37
9 37
10 37
10 37
10 37
3175
3175
3175
3175
23470 27223Flare 27223
24455 27722Ftze 27722
24673 28234Flare 28234
26878 28771Ftze 28771
28055 29343Flare 29343
28055 29928Ftze 29928
28055 30512Flare X512
10400
9670
9370
10160
72 2912
73 2611
71 2717
72 2845
69888 108752
62662 111363
65215 114080
68275 116925
748817971213789181650490
705916941813859771649784
6653 159665 1392630 1649119
7315 175565 1399945 1648387
7 136XO
7 136XO
7 136XO
7 136XO
00
00
00
444 00
060000
060000
10600 10600LowPressumOilSamplescaptured@0600hrs
1060010600APlotcondensatetakenAPI=444@60'FSpeoficGravily=OBORiH2$pullgppm
PetroClassFlowTestVersion4.5.0.5
C:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD24864DOWBFlowTestlibggall4
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 14
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %239 2015/10/30 20:30:00 96.50 96.50 3892 11109 44 15.88 1931 7 39 31.75 23.380 20.656 Flare 20.656 72 0.0240 21:00:00 97.00 97.00 3904 11196 44 15.88 1931 8 39 31.75 23.765 21.147 Flare 21.147 10.560 74 2.746 65.894 91.696 7.814 187.546 1335.374 16548.45 7 134000 0.0241 21:30:00 97.50 97.50 3909 11262 44 15.88 1965 8 39 31.75 24.362 21.649 Flare 21.649 74 0.0242 22:00:00 98.00 98.00 3912 11368 42 15.88 1965 8 39 31.75 24.362 22.156 Flare 22.156 10.390 73 2.805 67.327 94.501 7.585 182.033 1342.959 16540.86 7 134000 44.4 0.0243 22:00:00 98.00 98.00 API of condensate taken. API = 44.4 @ 60°F , Specific Gravity = 0.8046, H2S pull 0ppm by draeger.244 22:30:00 98.50 98.50 3910 11412 42 15.88 1999 8 38 31.75 24.625 22.667 Flare 22.667 73 0.0245 23:00:00 99.00 99.00 3913 11539 44 15.88 1999 8 38 31.75 24.625 23.180 Flare 23.180 9.520 71 2.761 66.259 97.262 6.759 162.221 1349.718 16534.10 7 134000 0.0246 23:30:00 99.50 99.50 3911 11579 44 15.88 1999 8 38 31.75 25.005 23.697 Flare 23.697 71 0.0247 2015/10/31 00:00:00 100.00 100.00 3914 11610 44 15.88 1999 8 38 31.75 25.005 24.217 Flare 24.217 10.360 72 2.901 69.619 100.163 7.459 179.021 1357.177 16526.64 7 134000 0.0248 00:00:00 100.00 100.00 00:00 hrs reading
Flowing Tubing pressure = 3914 kPaShut in Casing pressure = 11610 kPaFlowing temperature = 44°CChoke size = 40/64 (15.88mm)Gas Rate = 26.40 10³m³Total fluid rate = 10.36 m³/hrWater recovery rate = 7.46 m³/hrCondensate rate = 2.90 m³/hrPH =7 , Salinity = 134000 ppm, BS&W = 72 %API = 44.4 @ 60°F, Separator H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 100 hrsDaily gas produced to flare last 24 hrs = 18.69 10³m³Cum gas Produced to flare= 24.217 10³m³Cond Produced last 24 hrs = 62.06 m³Cum Cond Produced = 100.16 m³Water Recovered Last 24 Hrs = 146.91 m³Total Water Recovered = 1357.18 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16526.64 m³ Percentage Recovered from Initial Load = 7.58 %Chokes washed in 24 hours=0Total chokes washed =0
249 00:30:00 100.50 100.50 3875 11839 43 15.88 1999 8 38 31.75 24.238 24.730 Flare 24.730 72 0.0250 01:00:00 101.00 101.00 3836 12025 43 15.88 1999 8 38 31.75 24.238 25.235 Flare 25.235 9.680 71 2.807 67.373 102.970 6.873 164.947 1364.050 16519.77 7 136000 0.0251 01:30:00 101.50 101.50 3823 12224 43 15.88 1999 8 38 31.75 24.238 25.740 Flare 25.740 71 0.0252 02:00:00 102.00 102.00 3818 12389 43 15.88 1965 7 38 31.75 23.636 26.239 Flare 26.239 10.250 72 2.870 68.880 105.840 7.380 177.120 1371.430 16512.39 7 136000 46.1 0.0253 02:00:00 102.00 102.00 API of condensate taken. API = 46.1 @ 60°F , Specific Gravity = 0.7968, H2S pull 0ppm.254 02:30:00 102.50 102.50 3768 12576 43 15.88 1965 7 37 31.75 23.681 26.732 Flare 26.732 72 0.0255 03:00:00 103.00 103.00 3776 12744 43 15.88 1931 7 37 31.75 23.470 27.223 Flare 27.223 10.400 72 2.912 69.888 108.752 7.488 179.712 1378.918 16504.90 7 136000 0.0256 03:30:00 103.50 103.50 3883 12916 43 15.88 1965 8 37 31.75 24.455 27.722 Flare 27.722 72 0.0257 04:00:00 104.00 104.00 3812 13106 43 15.88 1999 8 37 31.75 24.673 28.234 Flare 28.234 9.670 73 2.611 62.662 111.363 7.059 169.418 1385.977 16497.84 7 136000 0.0258 04:30:00 104.50 104.50 4106 12819 40 15.88 1999 9 37 31.75 26.878 28.771 Flare 28.771 73 0.0259 05:00:00 105.00 105.00 4114 12810 40 15.88 2068 10 37 31.75 28.055 29.343 Flare 29.343 9.370 71 2.717 65.215 114.080 6.653 159.665 1392.630 16491.19 7 136000 0.0260 05:30:00 105.50 105.50 4102 12812 40 15.88 2068 10 37 31.75 28.055 29.928 Flare 29.928 71 0.0261 06:00:00 106.00 106.00 4116 12806 40 15.88 2068 10 37 31.75 28.055 30.512 Flare 30.512 10.160 72 2.845 68.275 116.925 7.315 175.565 1399.945 16483.87 7 136000 44.4 0.0262 06:00:00 106.00 106.00 Low Pressure Oil Samples captured @ 06:00 hrs263 06:00:00 106.00 106.00 API of condensate taken. API = 44.4 @ 60°F , Specific Gravity = 0.8046, H2S pull 0ppm.
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
FLOWTESTDATATestlime Well OnficeDryRowMalar
Tubing
Pres
Time Cum Row Owing
Pres
Flow
Temp
ChokeBshe Dg
Sne Pres Pres
MIR Piste
TempGze
GasRateCumGas Gas
To
TotalGas
Flared
RdVd
'0 mmhhmmssWW)mnldd Hrs Hrs kPag kPag mm kPag kPa 1tym'Id tipm'I)m'6
28062 31097Ftse2015IIOI31 1065010650 4092 3109T1535 2062 10063000 12712
1070010700 1588 2068 10 30 3175 28000 31681Flare 31681 9930070000 4111 12603
1535 2068 10 30 28000 32264Ftse12636 32264073000 1075010750 4110
1000010800
1005010850
4132 1588 2068 10
1535 2062 10
30 3175
30
28000 32047Flare
28290 33434Flee
3204T 10850000000 12600
4113 12562003000
1090010900 4098 1588 2062 10 30 3175 28290 34023Flare 34023090000 12522 10010
270 1090210902
1095010950
e to42I64(1667mm)090100 lncrm
30 29070 34621Flse271 4092 34621093000 12512 1667 2124 10
1100011000
1100011000
1105011050
1110011100
1115tl11150
1120011200
4088 30 3175
ravily=0 t971
39
39 3175
30
30 3175
30211 35239Flare 35239 11850100000 12520 1667 1931 12
472@60'FSpecI ofconde ificG H20pullgppm100000 nsatetaken API
30317 35069Flee
30426 36502Flare
30950 37141Ftse
30896 37785Flare
274 4087 350691951 12
1667 1965 12
1906 13
1667 1979 13
103000 12506
275 4081 36502 10880110000 12485
276 4103 12466 37141113000
37785 10230120000 4069 12417
1999 13 30 31059 38431Flse278 1125011250 4098 12349 30431123000
1130011300 12310 1667 1993 13 30 3175 31005 39077Flare 3907T 11XO130000 4120
1135011350
1140011400
2034 13
1667 2055 13
37
37 3175
31392 39727Ftse
31861 40386Flare
3972T133000 4125 12275
281 4138 12235 40386140000 11240
2068 13 30 31900 41050Flse4156 41050143000 11450 11450 12211
1150011500
1155tl11550
1160011600
1165011650
1667 2068 13
2068 13
1667 2002 13
2096 13
37 3175
37
37 3175
36
32275 41719Flare
32275 42391Ftse
32687 43068Flare
32862 43751Flee
41719 10560150000 4147 12170
42391153000 4140 12140
4156 43068 10230160000 12117
43751163000 4165 12079
32886 44436Flee
32886 45121Flee
287 1170011700
1175tl11750
1100011800
1100011800
1105011850
1667 2137 13
2137 13
36 3175
36
ravily=0 t892
36 3175
36
44436170000 4148 12055 9710
173000 4225 12005 45121
478 @60'FSpecI ofconde ificG H20pullgppm100000 nsatetaken API
35840 45037Flee
36679 46592Ftse
4263 11990 1667 2137 16
2137 16
4503T100000 9580
11990 46592103000 4260
1105811858
1190011900
1195011950
1195011950
1200012000
1205012050
12100 12100
12150 12150
e to46I64 (1588mm)103500 lncrm
3866 1826 2137 16
2206 15
te(3175mm)
1826 1999 11
1999 11
1826 2013 12
2034 12
36 3175
36
35840 47348Flare
35556 48091Flee
47348 9900lgm6190000
3785 40091193000 11676
Cliangeordi193000 ceplatel500Pla
3748 36 3010
36
36 3010
36
40900200000 11629 42075 48900Flare
43017 49786Ftse
43632 50689Flare
43861 51600Flee
10020
3780 49786203000 11550
3753 50689 9760210000 11476
3746 51600213000 11420
12200 12200 3726 11760 1826 2068 11 36 3010 43291 52508Flare 52508 10370220000
478@60'FSpec12200 12200
12250 12250
1230012300
1235012350
I ofconde ificG H20pullgppmravily=0 t892
36
36 3010
36
220000 nsatetaken API
2068 12
1826 2068 12
2075 12
44705 53425Flee
44t05 54356Flare
44781 55288Flee
3780 11311 53425223000
3716 54356230000 11217 9770
3710 55288233000 11201
2015IIVgI 12400 12400 3704 1826 2002 12 36 3010 44857 56222Flare 56222000000 11197 10050
PetroC(assFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAweD24804DOWSFlowTestllbggh((5
BSWOIGanOilRale OIGum
m''Idm'080
69113 119804
3038 72912 122842
3003 72072 125845
3792 91008 129637
2720 65200 132357
3069 73656 135426
2712 65008 130130
2585 62045 140724
2534 EO826 143250
2353 56470 145611
2330 55930 147941
2395 57400 150336
2475 59400 152811
2305 55310 155116
2538 EO902 157654
2489 59731 160142
2540 EO965 162683
2512 EO300 165195
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
Rnid dume
2
Wstw
Gain
WaterGumleadLTRPH SalinilyAPI
ppm 'API
1692071406996 1647682 136XO7050 00
136XO7812 1874801414008 1646901 00
160160 136XO7007 14210151646201 00
8058 193392 1429073 1645395 136XO 00
195840 14380338 160 1644579 140XO 00
IM519416438631711ni47 161 140XO 00
8508 1453782 1643004206112 144XO 00
8655 1462436 1642130207715 144XO 00
16413368026 1926141470462 148XO 00
14783397877 189050 1640540 148XO 00
7300 1485719 1639810177110 148XO 00
1492904 16390927 105 172440 148XO 00
16383497425 1702001500329 IXXO 00
77151851701508044 1637570 IXXO 00
173330 15152667222 1636855 IXXO 00
15231481636067 IEOXO4787801 189149 00
1530378 16353447230 173515 IEOXO 00
18090015379157537 1634591 IEOXO 00
ProdoctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 15
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %264 2015/10/31 06:30:00 106.50 106.50 4092 12712 42 15.88 2062 10 36 31.75 28.062 31.097 Flare 31.097 72 0.0265 07:00:00 107.00 107.00 4111 12603 43 15.88 2068 10 38 31.75 28.000 31.681 Flare 31.681 9.930 71 2.880 69.113 119.804 7.050 169.207 1406.996 16476.82 7 136000 0.0266 07:30:00 107.50 107.50 4110 12636 44 15.88 2068 10 38 31.75 28.000 32.264 Flare 32.264 71 0.0267 08:00:00 108.00 108.00 4132 12600 44 15.88 2068 10 38 31.75 28.000 32.847 Flare 32.847 10.850 72 3.038 72.912 122.842 7.812 187.488 1414.808 16469.01 7 136000 0.0268 08:30:00 108.50 108.50 4113 12562 44 15.88 2062 10 38 31.75 28.298 33.434 Flare 33.434 72 0.0269 09:00:00 109.00 109.00 4098 12522 44 15.88 2062 10 38 31.75 28.298 34.023 Flare 34.023 10.010 70 3.003 72.072 125.845 7.007 168.168 1421.815 16462.01 7 136000 0.0270 09:01:00 109.02 109.02 Increase choke to 42/64(16.67mm)271 09:30:00 109.50 109.50 4092 12512 45 16.67 2124 10 38 31.75 29.078 34.621 Flare 34.621 70 0.0272 10:00:00 110.00 110.00 4088 12520 44 16.67 1931 12 38 31.75 30.211 35.239 Flare 35.239 11.850 68 3.792 91.008 129.637 8.058 193.392 1429.873 16453.95 7 136000 0.0273 10:00:00 110.00 110.00 API of condensate taken. API = 47.2 @ 60°F , Specific Gravity = 0.7971, H2S pull 0ppm.274 10:30:00 110.50 110.50 4087 12506 44 16.67 1951 12 39 31.75 30.317 35.869 Flare 35.869 68 0.0275 11:00:00 111.00 111.00 4081 12485 44 16.67 1965 12 39 31.75 30.426 36.502 Flare 36.502 10.880 75 2.720 65.280 132.357 8.160 195.840 1438.033 16445.79 7 140000 0.0276 11:30:00 111.50 111.50 4103 12466 44 16.67 1986 13 38 31.75 30.950 37.141 Flare 37.141 75 0.0277 12:00:00 112.00 112.00 4069 12417 44 16.67 1979 13 38 31.75 30.896 37.785 Flare 37.785 10.230 70 3.069 73.656 135.426 7.161 171.864 1445.194 16438.63 7 140000 0.0278 12:30:00 112.50 112.50 4098 12349 44 16.67 1999 13 38 31.75 31.059 38.431 Flare 38.431 70 0.0279 13:00:00 113.00 113.00 4120 12310 43 16.67 1993 13 38 31.75 31.005 39.077 Flare 39.077 11.300 76 2.712 65.088 138.138 8.588 206.112 1453.782 16430.04 7 144000 0.0280 13:30:00 113.50 113.50 4125 12275 44 16.67 2034 13 37 31.75 31.392 39.727 Flare 39.727 76 0.0281 14:00:00 114.00 114.00 4138 12235 43 16.67 2055 13 37 31.75 31.861 40.386 Flare 40.386 11.240 77 2.585 62.045 140.724 8.655 207.715 1462.436 16421.38 7 144000 0.0282 14:30:00 114.50 114.50 4156 12211 43 16.67 2068 13 38 31.75 31.908 41.050 Flare 41.050 77 0.0283 15:00:00 115.00 115.00 4147 12170 44 16.67 2068 13 37 31.75 32.275 41.719 Flare 41.719 10.560 76 2.534 60.826 143.258 8.026 192.614 1470.462 16413.36 7 148000 0.0284 15:30:00 115.50 115.50 4140 12140 44 16.67 2068 13 37 31.75 32.275 42.391 Flare 42.391 76 0.0285 16:00:00 116.00 116.00 4156 12117 44 16.67 2082 13 37 31.75 32.687 43.068 Flare 43.068 10.230 77 2.353 56.470 145.611 7.877 189.050 1478.339 16405.48 7 148000 0.0286 16:30:00 116.50 116.50 4165 12079 44 16.67 2096 13 36 31.75 32.862 43.751 Flare 43.751 77 0.0287 17:00:00 117.00 117.00 4148 12055 43 16.67 2137 13 36 31.75 32.886 44.436 Flare 44.436 9.710 76 2.330 55.930 147.941 7.380 177.110 1485.719 16398.10 7 148000 0.0288 17:30:00 117.50 117.50 4225 12005 42 16.67 2137 13 36 31.75 32.886 45.121 Flare 45.121 76 0.0289 18:00:00 118.00 118.00 API of condensate taken. API = 47.8 @ 60°F , Specific Gravity = 0.7892, H2S pull 0ppm.290 18:00:00 118.00 118.00 4263 11998 42 16.67 2137 16 36 31.75 35.840 45.837 Flare 45.837 9.580 75 2.395 57.480 150.336 7.185 172.440 1492.904 16390.92 7 148000 0.0291 18:30:00 118.50 118.50 4260 11990 42 16.67 2137 16 36 31.75 36.679 46.592 Flare 46.592 75 0.0292 18:35:00 118.58 118.58 Increase choke to 46/64 (15.88mm)293 19:00:00 119.00 119.00 3866 11806 41 18.26 2137 16 36 31.75 35.840 47.348 Flare 47.348 9.900 75 2.475 59.400 152.811 7.425 178.200 1500.329 16383.49 7 150000 0.0294 19:30:00 119.50 119.50 3785 11676 40 18.26 2206 15 36 31.75 35.556 48.091 Flare 48.091 75 0.0295 19:30:00 119.50 119.50 Change orifice plate1.500 Plate(31.75mm).296 20:00:00 120.00 120.00 3748 11629 39 18.26 1999 11 36 38.10 42.075 48.900 Flare 48.900 10.020 77 2.305 55.310 155.116 7.715 185.170 1508.044 16375.78 7 150000 0.0297 20:30:00 120.50 120.50 3780 11550 42 18.26 1999 11 36 38.10 43.017 49.786 Flare 49.786 77 0.0298 21:00:00 121.00 121.00 3753 11476 39 18.26 2013 12 36 38.10 43.632 50.689 Flare 50.689 9.760 74 2.538 60.902 157.654 7.222 173.338 1515.266 16368.55 7 150000 0.0299 21:30:00 121.50 121.50 3746 11428 42 18.26 2034 12 36 38.10 43.861 51.600 Flare 51.600 74 0.0300 22:00:00 122.00 122.00 3726 11768 40 18.26 2068 11 36 38.10 43.291 52.508 Flare 52.508 10.370 76 2.489 59.731 160.142 7.881 189.149 1523.148 16360.67 7 150000 47.8 0.0301 22:00:00 122.00 122.00 API of condensate taken. API = 47.8 @ 60°F , Specific Gravity = 0.7892, H2S pull 0ppm.302 22:30:00 122.50 122.50 3780 11311 40 18.26 2068 12 36 38.10 44.705 53.425 Flare 53.425 76 0.0303 23:00:00 123.00 123.00 3716 11217 39 18.26 2068 12 36 38.10 44.705 54.356 Flare 54.356 9.770 74 2.540 60.965 162.683 7.230 173.515 1530.378 16353.44 7 150000 0.0304 23:30:00 123.50 123.50 3710 11201 39 18.26 2075 12 36 38.10 44.781 55.288 Flare 55.288 74 0.0305 2015/11/01 00:00:00 124.00 124.00 3704 11197 42 18.26 2082 12 36 38.10 44.857 56.222 Flare 56.222 10.050 75 2.512 60.300 165.195 7.537 180.900 1537.915 16345.91 7 150000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row Tubing
Pres
Well
OwingFlowChoke
Pres TempSne
DnficeDryRowMelar
Babe Dg MIR Plate
Pres Pres TempWze
CumGas Gas
To
TotalGas RdVd
Flared
BSWDlFmn OilRale OICum
Rnid
Water WaterWaterGum
Gain Rate
inertLTRPH SalinilyAPI
dume
2
WW)amfdd
X62015HVOI
hhmmasHrs Hrs
0000001240012400
kPag '0 mmkPag
0000Irmmsdiiig
kPag kPa '0 mm 1tym'id ftyap (I)m''Idm'APIFlowingTubmgpressure=3729kPa
ShutmCasingpressure=11197kPa
Flowingtemperature=39'0
Chokesize=46I64 (1826mm)
GasRate=5070IOVP
Totalguidrate=1005m'Ihr
Waterrecoveryrate=754m'Ihr
Condensaterate=251m'Ihr
PH=7,Salinity=150XOppmBSAW=75S
API=4784960'F,SeparatorH'S=gppmSand=gg'4
Dailyhrsgowed=24hrs
Cumhrsflowed=124hrs
Dailygasproducedtoflarelast24hrs=3200ItPm'um
gasProducedtoflare=5622210'm'ond
Producedlast24hrs= 6503m'um
CondProduced= 16520
m'aterRecoveredlast24
Hrs=18074m'otal
WaterRecovered=153792
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1634591
m'ercentageRecoveredfromInmalLoad= 859'4
Chokeswashedin24bourn=g
Totalchokeswashed=0
0010001241712417
0030001245012450
0100001250012500
Increasechoketo48)64)1905mm)
3693 11132 37 1905 1862 14 36 XI:45749 57166Flee 57166
TwoI o'lockreadmgsduetoAlbertatimechange
310
311
0100001250012500
013100 12552 12552
3664
3604
11103
11038
1905 1862
Ic;5 1862
3810 45749
45341
581 19Flare 58119 9750 75 2437
59099Flee 59099
58500 167633 7312 1755001545228 1633859 7 150XO 00
312 020000 12600 12600 3661 10953 1905 1875 3810 46326 60022Flare 60022 10060 71 2917 70018 170550 7 143 171422 1552370 16331457 152XO478 00
313 020000 12600 12600APIofco4de n APInsatetake ificG60'FSpec478rg ravily0 7892H28pullOppm
314
315
316
317
318
319
0230001265012650
030000 12700 12700
033000 12750 12750
040000 12800 12800
0430001285012850
050000 12900 12900
053000 12950 12950
3639
3461
3510
3479
10857
10853
10748
10696
10632
10532
10576
Ic;5 1882
1905 1931
IcX 2034
1905 1965
IcX 1999
1905 1999
IcX 2041
46006
3810 47013
49528
3810 48259
48276
3810 47860
48363
60984Flee 60984
61953Flare 61953 10220 73 2759
62959Ftze 62959
63977Flare 63977 9530 72 2668
64983Flee 64983
65984Flare 65984 10020 74 2605
66987Flee 6698T
66226
64042
62525
173309 7461
175978 6862
178583 7415
179054
164678
177955
1559831
1566692
1574107
1632399 7
1631713 7
1630971 7
152XO
152XO
152XO
00
00
00
060000 13000 13000 3489 10511 1905 2041 3810 48784 67999Flare 67999 9810 72 2747 65923 181330 7063 16951715811701630265 7 152XO471 00
0600001300013000
0600001300013000
LowPressumOilSamplescaptured490600hrs
APIofcondensatetakenAPI=47I rg60'FSpeoficGravity=0 7924H28pullOppm
063000 13050 13050
070000 13100 13100
073000 13150 13150
080000 13200 13200
083000 13250 13250
090000 13300 13300
0930001335013350
3416
3500
3410
3424
10437
10369
10337
10290
10235
10195
10150
IcX XOI
1 905 2034
IcX 2055
1905 2055
IcX 2055
1905 2062
IcX 2055
34
34 3810
35
36 3810
34
35 3810
34
48891
48891
49882
48952
49565
49132
49145
69016
70035
71064
72093
73119
74147
75171
Ftze 69016
Flare 70035
Flze Tl064
Flare 72093
Ftze T3119
Flare 74147
Ftze T5171
9030 72 2528
9820 74 2553
9920 74 2579
60682
61277
61901
183858
186411
188991
6502
7267
7341
156038 1587672 1629615 7 I52XO
174403 1594939 1628888 7 I52XO
176179 1602279 1628154 7 I52XO
00
00
00
PetroClassFlowTestVersion4.5.0.5
0:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTIHG,.IAweD24864DOWSFlowTestligggsf)6
ProdoctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 16
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %306 2015/11/01 00:00:00 124.00 124.00 00:00 hrs reading
Flowing Tubing pressure = 3729 kPaShut in Casing pressure = 11197 kPaFlowing temperature = 39°CChoke size = 46/64 (18.26mm)Gas Rate = 50.70 10³m³Total fluid rate = 10.05 m³/hrWater recovery rate = 7.54 m³/hrCondensate rate = 2.51 m³/hrPH =7 , Salinity = 150000 ppm, BS&W = 75 %API = 47.8 @ 60°F, Separator H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 124 hrsDaily gas produced to flare last 24 hrs = 32.00 10³m³Cum gas Produced to flare= 56.222 10³m³Cond Produced last 24 hrs = 65.03 m³Cum Cond Produced = 165.20 m³Water Recovered Last 24 Hrs = 180.74 m³Total Water Recovered = 1537.92 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16345.91 m³ Percentage Recovered from Initial Load = 8.59 %Chokes washed in 24 hours=0Total chokes washed =0
307 00:10:00 124.17 124.17 Increase choke to 48/64 (19.05mm)308 00:30:00 124.50 124.50 3693 11132 37 19.05 1862 14 36 38.10 45.749 57.166 Flare 57.166 75 0.0309 01:00:00 125.00 125.00 Two 1 o'clock readings due to Alberta time change.310 01:00:00 125.00 125.00 3664 11103 40 19.05 1862 14 36 38.10 45.749 58.119 Flare 58.119 9.750 75 2.437 58.500 167.633 7.312 175.500 1545.228 16338.59 7 150000 0.0311 01:31:00 125.52 125.52 3604 11038 31 19.05 1862 14 36 38.10 45.341 59.099 Flare 59.099 75 0.0312 02:00:00 126.00 126.00 3661 10953 37 19.05 1875 14 36 38.10 46.326 60.022 Flare 60.022 10.060 71 2.917 70.018 170.550 7.143 171.422 1552.370 16331.45 7 152000 47.8 0.0313 02:00:00 126.00 126.00 API of condensate taken. API = 47.8 @ 60°F , Specific Gravity = 0.7892, H2S pull 0ppm.314 02:30:00 126.50 126.50 3639 10857 36 19.05 1882 14 36 38.10 46.006 60.984 Flare 60.984 71 0.0315 03:00:00 127.00 127.00 3580 10853 40 19.05 1931 14 36 38.10 47.013 61.953 Flare 61.953 10.220 73 2.759 66.226 173.309 7.461 179.054 1559.831 16323.99 7 152000 0.0316 03:30:00 127.50 127.50 3642 10748 41 19.05 2034 15 36 38.10 49.528 62.959 Flare 62.959 73 0.0317 04:00:00 128.00 128.00 3461 10696 39 19.05 1965 15 36 38.10 48.259 63.977 Flare 63.977 9.530 72 2.668 64.042 175.978 6.862 164.678 1566.692 16317.13 7 152000 0.0318 04:30:00 128.50 128.50 3510 10632 40 19.05 1999 14 36 38.10 48.276 64.983 Flare 64.983 72 0.0319 05:00:00 129.00 129.00 3456 10532 39 19.05 1999 14 36 38.10 47.860 65.984 Flare 65.984 10.020 74 2.605 62.525 178.583 7.415 177.955 1574.107 16309.71 7 152000 0.0320 05:30:00 129.50 129.50 3479 10576 39 19.05 2041 14 36 38.10 48.363 66.987 Flare 66.987 74 0.0321 06:00:00 130.00 130.00 3489 10511 39 19.05 2041 14 36 38.10 48.784 67.999 Flare 67.999 9.810 72 2.747 65.923 181.330 7.063 169.517 1581.170 16302.65 7 152000 47.1 0.0322 06:00:00 130.00 130.00 Low Pressure Oil Samples captured @ 06:00 hrs323 06:00:00 130.00 130.00 API of condensate taken. API = 47.1 @ 60°F , Specific Gravity = 0.7924, H2S pull 0ppm.324 06:30:00 130.50 130.50 3416 10437 39 19.05 2034 14 34 38.10 48.891 69.016 Flare 69.016 72 0.0325 07:00:00 131.00 131.00 3500 10369 38 19.05 2034 14 34 38.10 48.891 70.035 Flare 70.035 9.030 72 2.528 60.682 183.858 6.502 156.038 1587.672 16296.15 7 152000 0.0326 07:30:00 131.50 131.50 3441 10337 40 19.05 2055 15 35 38.10 49.882 71.064 Flare 71.064 72 0.0327 08:00:00 132.00 132.00 3434 10290 40 19.05 2055 14 36 38.10 48.952 72.093 Flare 72.093 9.820 74 2.553 61.277 186.411 7.267 174.403 1594.939 16288.88 7 152000 0.0328 08:30:00 132.50 132.50 3410 10235 41 19.05 2055 15 34 38.10 49.565 73.119 Flare 73.119 74 0.0329 09:00:00 133.00 133.00 3485 10195 41 19.05 2062 14 35 38.10 49.132 74.147 Flare 74.147 9.920 74 2.579 61.901 188.991 7.341 176.179 1602.279 16281.54 7 152000 0.0330 09:30:00 133.50 133.50 3424 10150 41 19.05 2055 14 34 38.10 49.145 75.171 Flare 75.171 74 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Time Cum Row Tubing
Pres
Cming
Pres
Flow
Temp
ChokeBshe Dg
Sne Pres Pres
MIR Piste
TempGze
GasRateCumGas Gas
To
TotalGas
Flared
RdVdBSWOlFmn OilRale OtCum Water
Gain
WaterWaterGumleadLTRPH Salinily
IMM
API
WWlmnldd
331 2015IIVOI
hhmmasHrs Hrs
100000 13400 13400
103000 13450 13450
110000 13500 13500
112900 13548 13548
kPag
3531
lncrm
kPag
10123
10102
10055
mm kPag kPa
1905 2062 14
IcX 2068 14
1905 2068 14
e to52I6 4mm)4(206
'0 mm
34 3810
34
34 3810
ltym'Idftpm'8806
t6192Flare
48889 77209Flee
48889 t8228Flare
T6192
Tt209
TB228
II)m'270
73
9200 73
2503
2484
m'Id
m'9616
193977 6716
EO070 191493 6767 162410 1609047 1627477 7 I52XO
161184 161576316268067 152XO
'API
00
00
1130001355013550
120000 13600 13600
3437
31%
10009
9920
2064 2068 14
2064 2130 15
34
35 3810
48889 79246Flee
50395 80280Flare
T9246
80280 10400 75 2600 62400 196577 7800 187200 1623563 1626026 7 I52XO 00
337 1230001365013650
1300001370013700
9010
I ofconde n APInsatetake
i:Et 1765 21
ificG478 @60'7Spec
35
ravily=0 t892
54894 81377Flee
H26pullgppm
8137T
130000 13700 13700
133000 13750 13750
140000 13800 13800
1430001385013850
1500001390013900
1530001395013950
1600001400014000
1630001405014050
170000 14100 14100
173000 14150 14150
3066
2909
2959
2934
2903
2973
2896
2897
9758
9690
9625
9537
9495
9434
9396
9332
9309
9255
2064 1758 21
i:Et 1448 26
2064 1448 26
i:Et 1503 27
2064 1503 26
i:Et 1496 26
2064 1510 26
i:Et 1503 26
2064 1496 26
i:Et 1475 26
34 3810
35
35 3810
34
34 3810
34
34 3810
34
34 3810
34
54570 82517Flare
55447 83663Flse
55447 84819Flare
57121 85991Flse
56595 871 76Flare
56202 88351Flee
56460 89524Flare
56331 90699Flee
56202 91871Flare
55549 93035Flee
8251T
83663
84819
85991
87176
88351
89524
90699
91871
93035
9720 74
9690 75
9520 76
9100 76
9480 76
2527
2422
2285
2 1 84
2275
EO653 199105 7 193
58140 201527 7267
54835 203812 7235
52416 205996 6916
54605 208271 7205
172627 1630755 1625306 7 I53XO
174420 1638023 1624580 7 I53XO
173645 1645258 1623856 7 I53XO
165984 1652174 1623165 7 I53XO
172915 1659379 1622444 7 154XO
481
00
00
00
00
00
180000 14200 14200 I ofconde n APInsatetake ificG481@60'7Spec ravily=0 t879H26pullgppm
351
357
180000 14200 14200
183000 14250 14250
190000 14300 14300
193000 14350 14350
200000 14400 14400
2030001445014450
210000 14500 14500
213000 14550 14550
220000 14600 14600
2868
2841
2850
2838
2841
2838
2843
2813
2816
9211
9184
9122
9084
9039
9002
8962
8941
8844
2064 1482 26
i:Et 1503 26
2064 1503 26
i:Et 1482 26
2064 1482 26
i:Et 1496 26
2064 1503 26
i:Et 1510 26
2064 1482 25
34 3810
34
34 3810
34
34 3810
34
34 3810
34
34 3810
55679 94194Flare
55798 95355Flee
56595 96526Flare
55679 97696Flee
55943 98858Flare
55670 100021Ftse
56065 101185Flare
56193 102354Flse
55147 103514Flare
95355
96526
97696
98858
IX021
101185
102354
103514
9100 75
9590 76
9230 76
9070 76
9140 77
2275
2302
2215
2 177
2102
54600 210546 6825
55238 212848 7288
53165 215063 7015
52243 217240 6893
50453 219342 7038
163800 1666204 1621762 7 I54XO
174922 1673492 1621033 7 154XO
168355 1680507 1620331 7 154XO
165437 1687400 1 619642 7 I54XO
168907 1694438 1 618938 7 I54XO481
00
00
00
00
00
2200001460014600 I ofconde n APInsatetake ificG481@60'7Spec ravily=0 t879H26pullgppm
363 2015IIV02
2230001465014650
2300001470014700
2330001475014750
0000001480014800
2803
2758
2752
2748
8856
8830
8824
8819
i:Et 1510 25
2064 1496 25
i:Et 151tl 25
2064 1489 25
34
34 3810
34
34 3810
55386 104665Flee
55402 105819Flare
55114 106971Ftse
55006 108118Flare
104665
105819
106971
108118
9780 77
9100 75
2249
2275
53986 221591 7531
54600 223866 6825
180734 1701969 1 618185 7 I54XO
163800 1708794 1 617503 7 I54XO
00
00
PetroClassFlowTestVersion4.5.0.5
0iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTEST)MG,.IAweD24864DOWBFlowTestlibgth)l7
ProdnctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 17
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %331 2015/11/01 10:00:00 134.00 134.00 3531 10123 41 19.05 2062 14 34 38.10 48.806 76.192 Flare 76.192 9.270 73 2.503 60.070 191.493 6.767 162.410 1609.047 16274.77 7 152000 0.0332 10:30:00 134.50 134.50 3594 10102 41 19.05 2068 14 34 38.10 48.889 77.209 Flare 77.209 73 0.0333 11:00:00 135.00 135.00 3434 10055 42 19.05 2068 14 34 38.10 48.889 78.228 Flare 78.228 9.200 73 2.484 59.616 193.977 6.716 161.184 1615.763 16268.06 7 152000 0.0334 11:29:00 135.48 135.48 Increase choke to 52/64 (20.64mm)335 11:30:00 135.50 135.50 3437 10009 42 20.64 2068 14 34 38.10 48.889 79.246 Flare 79.246 73 0.0336 12:00:00 136.00 136.00 3156 9920 42 20.64 2130 15 35 38.10 50.395 80.280 Flare 80.280 10.400 75 2.600 62.400 196.577 7.800 187.200 1623.563 16260.26 7 152000 0.0337 12:30:00 136.50 136.50 3055 9010 42 20.64 1765 21 35 38.10 54.894 81.377 Flare 81.377 75 0.0338 13:00:00 137.00 137.00 API of condensate taken. API = 47.8 @ 60°F , Specific Gravity = 0.7892, H2S pull 0ppm.339 13:00:00 137.00 137.00 3066 9758 42 20.64 1758 21 34 38.10 54.570 82.517 Flare 82.517 9.720 74 2.527 60.653 199.105 7.193 172.627 1630.755 16253.06 7 153000 0.0340 13:30:00 137.50 137.50 2909 9690 42 20.64 1448 26 35 38.10 55.447 83.663 Flare 83.663 74 0.0341 14:00:00 138.00 138.00 3042 9625 42 20.64 1448 26 35 38.10 55.447 84.819 Flare 84.819 9.690 75 2.422 58.140 201.527 7.267 174.420 1638.023 16245.80 7 153000 0.0342 14:30:00 138.50 138.50 3044 9537 40 20.64 1503 27 34 38.10 57.121 85.991 Flare 85.991 75 0.0343 15:00:00 139.00 139.00 2959 9495 40 20.64 1503 26 34 38.10 56.595 87.176 Flare 87.176 9.520 76 2.285 54.835 203.812 7.235 173.645 1645.258 16238.56 7 153000 0.0344 15:30:00 139.50 139.50 2934 9434 40 20.64 1496 26 34 38.10 56.202 88.351 Flare 88.351 76 0.0345 16:00:00 140.00 140.00 2903 9396 41 20.64 1510 26 34 38.10 56.460 89.524 Flare 89.524 9.100 76 2.184 52.416 205.996 6.916 165.984 1652.174 16231.65 7 153000 0.0346 16:30:00 140.50 140.50 2973 9332 41 20.64 1503 26 34 38.10 56.331 90.699 Flare 90.699 76 0.0347 17:00:00 141.00 141.00 2896 9309 41 20.64 1496 26 34 38.10 56.202 91.871 Flare 91.871 9.480 76 2.275 54.605 208.271 7.205 172.915 1659.379 16224.44 7 154000 0.0348 17:30:00 141.50 141.50 2897 9255 41 20.64 1475 26 34 38.10 55.549 93.035 Flare 93.035 76 48.1 0.0349 18:00:00 142.00 142.00 API of condensate taken. API = 48.1 @ 60°F , Specific Gravity = 0.7879, H2S pull 0ppm.350 18:00:00 142.00 142.00 2868 9211 41 20.64 1482 26 34 38.10 55.679 94.194 Flare 94.194 9.100 75 2.275 54.600 210.546 6.825 163.800 1666.204 16217.62 7 154000 0.0351 18:30:00 142.50 142.50 2841 9184 41 20.64 1503 26 34 38.10 55.798 95.355 Flare 95.355 75 0.0352 19:00:00 143.00 143.00 2850 9122 40 20.64 1503 26 34 38.10 56.595 96.526 Flare 96.526 9.590 76 2.302 55.238 212.848 7.288 174.922 1673.492 16210.33 7 154000 0.0353 19:30:00 143.50 143.50 2838 9084 40 20.64 1482 26 34 38.10 55.679 97.696 Flare 97.696 76 0.0354 20:00:00 144.00 144.00 2841 9039 40 20.64 1482 26 34 38.10 55.943 98.858 Flare 98.858 9.230 76 2.215 53.165 215.063 7.015 168.355 1680.507 16203.31 7 154000 0.0355 20:30:00 144.50 144.50 2838 9002 40 20.64 1496 26 34 38.10 55.670 100.021 Flare 100.021 76 0.0356 21:00:00 145.00 145.00 2843 8962 40 20.64 1503 26 34 38.10 56.065 101.185 Flare 101.185 9.070 76 2.177 52.243 217.240 6.893 165.437 1687.400 16196.42 7 154000 0.0357 21:30:00 145.50 145.50 2813 8941 39 20.64 1510 26 34 38.10 56.193 102.354 Flare 102.354 76 0.0358 22:00:00 146.00 146.00 2816 8844 39 20.64 1482 25 34 38.10 55.147 103.514 Flare 103.514 9.140 77 2.102 50.453 219.342 7.038 168.907 1694.438 16189.38 7 154000 48.1 0.0359 22:00:00 146.00 146.00 API of condensate taken. API = 48.1 @ 60°F , Specific Gravity = 0.7879, H2S pull 0ppm.360 22:30:00 146.50 146.50 2803 8856 39 20.64 1510 25 34 38.10 55.386 104.665 Flare 104.665 77 0.0361 23:00:00 147.00 147.00 2758 8830 38 20.64 1496 25 34 38.10 55.402 105.819 Flare 105.819 9.780 77 2.249 53.986 221.591 7.531 180.734 1701.969 16181.85 7 154000 0.0362 23:30:00 147.50 147.50 2752 8824 38 20.64 1510 25 34 38.10 55.114 106.971 Flare 106.971 77 0.0363 2015/11/02 00:00:00 148.00 148.00 2748 8819 39 20.64 1489 25 34 38.10 55.006 108.118 Flare 108.118 9.100 75 2.275 54.600 223.866 6.825 163.800 1708.794 16175.03 7 154000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMelar Rnid dume
2
WWfamfdd
364 2015IIV02
Time Cum Row
hhmmasHrs Hrs
0000001480014800
TubingOwing
Pres Pres
kPag kPag
0000Irmmsdir10
FlowChokeBabe
TempSne Pres
'0 mm kPart
Dg
Pres
MIR
Temp
mm 1tym'id
CumGas Gas
To
TotalGas RdVd BSW
Flared
ftyap (ljm'''Idm'IGan
OilRale OIGum Watw
Gain
WaterGumleadLTRPH SalinilyAPI Smd
Cd
'API
FlowingTubmgpressure=2748kPa
ShutmCasingpressure=8819kPa
Flowingtemperature=39'0
Chokesize=58'64f2064mmi
GasRate=5816IOVP
Totalguidrate=9 10 m'Ihr
Waterrecoveryrate=682m'Ihr
Condensaterate=228m'Ihr
PH=t,Salinity=154XOppmBSBW=75S
API=481@60'6,SeparatorH'S=gppmSand=gg'I
Dailyhrsgowed=24hrs
Cumhrsflowed=148hrs
Dailygasproducedtoflarelast24hrs=51901tPm'um
gasProducedtoflare=108II8 IOVP
CondProducedlast24hrs= 586tm'um
CondProduced=22387
m'aterRecoveredlast24
Hrs=17088m'otal
WaterRecovered=1708t9m'nmalLoadFluidtoRecover=
1788382m'oad
FluidLetttoRecover= 1617503
m'ercentageRecoveredfromInmalLoad= 959'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
003000 14850 14850
010000 14900 14900
013000 14950 14950
2749 8734
2731 8696
2742 8660
41 i:64 1496
39 2064 1503
38 i:64 1510
25 34
25 34 3810
25 34
54862 109262Flee 109262
54988 110406Flare 110406
551 14 I1 1 553Flee 111 553
9580 75 2395 57480 226261 7 185 1724401715979 1616784 7 156XO 00
020000 15000 15000 2719 8629 40 2064 1503 25 34 3810 54988 112700Flare 112700 9240 76 2218 53222 228479 7022 168538 1723001 1616082 7 157XO482 00
0200001500015000APIofcoeds ificGravity=0 t873n API=482@60'FSpecnsatetake H26pullgppm
3TO
3TI
3T4
3T5
376
0230001505015050
030000 15100 15100
033000 15150 15150
040000 15200 15200
043000 15250 15250
050000 15300 15300
053000 15350 15350
2706 8542
2691 8564
2671 8344
2661 8310
2667 8406
2661 8462
2669 8499
38 i:64 1462
37 2064 1496
38 i:64 1475
38 2064 1475
37 i:64 1475
37 2064 1448
37 i:64 1448
25 34
25 34 3810
24 34
24 34 3810
24 34
24 34 3810
24 34
54229 113838Flee 113838
54862 114974Flare 114974
53941 116108Flze 116108
53941 117231Flare 117231
53941 118355Flee 118355
53437 119474Flare 119474
53437 120587Ftze 12058T
9920
9210
9150
77 2282 54758
75 2302 55260
76 2196 52704
230761
233063
235259
7638 183322
6907 165780
6954 166896
1730639
1737547
1744501
1615318
1614627
1613932
7 1$IXO
7 1$IXO
7 158XO
00
00
00
378
0600001540015400
0600001540015400
0600001540015400
2654 8512 37 2064 1448 25 34 3810 53t06 121703Flare 121703
LowPressumOilSamplescaptured@0600hrs
APIofcondensatetakenAPI=482@60'6SpeoficGravity=0 t873H26pullgppm
9720 75 2430 58320 237689 7290 174960 17517911613203 7 158XO482 00
0630001545015450
0700001550015500
0730001555015550
0800001560015600
0830001565015650
0900001570015700
0930001575015750
1000001580015800
103000 15850 15850
2644
2640
2593
2610
2625
2591
2569
2515
2514
8391
8350
8319
8303
8279
8253
8233
8217
8180
i:64 1420 24
2064 1427 24
i:64 1434 24
2064 1407 23
i:64 1455 24
2064 1400 24
i:64 1379 24
2064 1393 23
i:64 1379 24
3810
3810
3810
3810
52661 122811
53056 123912
52372 125010
51695 126094
52845 127183
52206 128278
51726 129360
51172 130432
51459 1 31501
Ftze 122811
Flare 123912
Ftze 125010
Flare 126094
Ftze 127183
Flare 128278
Ftze 129360
Flare IX432
Ftze 131501
9010
8700
8200
8450
2 162 51898 239851 6848
2175 52200 242026 6525
I 968 47232 243994 6232
2 113 50700 246107 6337
164342
156600
149568
152100
1758639 1612518
17651641611866
1771396 1611242
1777733 1610609
1$IXO
1$IXO
158XO
158XO
00
00
00
00
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD24864DOWSFlowTestllbQIMII8
ProdoctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 18
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %364 2015/11/02 00:00:00 148.00 148.00 00:00 hrs reading
Flowing Tubing pressure = 2748 kPaShut in Casing pressure = 8819 kPaFlowing temperature = 39°CChoke size = 52/64 (20.64mm)Gas Rate = 58.16 10³m³Total fluid rate = 9.10 m³/hrWater recovery rate = 6.82 m³/hrCondensate rate = 2.28 m³/hrPH =7 , Salinity = 154000 ppm, BS&W = 75 %API = 48.1 @ 60°F, Separator H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 148 hrsDaily gas produced to flare last 24 hrs = 51.90 10³m³Cum gas Produced to flare= 108.118 10³m³Cond Produced last 24 hrs = 58.67 m³Cum Cond Produced = 223.87 m³Water Recovered Last 24 Hrs = 170.88 m³Total Water Recovered = 1708.79 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16175.03 m³ Percentage Recovered from Initial Load = 9.59 %Chokes washed in 24 hours=0Total chokes washed =0
365 00:30:00 148.50 148.50 2749 8734 41 20.64 1496 25 34 38.10 54.862 109.262 Flare 109.262 75 0.0366 01:00:00 149.00 149.00 2731 8696 39 20.64 1503 25 34 38.10 54.988 110.406 Flare 110.406 9.580 75 2.395 57.480 226.261 7.185 172.440 1715.979 16167.84 7 156000 0.0367 01:30:00 149.50 149.50 2742 8660 38 20.64 1510 25 34 38.10 55.114 111.553 Flare 111.553 75 0.0368 02:00:00 150.00 150.00 2719 8629 40 20.64 1503 25 34 38.10 54.988 112.700 Flare 112.700 9.240 76 2.218 53.222 228.479 7.022 168.538 1723.001 16160.82 7 157000 48.2 0.0369 02:00:00 150.00 150.00 API of condensate taken. API = 48.2 @ 60°F , Specific Gravity = 0.7873, H2S pull 0ppm.370 02:30:00 150.50 150.50 2706 8542 38 20.64 1462 25 34 38.10 54.229 113.838 Flare 113.838 76 0.0371 03:00:00 151.00 151.00 2691 8564 37 20.64 1496 25 34 38.10 54.862 114.974 Flare 114.974 9.920 77 2.282 54.758 230.761 7.638 183.322 1730.639 16153.18 7 158000 0.0372 03:30:00 151.50 151.50 2671 8344 38 20.64 1475 24 34 38.10 53.941 116.108 Flare 116.108 77 0.0373 04:00:00 152.00 152.00 2661 8310 38 20.64 1475 24 34 38.10 53.941 117.231 Flare 117.231 9.210 75 2.302 55.260 233.063 6.907 165.780 1737.547 16146.27 7 158000 0.0374 04:30:00 152.50 152.50 2667 8406 37 20.64 1475 24 34 38.10 53.941 118.355 Flare 118.355 75 0.0375 05:00:00 153.00 153.00 2661 8462 37 20.64 1448 24 34 38.10 53.437 119.474 Flare 119.474 9.150 76 2.196 52.704 235.259 6.954 166.896 1744.501 16139.32 7 158000 0.0376 05:30:00 153.50 153.50 2669 8499 37 20.64 1448 24 34 38.10 53.437 120.587 Flare 120.587 76 0.0377 06:00:00 154.00 154.00 2654 8512 37 20.64 1448 25 34 38.10 53.706 121.703 Flare 121.703 9.720 75 2.430 58.320 237.689 7.290 174.960 1751.791 16132.03 7 158000 48.2 0.0378 06:00:00 154.00 154.00 Low Pressure Oil Samples captured @ 06:00 hrs379 06:00:00 154.00 154.00 API of condensate taken. API = 48.2 @ 60°F , Specific Gravity = 0.7873, H2S pull 0ppm.380 06:30:00 154.50 154.50 2644 8391 37 20.64 1420 24 34 38.10 52.661 122.811 Flare 122.811 75 0.0381 07:00:00 155.00 155.00 2640 8350 38 20.64 1427 24 34 38.10 53.056 123.912 Flare 123.912 9.010 76 2.162 51.898 239.851 6.848 164.342 1758.639 16125.18 7 158000 0.0382 07:30:00 155.50 155.50 2593 8319 38 20.64 1434 24 34 38.10 52.372 125.010 Flare 125.010 76 0.0383 08:00:00 156.00 156.00 2610 8303 38 20.64 1407 23 33 38.10 51.695 126.094 Flare 126.094 8.700 75 2.175 52.200 242.026 6.525 156.600 1765.164 16118.66 7 158000 0.0384 08:30:00 156.50 156.50 2625 8279 38 20.64 1455 24 33 38.10 52.845 127.183 Flare 127.183 75 0.0385 09:00:00 157.00 157.00 2591 8253 38 20.64 1400 24 32 38.10 52.206 128.278 Flare 128.278 8.200 76 1.968 47.232 243.994 6.232 149.568 1771.396 16112.42 7 158000 0.0386 09:30:00 157.50 157.50 2569 8233 38 20.64 1379 24 33 38.10 51.726 129.360 Flare 129.360 76 0.0387 10:00:00 158.00 158.00 2515 8217 38 20.64 1393 23 33 38.10 51.172 130.432 Flare 130.432 8.450 75 2.113 50.700 246.107 6.337 152.100 1777.733 16106.09 7 158000 0.0388 10:30:00 158.50 158.50 2514 8180 38 20.64 1379 24 33 38.10 51.459 131.501 Flare 131.501 75 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
TubingCmingFlow
Pres Pres Temp
QmksSkdm
Bue Pma
OnficeDryRowMalar
Dg MIR
Pres Temp
CumGas Gas
To
TotalGas RdVd BSW
Flared
OIGanOilRale
Rnid
OlCum Water
Gain
WaterCumlnarlLTRPH SalinilyAPI
dume
2
WW)mnfddhhmmssHrs Hrs kPag kPag '0 mm kPag kPa '0 mm 1tym'ld ftyay (I)m'''Idm'pm'API
389 2015HV02110000
113000
120000
120000
1590015900
1595015950
1600016000
1600016000
2540 8164 38
2541 8144 38
2544 8131 38
I ofcondensatetakenAPI
2064 1379
i:64 1379
2064 1386
60'FSpec484@
23 34
23 34
23 34
ificGravily
3810
3810
0 7867
13256750826
13362851096
IM69451222
H23pullOppm
Flare
Ftze
Flare
13256T 7830 75
133628
134694 7960 74
1 957 Ri980
2070 49670
248064 5872
250134 5890
140940
141370
1783606 1610021 7
1789496 1609432 7
158XO
158XO
00
00
123000
130000
133000
140000
143000
1605016050
16100 16100
16150 16150
16200 16200
16250 16250
2652 8093 38
2646 8086 38
2578 8047 39
2450 8035 39
2462 8039 39
i:64 1379
2064 1379
i:64 1379
2064 1386
i:64 1386
23 34
23 34
23 34
23 34
23 34
3810
3810
50826
50826
5tl555
50680
50407
135757
136816
137872
138927
139980
Ftze
Flare
Ftze
Flare
Ftze
13575T
136816 7 150 75
137872
13892T 7000 75
139980
I 788 42900
I 750 42000
251922 5362
253672 5250
128700
126000
1794858 1608896 7
1800108 1608371 7
160XO
160XO
00
00
401
150000
153000
153100
160000
1630016300
1635016350
1635216352
1640016400
lncrm
2481 7977 39
2440 7961 39
sechoketo56I64(222
23lni 7941 39
2064 1386
i:64 1386
3mm)
2223 1372
23 34
23 34
22 33
3810
3810
50680
50680
49977
141033
142089
143137
Flare
Ftze
Flare
141033 6750 74
142089
14313T 7560 75
I 755 42120
1 990 45360
255427 4995
257317 5670
119880
136080
1805103 1607872 7
1810773 1607305 7
160XO
160XO
00
00
163000
170000
173000
180000
180000
1645016450
1650016500
1655016550
1660016600
1660016600
2420 7918 39
2433 8262 39
2510 7901 39
2577 7891 39
1800Irmmsdirig
iiii 1379
2223 1379
iiii 1393
2223 1379
22 33
20 33
24 33
24 33
3810
3810
50101
47264
51982
51459
144180
145194
146228
147305
Ftze
Flare
Ftze
Flare
144180
145194 7380 76
146228
147305 7240 75
I 771 42509
1 910 43440
259088 5609
260898 5430
134611
130320
1816382 1606744 7
1821812 1606201 7
160XO
160XO
00
00
FlowingTubmgpressure=257tkPa
ShutmCasingpressure=7891kPa
Flowingtemperature=39'0
Chokesize=56I64I2064mml
GasRate=5443IOVP
TotaHluidrate=724 m'Ihr
Waterrecoveryrate=543m'Ihr
Condensaterate= 1 81m'Ihr
PH=t,Salinity=160XOppmBSBW=75S
API=481@60'6,SeparatorH'S=gppmSand=00'I
DailyhrsBowed=18hrs
Cumhrsflowed=166hrs
Dailygasproducedtoflarelast18hrs=39191tPm'um
gasProducedtoflare=14730510VP
CondProducedlast18hrs=3703m'um
CondProduced=26090
m'aterRecoveredlast18Hrs=11302m'otal
WaterRecovered=182181
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1606201
m'ercentageRecoveredfromInmalLoad= 1019H
Chokeswashedin18houm=0
Totalchokeswashed=0
407
410
411
412
413
183000
190000
193000
200000
203000
210000
213000
1665016650
1670016700
1675016750
1680016800
1685016850
1690016900
1695016950
2417 7883 39
2419 7840 37
2396 7813 39
2326 7807 37
2528 7791 37
2313 7775 37
2416 7757 38
iiii 1103
2223 1103
iiii 1103
2223 1138
riii 1158
2223 1172
riii 1158
27 33 XI: 49587
28 33 3810 50029
28 33 XI: 50029
27 33 3810 49882
27 33 XI: 50091
27 33 3810 50613
27 33 XI: 50551
148358
149395
150438
151478
152520
153569
154622
Flze 148358
Flare 149395
Flee 150438
Flare 151478
Ftze 152520
Flare 153569
Flee 154622
7320
7840
7890
75 1 930
76 I 882
75 1 973
43920 262728
45158 264609
47340 266582
5490 131760 1827302 1605652
5958 143002 1833261 1605056
5917 142020 1939178 1604464
ISIXO
158XO
ISIXO
00
00
00
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD248649OWSFlowTestlgkgghll9
ProdnctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 19
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %389 2015/11/02 11:00:00 159.00 159.00 2540 8164 38 20.64 1379 23 34 38.10 50.826 132.567 Flare 132.567 7.830 75 1.957 46.980 248.064 5.872 140.940 1783.606 16100.21 7 158000 0.0390 11:30:00 159.50 159.50 2541 8144 38 20.64 1379 23 34 38.10 51.096 133.628 Flare 133.628 75 0.0391 12:00:00 160.00 160.00 2544 8131 38 20.64 1386 23 34 38.10 51.222 134.694 Flare 134.694 7.960 74 2.070 49.670 250.134 5.890 141.370 1789.496 16094.32 7 158000 0.0392 12:00:00 160.00 160.00 API of condensate taken. API = 48.4 @ 60°F , Specific Gravity = 0.7867, H2S pull 0ppm.393 12:30:00 160.50 160.50 2652 8093 38 20.64 1379 23 34 38.10 50.826 135.757 Flare 135.757 74 0.0394 13:00:00 161.00 161.00 2646 8086 38 20.64 1379 23 34 38.10 50.826 136.816 Flare 136.816 7.150 75 1.788 42.900 251.922 5.362 128.700 1794.858 16088.96 7 160000 0.0395 13:30:00 161.50 161.50 2578 8047 39 20.64 1379 23 34 38.10 50.555 137.872 Flare 137.872 75 0.0396 14:00:00 162.00 162.00 2450 8035 39 20.64 1386 23 34 38.10 50.680 138.927 Flare 138.927 7.000 75 1.750 42.000 253.672 5.250 126.000 1800.108 16083.71 7 160000 0.0397 14:30:00 162.50 162.50 2462 8039 39 20.64 1386 23 34 38.10 50.407 139.980 Flare 139.980 75 0.0398 15:00:00 163.00 163.00 2481 7977 39 20.64 1386 23 34 38.10 50.680 141.033 Flare 141.033 6.750 74 1.755 42.120 255.427 4.995 119.880 1805.103 16078.72 7 160000 0.0399 15:30:00 163.50 163.50 2440 7961 39 20.64 1386 23 34 38.10 50.680 142.089 Flare 142.089 74 0.0400 15:31:00 163.52 163.52 Increase choke to 56/64 (22.23mm)401 16:00:00 164.00 164.00 2386 7941 39 22.23 1372 22 33 38.10 49.977 143.137 Flare 143.137 7.560 75 1.890 45.360 257.317 5.670 136.080 1810.773 16073.05 7 160000 0.0402 16:30:00 164.50 164.50 2420 7918 39 22.23 1379 22 33 38.10 50.101 144.180 Flare 144.180 75 0.0403 17:00:00 165.00 165.00 2433 8262 39 22.23 1379 20 33 38.10 47.264 145.194 Flare 145.194 7.380 76 1.771 42.509 259.088 5.609 134.611 1816.382 16067.44 7 160000 0.0404 17:30:00 165.50 165.50 2510 7901 39 22.23 1393 24 33 38.10 51.982 146.228 Flare 146.228 76 0.0405 18:00:00 166.00 166.00 2577 7891 39 22.23 1379 24 33 38.10 51.459 147.305 Flare 147.305 7.240 75 1.810 43.440 260.898 5.430 130.320 1821.812 16062.01 7 160000 0.0406 18:00:00 166.00 166.00 18:00 hrs reading
Flowing Tubing pressure = 2577 kPaShut in Casing pressure = 7891 kPaFlowing temperature = 39°CChoke size = 56/64 (20.64mm)Gas Rate = 54.43 10³m³Total fluid rate = 7.24 m³/hrWater recovery rate = 5.43 m³/hrCondensate rate = 1.81 m³/hrPH =7 , Salinity = 160000 ppm, BS&W = 75 %API = 48.1 @ 60°F, Separator H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 18 hrs Cum hrs flowed = 166 hrsDaily gas produced to flare last 18 hrs = 39.19 10³m³Cum gas Produced to flare= 147.305 10³m³Cond Produced last 18 hrs = 37.03 m³Cum Cond Produced = 260.90 m³Water Recovered Last 18 Hrs = 113.02 m³Total Water Recovered = 1821.81 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16062.01 m³ Percentage Recovered from Initial Load = 10.19 %Chokes washed in 18 hours=0Total chokes washed =0
407 18:30:00 166.50 166.50 2417 7883 39 22.23 1103 27 33 38.10 49.587 148.358 Flare 148.358 75 0.0408 19:00:00 167.00 167.00 2419 7840 37 22.23 1103 28 33 38.10 50.029 149.395 Flare 149.395 7.320 75 1.830 43.920 262.728 5.490 131.760 1827.302 16056.52 7 158000 0.0409 19:30:00 167.50 167.50 2396 7813 39 22.23 1103 28 33 38.10 50.029 150.438 Flare 150.438 75 0.0410 20:00:00 168.00 168.00 2326 7807 37 22.23 1138 27 33 38.10 49.882 151.478 Flare 151.478 7.840 76 1.882 45.158 264.609 5.958 143.002 1833.261 16050.56 7 158000 0.0411 20:30:00 168.50 168.50 2528 7791 37 22.23 1158 27 33 38.10 50.091 152.520 Flare 152.520 76 0.0412 21:00:00 169.00 169.00 2313 7775 37 22.23 1172 27 33 38.10 50.613 153.569 Flare 153.569 7.890 75 1.973 47.340 266.582 5.917 142.020 1839.178 16044.64 7 158000 0.0413 21:30:00 169.50 169.50 2416 7757 38 22.23 1158 27 33 38.10 50.551 154.622 Flare 154.622 75 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
Tubing0 ming
Pres Pres
FlowChokeBshe
TempSns Pres
OnficeDryRowMalar
Dg MIR Piste GasRatsCumGasGas TolalGasRdVd
Pres TempGze To Flared
BSWOIGanOilRale 01Cum
Rnid
Wstw WsHr
Gain Rate
WaterGumleadLTRPH SalinilyAPI
dume
2
WWlmnlddhhmmasHrs Hrs kPag kPag '0 mm kPag kPa '0 mm IIFm'id ID'm'tpop(ljm'''Idm'pm'API
414 2015HV02220000 17000 17000 2314 7741 37 2223 1165 27 33 381 0 50467 1 55675Flare 155675 7810 76 I 874 44986 268456 5936 142454 18451141603871 7 158XO468 00
415 2200001700017000APIofcondo ificGravity=0 t9XH26pullOppmn API=468@60'FSpecnsatetake
416
417
418
419 2015HV03
223000 17050 17050
230000 17100 17100
233000 17150 17150
000000 17200 17200
000000 17200 17200
2322 7711
2405 7709
2412 7708
2407 7706
0000Irmmsdiilg
37 iiii 1172
38 2223 1172
38 iiii 1165
38 2223 1158
27 33 XI: 50381 156725Flee 156725
26 33 381 0 50149 1 57772Flare 157772 7580
27 33 XI: 50697 158823Flee 158823
27 33 381 0 50322 1 59875Flare 159875 7720
76 I 819 43661
75 I 930 Ri320
270275
272205
5761 138259
5790 138960
1850875
1856665
1603295
1602716
7 160XO
7 160XO
00
00
FlowingTubmgpressure=240ttPa
ShutmCasingpressure=7706kPa
Flowingtemperature=38'0
Chokesize=56I64f2223mml
GasRate=5326IOVP
TotaHluidrate=7t2m'Ihr
Waterrecoveryrate=579m'Ihr
Condensaterate= 1 93m'Ihr
PH=7, Salinity=160XOppmBSSW=75'I
API=468@60'6,SeparatorH'S=gppmSand=gg'I
Dailyhrsgowed=24hrs
Cumhrsflowed=172hrs
Dailygasproducedtoflarelast24hrs=51t61tPm'um
gasProducedtoflare=15987510VP
CondProducedlast24hrs= 4834m'um
CondProduced=27221
m'aterRecoveredlast24Hrs=14787m'otal
WaterRecovered=185666
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1602t16
m'ercentageRecoveredfromInmalLoad= 1038H
Chokeswashedin24bourn=g
Totalchokeswashed=0
421 003000 17250 17250
0100001730017300
2444
2344
7637
7616
r'o2223
1172
1172
Jc I
'810
49680 160917Flee 16091T
49444 161949Flare 161949 7870 76 I 889 45331 274094 5981 143549 1862646 1602117 7 160XO 00
424
0130001735017350
0200001740017400
0200001740017400
2430
2449
7605
7580
I ofcondensatetaken API
1172r'o2223 1172
ificG60'FSpec471M ravily
Jc I
'810
0 7924
48880 162974Ftae 162974
48640 163989Flare 163989
H26pullgppm
7150 77 I 644 39468 275739 5506 132132 18681 51 1601567 7 166XO471 00
431
0230001745017450
030000 17500 17500
033000 17550 17550
040000 17600 17600
0430001765017650
050000 17700 17700
053000 17750 17750
060000 17800 17800
2418
2404
2363
2334
2315
2264
2310
2299
7594
7503
7568
7514
7515
7502
7511
7499
2223
r'o2223
r'o2223
r'o2223
1172
1172
1172
1186
1186
1172
1165
1172
Jc I
'810
Jc I
'810
Jc I
'810
Jc I
'810
48640 165003Ftae 165003
48488 1 66015Flare 166015
48245 167022Ftae 167022
48919 168034Flare 168034
48522 169049Flee 169049
48158 I70056Flare 170056
47534 1 71053Flee 171053
47915 172047Flare 172047
7050
7740
7370
7510
76 1 692 X608
75 1 935 Ri440
75 1 842 44220
76 1 802 43258
277431
279366
281208
283011
5358 128592
5805 139320
5527 132660
5708 136982
1873509 1601031
1879314 1600451
1884842 1599898
1890549 1599327
7 166XO
7 166XO
7 166XO
7 166XO471
00
00
00
00
0600001780017800
0630001785017850
0700001790017900
2299
2328
7451
7420
I ofcondensatetaken API ificG60'FSpec471@ ravily
1172
2223 1172
0 7924H26pullgppm
Jc I
'810
48002 1 73047Flare 173047
48002 1 74047Ftae 17404T 7370 75 1 842 44220 284853 5527 132660 1896077 1598774 7 166XO 00
437 0730001795017950
080000 18000 18000
2453
2462
7402
7397
r'o2223
1172
1172
Jc I
'810
48245 175049Flare 175049
48245 1 76054Flee 176054 6850 75 1 713 41100 286566 5 138 1233001901214 1598261 7 166XO 00
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD24864DOWSFlowTestlSQRPO
ProdnctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 20
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %414 2015/11/02 22:00:00 170.00 170.00 2314 7741 37 22.23 1165 27 33 38.10 50.467 155.675 Flare 155.675 7.810 76 1.874 44.986 268.456 5.936 142.454 1845.114 16038.71 7 158000 46.8 0.0415 22:00:00 170.00 170.00 API of condensate taken. API = 46.8 @ 60°F , Specific Gravity = 0.7930, H2S pull 0ppm.416 22:30:00 170.50 170.50 2322 7711 37 22.23 1172 27 33 38.10 50.381 156.725 Flare 156.725 76 0.0417 23:00:00 171.00 171.00 2405 7709 38 22.23 1172 26 33 38.10 50.149 157.772 Flare 157.772 7.580 76 1.819 43.661 270.275 5.761 138.259 1850.875 16032.95 7 160000 0.0418 23:30:00 171.50 171.50 2412 7708 38 22.23 1165 27 33 38.10 50.697 158.823 Flare 158.823 76 0.0419 2015/11/03 00:00:00 172.00 172.00 2407 7706 38 22.23 1158 27 33 38.10 50.322 159.875 Flare 159.875 7.720 75 1.930 46.320 272.205 5.790 138.960 1856.665 16027.16 7 160000 0.0420 00:00:00 172.00 172.00 00:00 hrs reading
Flowing Tubing pressure = 2407kPaShut in Casing pressure = 7706 kPaFlowing temperature = 38°CChoke size = 56/64 (22.23mm)Gas Rate = 53.26 10³m³Total fluid rate = 7.72 m³/hrWater recovery rate = 5.79 m³/hrCondensate rate = 1.93 m³/hrPH =7 , Salinity = 160000 ppm, BS&W = 75 %API = 46.8 @ 60°F, Separator H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 172 hrsDaily gas produced to flare last 24 hrs = 51.76 10³m³Cum gas Produced to flare= 159.875 10³m³Cond Produced last 24 hrs = 48.34 m³Cum Cond Produced = 272.21 m³Water Recovered Last 24 Hrs = 147.87 m³Total Water Recovered = 1856.66 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 16027.16 m³ Percentage Recovered from Initial Load = 10.38 %Chokes washed in 24 hours=0Total chokes washed =0
421 00:30:00 172.50 172.50 2444 7637 37 22.23 1172 26 33 38.10 49.680 160.917 Flare 160.917 75 0.0422 01:00:00 173.00 173.00 2344 7616 37 22.23 1172 26 33 38.10 49.444 161.949 Flare 161.949 7.870 76 1.889 45.331 274.094 5.981 143.549 1862.646 16021.17 7 160000 0.0423 01:30:00 173.50 173.50 2430 7605 39 22.23 1172 25 34 38.10 48.880 162.974 Flare 162.974 76 0.0424 02:00:00 174.00 174.00 2449 7580 38 22.23 1172 25 34 38.10 48.640 163.989 Flare 163.989 7.150 77 1.644 39.468 275.739 5.506 132.132 1868.151 16015.67 7 166000 47.1 0.0425 02:00:00 174.00 174.00 API of condensate taken. API = 47.1 @ 60°F , Specific Gravity = 0.7924, H2S pull 0ppm.426 02:30:00 174.50 174.50 2418 7594 37 22.23 1172 25 34 38.10 48.640 165.003 Flare 165.003 77 0.0427 03:00:00 175.00 175.00 2404 7503 37 22.23 1172 25 33 38.10 48.488 166.015 Flare 166.015 7.050 76 1.692 40.608 277.431 5.358 128.592 1873.509 16010.31 7 166000 0.0428 03:30:00 175.50 175.50 2363 7568 37 22.23 1172 24 33 38.10 48.245 167.022 Flare 167.022 76 0.0429 04:00:00 176.00 176.00 2334 7514 37 22.23 1186 25 34 38.10 48.919 168.034 Flare 168.034 7.740 75 1.935 46.440 279.366 5.805 139.320 1879.314 16004.51 7 166000 0.0430 04:30:00 176.50 176.50 2315 7515 37 22.23 1186 24 33 38.10 48.522 169.049 Flare 169.049 75 0.0431 05:00:00 177.00 177.00 2264 7502 37 22.23 1172 24 34 38.10 48.158 170.056 Flare 170.056 7.370 75 1.842 44.220 281.208 5.527 132.660 1884.842 15998.98 7 166000 0.0432 05:30:00 177.50 177.50 2310 7511 37 22.23 1165 24 34 38.10 47.534 171.053 Flare 171.053 75 0.0433 06:00:00 178.00 178.00 2299 7499 37 22.23 1172 24 34 38.10 47.915 172.047 Flare 172.047 7.510 76 1.802 43.258 283.011 5.708 136.982 1890.549 15993.27 7 166000 47.1 0.0434 06:00:00 178.00 178.00 API of condensate taken. API = 47.1 @ 60°F , Specific Gravity = 0.7924, H2S pull 0ppm.435 06:30:00 178.50 178.50 2299 7451 37 22.23 1172 24 33 38.10 48.002 173.047 Flare 173.047 76 0.0436 07:00:00 179.00 179.00 2328 7420 37 22.23 1172 24 33 38.10 48.002 174.047 Flare 174.047 7.370 75 1.842 44.220 284.853 5.527 132.660 1896.077 15987.74 7 166000 0.0437 07:30:00 179.50 179.50 2453 7402 37 22.23 1172 24 33 38.10 48.245 175.049 Flare 175.049 75 0.0438 08:00:00 180.00 180.00 2462 7397 37 22.23 1172 24 33 38.10 48.245 176.054 Flare 176.054 6.850 75 1.713 41.100 286.566 5.138 123.300 1901.214 15982.61 7 166000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row Tubing
Pres
Well
Owing
Pres
FlowChoke
TempSne
Gabe Dg
Pres Pres
OnficeDryRowMelar
MIR
Temp
CumGas Gas TotalGas
To Flared
RdVdBSWOIGanOilRale OlCum
Rnid
Water WaterWaterGumleadLTR
Gain Rate
PH SelrrrrV
dume
2
API Smd
Cd
WWlamldd
2015HV03
hhmmss
083000 18050 18050
kPag
2464
kPag
7390
'0 mm
37 r J 1207 25
mm 1tym'Id
49179 177069Flare 177069
ii)m''Idm'API
451
090000
093000
100000
103000
110000
113000
120000
123000
130000
133000
140000
143000
150000
153000
160000
163000
170000
18100
18150
18200
18250
18300
18350
18400
18450
18500
18550
18600
18650
18700
18750
18800
18850
18900
18100
18150
18200
18250
18300
18350
18400
18450
18500
18550
18600
18650
IBTOO
IBT50
18800
18850
18900
2464
2243
2314
2338
2139
2283
2343
2325
2439
2295
2298
2247
2356
2369
2234
2236
2238
7397
7390
7342
7329
7337
7298
7284
7261
7271
7241
7221
7241
7199
7202
7182
7185
7186
37 2223
37 r J
37 2223
37 r J
37 2223
37 r J
37 2223
38 r J
38 2223
38 r J
38 2223
38 r J
38 2223
37 r J
37 2223
37 r J
37 2223
1172 24
1179 25
1172 24
1172 24
1172 24
1138 23
1138 23
1138 23
1138 23
1138 23
1138 23
1138 23
1207 24
1172 23
1172 23
1172 23
1172 23
3810
3810
3810
3810
3810
3810
3810
3810
3810
48245
48715
47844
47844
47598
46666
46666
46666
46666
46421
46421
46174
48775
46850
46850
47100
46850
178084
179094
180100
181097
182091
IX073
184X5
185017
185989
186959
187926
188891
189880
190876
191852
192830
193809
Flee 178084
Flare 179094
Flare 180100
Ftze 18109T
Flare 182091
Flee 183073
Flare 184045
Flze 185017
Flare 185989
Flze 186959
Flare 187926
Flze 188891
Flare 189880
Flze 190876
Flare 191852
Ftze 192830
Flare 193809
7200
6300
6100
6400
6300
6860
6640
6330
6120
75 1 800
74 I 638
75 1 525
76 I 536
76 I 512
75 1 715
75 1 660
76 I 519
75 1 530
43200 288366
39312 290004
X600 291529
X864 293065
X288 294577
41160 296292
39840 297952
X461 299471
X720 301001
540012960019066141597721
4662 1 11888 1911 276 1597254
4575 109800 1915851 1596797
4864 116736 1920715 1596310
478811491219255031595832
514512348019306481595317
4980 119520 1935628 1594819
4811 115459 1940439 1594338
4590 110160 1945029 1593879
166XO
166XO
166XO
164XO
164XO
164XO
166XO
166XO
164XO
01
01
02
02
01
01
01
01
468 01
457 170000 18900 18900 I ofconde n APInsatetake ificG60'FSpec468@ ravily0 79XH26pullOppm
173000
180000
18950
19000
18950
19000
2352
2381
7188
7189
37 r J
37 2223
1172 23
1172 23 3810
47187
47187
194789
195772
Flze 194789
Flare 195772 6010 75 1 502 X060 302503 4508 108180 1949537 1593428 164XO 01
180000 19000 190001800Irmmsdirig
FlowingTubmgpressure=2381kPa
ShutmCasingpressure=7189kPa
Flowingtemperature=3TC
Chokesize=56I64f2223mmi
GasRate=4994IOVP
TotaHluidrate=601 m'Ihr
Waterrecoveryrate=451m'Ihr
Condensaterate= 1 50m'Ihr
PH=t,Salinity=164XOppmBSBW=75S
API=468@60'F,SeparatorH'S=gppmSand=gg'I
DailyhrsBowed=lghrs
Cumhrsflowed=190hrs
Dailygasproducedtoflarelast18hrs=35901tPm'um
gasProducedtoflare=19577210VP
CondProducedlast18hrs= 3030m'um
CondProduced=30250m'ater
Recoveredlast18Hrs=9287m'otal
WaterRecovered=194954
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1593428
m'ercentageRecoveredfromInmalLoad= 10918
Chokeswashedin18bourn=g
Totalchokeswashed=0
183000
190000
193000
19050
19100
19150
19050
19100
19150
2364 7114 37 iiii 1 172 23 31 XI: 47436 1 96757Flee 19675T
2133 7109 3t 2223 1 172 23 32 381 0 47100 1 97742Flare 197742 6510 75 I 628 39060 304131 4882 117180 1954419 1592940 7 I69XO 0I
2255 7092 36 iiii 1165 23 32 XI: 46715 198719Flee 198719
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAweD2XSBHDOWBFlowTestlSQRPS
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 21
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %439 2015/11/03 08:30:00 180.50 180.50 2464 7390 37 22.23 1207 25 33 38.10 49.179 177.069 Flare 177.069 75 0.0440 09:00:00 181.00 181.00 2464 7397 37 22.23 1172 24 33 38.10 48.245 178.084 Flare 178.084 7.200 75 1.800 43.200 288.366 5.400 129.600 1906.614 15977.21 7 166000 0.1441 09:30:00 181.50 181.50 2243 7390 37 22.23 1179 25 32 38.10 48.715 179.094 Flare 179.094 75 0.1442 10:00:00 182.00 182.00 2314 7342 37 22.23 1172 24 32 38.10 47.844 180.100 Flare 180.100 6.300 74 1.638 39.312 290.004 4.662 111.888 1911.276 15972.54 7 166000 0.1443 10:30:00 182.50 182.50 2338 7329 37 22.23 1172 24 32 38.10 47.844 181.097 Flare 181.097 74 0.1444 11:00:00 183.00 183.00 2139 7337 37 22.23 1172 24 32 38.10 47.598 182.091 Flare 182.091 6.100 75 1.525 36.600 291.529 4.575 109.800 1915.851 15967.97 7 166000 0.2445 11:30:00 183.50 183.50 2283 7298 37 22.23 1138 23 32 38.10 46.666 183.073 Flare 183.073 75 0.2446 12:00:00 184.00 184.00 2343 7284 37 22.23 1138 23 32 38.10 46.666 184.045 Flare 184.045 6.400 76 1.536 36.864 293.065 4.864 116.736 1920.715 15963.10 7 164000 0.2447 12:30:00 184.50 184.50 2325 7261 38 22.23 1138 23 32 38.10 46.666 185.017 Flare 185.017 76 0.2448 13:00:00 185.00 185.00 2439 7271 38 22.23 1138 23 32 38.10 46.666 185.989 Flare 185.989 6.300 76 1.512 36.288 294.577 4.788 114.912 1925.503 15958.32 7 164000 0.1449 13:30:00 185.50 185.50 2295 7241 38 22.23 1138 23 32 38.10 46.421 186.959 Flare 186.959 76 0.1450 14:00:00 186.00 186.00 2298 7221 38 22.23 1138 23 32 38.10 46.421 187.926 Flare 187.926 6.860 75 1.715 41.160 296.292 5.145 123.480 1930.648 15953.17 7 164000 0.1451 14:30:00 186.50 186.50 2247 7241 38 22.23 1138 23 32 38.10 46.174 188.891 Flare 188.891 75 0.1452 15:00:00 187.00 187.00 2356 7199 38 22.23 1207 24 32 38.10 48.775 189.880 Flare 189.880 6.640 75 1.660 39.840 297.952 4.980 119.520 1935.628 15948.19 7 166000 0.1453 15:30:00 187.50 187.50 2369 7202 37 22.23 1172 23 32 38.10 46.850 190.876 Flare 190.876 75 0.1454 16:00:00 188.00 188.00 2234 7182 37 22.23 1172 23 32 38.10 46.850 191.852 Flare 191.852 6.330 76 1.519 36.461 299.471 4.811 115.459 1940.439 15943.38 7 166000 0.1455 16:30:00 188.50 188.50 2236 7185 37 22.23 1172 23 32 38.10 47.100 192.830 Flare 192.830 76 0.1456 17:00:00 189.00 189.00 2238 7186 37 22.23 1172 23 32 38.10 46.850 193.809 Flare 193.809 6.120 75 1.530 36.720 301.001 4.590 110.160 1945.029 15938.79 7 164000 46.8 0.1457 17:00:00 189.00 189.00 API of condensate taken. API = 46.8 @ 60°F , Specific Gravity = 0.7936, H2S pull 0ppm.458 17:30:00 189.50 189.50 2352 7188 37 22.23 1172 23 31 38.10 47.187 194.789 Flare 194.789 75 0.1459 18:00:00 190.00 190.00 2381 7189 37 22.23 1172 23 31 38.10 47.187 195.772 Flare 195.772 6.010 75 1.502 36.060 302.503 4.508 108.180 1949.537 15934.28 7 164000 0.1460 18:00:00 190.00 190.00 18:00 hrs reading
Flowing Tubing pressure = 2381 kPaShut in Casing pressure = 7189 kPaFlowing temperature = 37°CChoke size = 56/64 (22.23mm)Gas Rate = 49.94 10³m³Total fluid rate = 6.01 m³/hrWater recovery rate = 4.51 m³/hrCondensate rate = 1.50 m³/hrPH =7 , Salinity = 164000 ppm, BS&W = 75 %API = 46.8 @ 60°F, Separator H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 18 hrs Cum hrs flowed = 190 hrsDaily gas produced to flare last 18 hrs = 35.90 10³m³Cum gas Produced to flare= 195.772 10³m³Cond Produced last 18 hrs = 30.30 m³Cum Cond Produced = 302.50 m³Water Recovered Last 18 Hrs = 92.87 m³Total Water Recovered = 1949.54 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15934.28 m³ Percentage Recovered from Initial Load = 10.91 %Chokes washed in 18 hours=0Total chokes washed =0
461 18:30:00 190.50 190.50 2364 7114 37 22.23 1172 23 31 38.10 47.436 196.757 Flare 196.757 75 0.1462 19:00:00 191.00 191.00 2133 7109 37 22.23 1172 23 32 38.10 47.100 197.742 Flare 197.742 6.510 75 1.628 39.060 304.131 4.882 117.180 1954.419 15929.40 7 169000 0.1463 19:30:00 191.50 191.50 2255 7092 36 22.23 1165 23 32 38.10 46.715 198.719 Flare 198.719 75 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row Tubing
Pres
Well
CmingFlow
Pres Temp
QmksSkdw
$ns Pma
OnficeDryRowMalar
Dg MIR
Pres Temp
CumGas Gas TotalGas
To Flared
RdVdBSWOIGanOilRale OlCum
Rnid
Water WaterWaterGumleadLTR
Gain Rate
PH SalinilyAPI
dume
2
WWlamlddhhmmss kPag kPag '0 mm kPag kPa '0 mm 1tym'Id ii)m''Idm'pm'API
2015HV03200000
203000
210000
213000
220000
19200
19250
19300
19350
19400
19200
19250
19300
19350
19400
2234
2216
2341
2219
2111
7076 36
7069 36
7043 36
7051 36
7041 36
2223 1172
riii 1158
2223 1172
riii 1172
2223 1172
23 32
23 31
23 31
23 31
23 31
3810
Jc I
'810
Jc I
'810
46850
46665
46935
47187
46935
IX694
200668
201643
202624
203604
Flare 199694
Flee 2X668
Flare 201643
Ftze 202624
Flare 203604
6840
6140
6400
75 1 710
75 1 535
76 I 536
41040 305841
X840 307376
X864 308912
5 130 123120 1959549 1592427
4605 110520 1964154 1591967
4864 116736 1969018 1591480
169XO
169XO
168XO465
01
01
01
4TO
4TI
220000
223000
230000
19400
19450
19500
19400
19450
19500
I ofconde
2336
2123
nsatetakenAPI
7025 36
7072 36
riii 1172
2223 1172
23 32
23 32
ificG60'FSpec465@ ravily0 7949
Jc I
'810
46850
46850
204581
205557
H2$pullOppm
Flze 204581
Flare 205557 6560 75 1 640 39360 310552 4920 I18080 1973938 1590988 168XO 01
2015MV04
233000
000000
19550
19600
19550
19600
2210
2199
7069 36
7029 36
riii 1172
2223 1172
23 32
23 32
Jc I
'810
47100
46597
206536
207512
Flze 206536
Flare 207512 6660 76 I 598 38362 312150 5062 121478 1979000 1590482 168XO 01
4T4 000000 19600 196000000Irmmsdii10
FlowingTubmgpressure=2199kPa
ShutmCasingpressure=7029kPa
Flowingtemperature=36'0
Chokesize=56I64f2223mmi
GasRate=4932IOVP
TotaHluidrate=666 m'Ihr
Waterrecoveryrate=506m'Ihr
Condensaterate= 1 60m'Ihr
PH=7,Salinity=168XOppmBSSW=TSS
API=465@60'6,SeparatorH'S=gppmSand=gg'I
Dailyhrsgowed=24hrs
Cumhrsflowed=196hrs
Dailygasproducedtoflarelast24hrs=47641tPm'um
gasProducedtoflare=20751210VP
CondProducedlast24hrs= 3994m'um
CondProduced=31215
m'aterRecoveredlast24
Hrs=12234m'otal
WaterRecovered=197900
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1590482
m'ercentageRecoveredfromInmalLoad= 1106H
Chokeswashedin24bourn=g
Totalchokeswashed=0
4T5
476
478
003000
010000
013000
020000
19650
19700
19750
19800
19650
19T00
19T50
19800
2308
2142
2296
2245
6971 37
6969 37
6972 37
6962 36
riii 1172
2223 1172
riii 1172
2223 1165
22 32 XI: 46344
23 33 3810 46513
22 32 XI: 46344
23 32 3810 46715
208480
209447
210414
211364
Ftze
Flare
Ftze
Flare
208480
20944T
210414
211384
6680
6620
76 I 603
75 1 655
38477 313753
39720 315408
5077 121843 1984077
4965 119160 1989042
1589974
1589478
7 168XO
7 168XO
01
465 01
020000 19800 19800APIofcoedsnsatetakenAPI465@60'FSpecificGravity=0 7949H2$pullOppm
023000
030000
033000
040000
043000
050000
053000
060000
19850
19900
19950
20000
20050
20100
20150
20200
19850
19900
19950
20000
20050
20100
20150
20200
2055
3197
2011
2132
2283
2248
2164
2184
6945 37
6935 36
6915 36
6926 37
6907 37
6892 36
6X5 37
6888 37
riii 1158
2223 1151
riii 1172
2223 1158
riii 1172
2223 1172
iiii 1165
2223 1158
22 32 XI: 45824
22 32 3810 45691
22 32 XI: 45832
22 32 3810 45824
22 32 XI: 45832
22 32 3810 46344
22 32 XI: 45957
22 31 3810 45652
212348
213301
214254
215209
216164
217124
218085
219040
Ftze
Flare
Ftze
Flare
Ftze
Flare
Ftze
Flare
212348
213301
214254
215209
216164
217124
218085
219040
6420
6000
5880
5820
75 1 605
75 1 500
77 1 352
76 I 397
38520 317013
X000 318513
32458 319866
33523 321263
4815 115560 1993857
4500 108000 1998357
4528 108662 2002884
4423 106157 2007307
1588996
1588546
1588094
1587651
7 170XO
7 170XO
7 172XO
7 172XO
01
01
01
465 01
060000 20200 20200APlotcondensatetakenApl=465@60'6SpeoficGravily=07949H2$pullgppm
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIMG,.IAweD24884DOWSFlowTestlSQRP2
ProdnctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 22
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %464 2015/11/03 20:00:00 192.00 192.00 2234 7076 36 22.23 1172 23 32 38.10 46.850 199.694 Flare 199.694 6.840 75 1.710 41.040 305.841 5.130 123.120 1959.549 15924.27 7 169000 0.1465 20:30:00 192.50 192.50 2216 7069 36 22.23 1158 23 31 38.10 46.665 200.668 Flare 200.668 75 0.1466 21:00:00 193.00 193.00 2341 7043 36 22.23 1172 23 31 38.10 46.935 201.643 Flare 201.643 6.140 75 1.535 36.840 307.376 4.605 110.520 1964.154 15919.67 7 169000 0.1467 21:30:00 193.50 193.50 2219 7051 36 22.23 1172 23 31 38.10 47.187 202.624 Flare 202.624 75 0.1468 22:00:00 194.00 194.00 2111 7041 36 22.23 1172 23 31 38.10 46.935 203.604 Flare 203.604 6.400 76 1.536 36.864 308.912 4.864 116.736 1969.018 15914.80 7 168000 46.5 0.1469 22:00:00 194.00 194.00 API of condensate taken. API = 46.5 @ 60°F , Specific Gravity = 0.7949, H2S pull 0ppm.470 22:30:00 194.50 194.50 2336 7025 36 22.23 1172 23 32 38.10 46.850 204.581 Flare 204.581 76 0.1471 23:00:00 195.00 195.00 2123 7072 36 22.23 1172 23 32 38.10 46.850 205.557 Flare 205.557 6.560 75 1.640 39.360 310.552 4.920 118.080 1973.938 15909.88 7 168000 0.1472 23:30:00 195.50 195.50 2210 7069 36 22.23 1172 23 32 38.10 47.100 206.536 Flare 206.536 75 0.1473 2015/11/04 00:00:00 196.00 196.00 2199 7029 36 22.23 1172 23 32 38.10 46.597 207.512 Flare 207.512 6.660 76 1.598 38.362 312.150 5.062 121.478 1979.000 15904.82 7 168000 0.1474 00:00:00 196.00 196.00 00:00 hrs reading
Flowing Tubing pressure = 2199 kPaShut in Casing pressure = 7029 kPaFlowing temperature = 36°CChoke size = 56/64 (22.23mm)Gas Rate = 49.32 10³m³Total fluid rate = 6.66 m³/hrWater recovery rate = 5.06 m³/hrCondensate rate = 1.60 m³/hrPH =7 , Salinity = 168000 ppm, BS&W = 76 %API = 46.5 @ 60°F, Separator H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 196 hrsDaily gas produced to flare last 24 hrs = 47.64 10³m³Cum gas Produced to flare= 207.512 10³m³Cond Produced last 24 hrs = 39.94 m³Cum Cond Produced = 312.15 m³Water Recovered Last 24 Hrs = 122.34 m³Total Water Recovered = 1979.00 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15904.82 m³ Percentage Recovered from Initial Load = 11.06 %Chokes washed in 24 hours=0Total chokes washed =0
475 00:30:00 196.50 196.50 2308 6971 37 22.23 1172 22 32 38.10 46.344 208.480 Flare 208.480 76 0.1476 01:00:00 197.00 197.00 2142 6969 37 22.23 1172 23 33 38.10 46.513 209.447 Flare 209.447 6.680 76 1.603 38.477 313.753 5.077 121.843 1984.077 15899.74 7 168000 0.1477 01:30:00 197.50 197.50 2296 6972 37 22.23 1172 22 32 38.10 46.344 210.414 Flare 210.414 76 0.1478 02:00:00 198.00 198.00 2245 6962 36 22.23 1165 23 32 38.10 46.715 211.384 Flare 211.384 6.620 75 1.655 39.720 315.408 4.965 119.160 1989.042 15894.78 7 168000 46.5 0.1479 02:00:00 198.00 198.00 API of condensate taken. API = 46.5 @ 60°F , Specific Gravity = 0.7949, H2S pull 0ppm.480 02:30:00 198.50 198.50 2055 6945 37 22.23 1158 22 32 38.10 45.824 212.348 Flare 212.348 75 0.1481 03:00:00 199.00 199.00 3197 6935 36 22.23 1151 22 32 38.10 45.691 213.301 Flare 213.301 6.420 75 1.605 38.520 317.013 4.815 115.560 1993.857 15889.96 7 170000 0.1482 03:30:00 199.50 199.50 2011 6915 36 22.23 1172 22 32 38.10 45.832 214.254 Flare 214.254 75 0.1483 04:00:00 200.00 200.00 2132 6926 37 22.23 1158 22 32 38.10 45.824 215.209 Flare 215.209 6.000 75 1.500 36.000 318.513 4.500 108.000 1998.357 15885.46 7 170000 0.1484 04:30:00 200.50 200.50 2283 6907 37 22.23 1172 22 32 38.10 45.832 216.164 Flare 216.164 75 0.1485 05:00:00 201.00 201.00 2248 6892 36 22.23 1172 22 32 38.10 46.344 217.124 Flare 217.124 5.880 77 1.352 32.458 319.866 4.528 108.662 2002.884 15880.94 7 172000 0.1486 05:30:00 201.50 201.50 2164 6905 37 22.23 1165 22 32 38.10 45.957 218.085 Flare 218.085 77 0.1487 06:00:00 202.00 202.00 2184 6888 37 22.23 1158 22 31 38.10 45.652 219.040 Flare 219.040 5.820 76 1.397 33.523 321.263 4.423 106.157 2007.307 15876.51 7 172000 46.5 0.1488 06:00:00 202.00 202.00 API of condensate taken. API = 46.5 @ 60°F , Specific Gravity = 0.7949, H2S pull 0ppm.
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Dale Time Cum Row TubingCmingFlowChoke
Pres Pres TempSns
Dg MIR
Pres Temp
CumGas Gas TolalGasRdVd
To Flared
BSWOIGanOilRale 09Cum Wstw Wshr
Gain Rate
WaterGumloadLTRPH SalinilyAPI
WWtumtddhhmmss
2015MV04063000 20250 20250
kPag kPag '0 mm
2252 6865 36 iiii 1151
kPa '0
22 32
mm 1tym'id
45437 219988
ttpap(I)m'ta
e 219988
m''Idm'pm'API
491
070000
073000
000000
003000
090000
093000
100000
20300
20350
20400
20450
20500
20550
20600
20300
20350
20400
20450
20500
20550
20600
2185 6851 37 2223
2268 6839 36 iiii
2246 6840 37 2223
2236 6833 37 iiii
2221 6826 36 2223
2234 6820 36 iiii
2289 6819 36 2223
1138
1138
1138
1158
1138
1138
1103
22 31
22 31
22 31
22 31
22 31
21 31
21 31
3010 44999
44999
3010 44999
45395
3010 44999
44743
3010 43826
220930
221068
222005
223747
224689
225623
226546
Flare 220930 4810
Ftae 221068
Flare 222005 5770
Ftae 22374T
Flare 224689 5 120
Ftae 225623
Flare 226546 4710
76 1 154 27706
76 I 385 33235
76 I 229 29491
74 I 225 29390
322417
323802
325031
326255
3656 87734
4305 105245
3891 93389
3405 83650
2010963
2015348
2019239
2022725
15072867 172XO
15068477 172XO
15064507 172XO
I506110 7 I72XO496
01
01
01
01
497 100000 20600 20600 I ofcondensatetakenAPI ificG60'FSpec496@ ravily0 7812H20pullOppm
103000
110000
113000
120000
123000
130000
133000
140000
20650
20700
20750
20000
20050
20900
20950
21000
20650
20T00
20T50
20800
20850
20900
20950
21000
2388 6797 37 iiii
2285 6814 38 2223
2205 6820 39 iiii
2260 6823 39 2223
2270 6810 39 iiii
2266 6806 39 2223
2267 6791 39 iiii2272 6784 39 2223
1103
1138
1158
1124
1124
1138
1103
1103
22 31
22 31
22 31
21 31
21 31
21 31
21 32
21 32
44332
3014 45097
45494
3010 44479
44479
3010 44743
44000
3010 43746
227464
228396
229340
230277
231203
232133
233057
233971
Flae 227464
Flare 220396 4930
Ftae 229340
Flare 2X277 5 130
Ftae 231203
Flare 232133 5 160
Flae 23305T
Flare 233971 4 150
76 1 183 28397
74 I 334 32011
76 1 230 29722
74 I 079 25896
327430
320772
330011
331090
3747 89923
3796 91109
3922 94110
3071 73704
2026472
2030268
2034189
2037260
15057357 172XO
15053557 172XO
15049637 ITOXO
1504656 7 ITOXO496
01
01
01
01
140000 21000 21000 I ofcondensatetakenAPI ificG60'FSpec496@ ravily0 7812H20pullOppm
510
511
512
513
514
143000
150000
153000
160000
163000
170000
173000
100000
21050
21100
21150
21200
21250
21300
21350
21400
21050
21100
21150
21200
21250
21300
21350
21400
2248 6777 39 iiii
2209 6760 39 2223
2327 6760 39 iiii
2178 6734 38 2223
2129 6706 39 iiii
2187 6695 39 2223
2254 6687 39 iiii
2272 6679 39 2223
1103
1103
1124
1138
1138
1117
1117
1138
21 32
21 32
21 32
21 32
21 33
21 33
21 33
21 33
43746
3010 43746
44142
3010 44404
44324
3010 43931
44185
3010 44580
234083
235794
236709
237632
238556
239475
240393
241318
Flae 234083
Flare 235794 4860
Flee 236709
Flare 237632 4740
Flee 230556
Flare 239475 4750
Flae 240393
Flare 241318 4830
75 I 215 29160
73 1280 X715
I 282 X700
75 I 208 28900
332305
333584
334867
336074
3645 87480
3460 83045
3468 83220
3622 86940
2040905
2044366
2047033
2051456
15042917 ITOXO
15039457 168XO
15035997 168XO
1503236 7 168XO499
01
01
01
01
515 100000 21400 21400 I ofcondensatetakenAPI ificG60'FSpec499@ ravily H20pullOppm
516
517
518
519
521
103000
190000
193000
200000
203000
210000
213000
220000
21450
21500
21550
21600
21650
21700
21750
21000
21450
21500
21550
21600
21650
21700
21750
21800
2198 6651 39 iiii
2137 6649 39 2223
1976 6640 39 iiii
1998 6617 38 2223
1984 6630 38 iiii1996 6629 38 2223
2105 6617 38 iiii
2222 6599 38 2223
1138
1138
1131
1131
1124
1172
1103
1138
22 33
21 33
21 33
21 33
21 33
21 33
21 33
20 33
44836
3010 44580
43935
3010 43676
43805
3010 45232
43157
3010 43280
242249
243181
244103
245015
245927
246054
247775
248675
Ftae 242249
Flare 241181 4880
Flee 244103
Flare 245015 4990
Flee 24592T
Flare 246054 4510
Ftae 247775
Flare 240675 4780
75 1 220 29200
74 1 297 31138
75 1 128 27060
75 1 195 28600
337294
330592
339719
340914
3660 87840
3693 80622
3302 81180
3505 86040
2055116
2058008
2062191
2065776
15028707 166XO
15025017 166XO
15021637 166XO
1501804 7 168XO499
01
01
01
01
524 220000 21000 21800 I ofcondensatetakenAPI ificG60'FSpec499@ ravily H20pullOppm
223000
230000
233000
2015MV05000000
21050
21900
21950
22000
21850
21900
21950
22000
2162 6591 37 iiii
2124 6579 37 2223
2129 6573 37 iiii2119 6569 37 2223
1124
1131
1117
1145
21 33
21 33
21 33
20 33
43805
3010 43676
43675
3010 43671
249582
250494
251404
252313
Ftae 249582
Flare 250494 4650
Flae 251404
Flare 252313 4690
75 1163 27900
76 1 126 27014
342077
343202
3407 83700
3564 85546
2069263
2072028
15014567 ITOXO
15010997 ITOXO
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAweD24804DOWBFlowTestlSQRP3
ProductiontestItgABchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 23
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %489 2015/11/04 06:30:00 202.50 202.50 2252 6865 36 22.23 1151 22 32 38.10 45.437 219.988 Flare 219.988 76 0.1490 07:00:00 203.00 203.00 2185 6851 37 22.23 1138 22 31 38.10 44.999 220.930 Flare 220.930 4.810 76 1.154 27.706 322.417 3.656 87.734 2010.963 15872.86 7 172000 0.1491 07:30:00 203.50 203.50 2268 6839 36 22.23 1138 22 31 38.10 44.999 221.868 Flare 221.868 76 0.1492 08:00:00 204.00 204.00 2246 6840 37 22.23 1138 22 31 38.10 44.999 222.805 Flare 222.805 5.770 76 1.385 33.235 323.802 4.385 105.245 2015.348 15868.47 7 172000 0.1493 08:30:00 204.50 204.50 2236 6833 37 22.23 1158 22 31 38.10 45.395 223.747 Flare 223.747 76 0.1494 09:00:00 205.00 205.00 2221 6826 36 22.23 1138 22 31 38.10 44.999 224.689 Flare 224.689 5.120 76 1.229 29.491 325.031 3.891 93.389 2019.239 15864.58 7 172000 0.1495 09:30:00 205.50 205.50 2234 6828 36 22.23 1138 21 31 38.10 44.743 225.623 Flare 225.623 76 0.1496 10:00:00 206.00 206.00 2289 6819 36 22.23 1103 21 31 38.10 43.826 226.546 Flare 226.546 4.710 74 1.225 29.390 326.255 3.485 83.650 2022.725 15861.10 7 172000 49.6 0.1497 10:00:00 206.00 206.00 API of condensate taken. API = 49.6 @ 60°F , Specific Gravity = 0.7812, H2S pull 0ppm.498 10:30:00 206.50 206.50 2388 6797 37 22.23 1103 22 31 38.10 44.332 227.464 Flare 227.464 74 0.1499 11:00:00 207.00 207.00 2285 6814 38 22.23 1138 22 31 38.14 45.097 228.396 Flare 228.396 4.930 76 1.183 28.397 327.438 3.747 89.923 2026.472 15857.35 7 172000 0.1500 11:30:00 207.50 207.50 2205 6828 39 22.23 1158 22 31 38.14 45.494 229.340 Flare 229.340 76 0.1501 12:00:00 208.00 208.00 2260 6823 39 22.23 1124 21 31 38.10 44.479 230.277 Flare 230.277 5.130 74 1.334 32.011 328.772 3.796 91.109 2030.268 15853.55 7 172000 0.1502 12:30:00 208.50 208.50 2270 6810 39 22.23 1124 21 31 38.10 44.479 231.203 Flare 231.203 74 0.1503 13:00:00 209.00 209.00 2266 6806 39 22.23 1138 21 31 38.10 44.743 232.133 Flare 232.133 5.160 76 1.238 29.722 330.011 3.922 94.118 2034.189 15849.63 7 170000 0.1504 13:30:00 209.50 209.50 2267 6791 39 22.23 1103 21 32 38.10 44.000 233.057 Flare 233.057 76 0.1505 14:00:00 210.00 210.00 2272 6784 39 22.23 1103 21 32 38.10 43.746 233.971 Flare 233.971 4.150 74 1.079 25.896 331.090 3.071 73.704 2037.260 15846.56 7 170000 49.6 0.1506 14:00:00 210.00 210.00 API of condensate taken. API = 49.6 @ 60°F , Specific Gravity = 0.7812, H2S pull 0ppm.507 14:30:00 210.50 210.50 2248 6777 39 22.23 1103 21 32 38.10 43.746 234.883 Flare 234.883 74 0.1508 15:00:00 211.00 211.00 2209 6768 39 22.23 1103 21 32 38.10 43.746 235.794 Flare 235.794 4.860 75 1.215 29.160 332.305 3.645 87.480 2040.905 15842.91 7 170000 0.1509 15:30:00 211.50 211.50 2327 6760 39 22.23 1124 21 32 38.10 44.142 236.709 Flare 236.709 75 0.1510 16:00:00 212.00 212.00 2178 6734 38 22.23 1138 21 32 38.10 44.404 237.632 Flare 237.632 4.740 73 1.280 30.715 333.584 3.460 83.045 2044.366 15839.45 7 168000 0.1511 16:30:00 212.50 212.50 2129 6706 39 22.23 1138 21 33 38.10 44.324 238.556 Flare 238.556 73 0.1512 17:00:00 213.00 213.00 2187 6695 39 22.23 1117 21 33 38.10 43.931 239.475 Flare 239.475 4.750 73 1.282 30.780 334.867 3.468 83.220 2047.833 15835.99 7 168000 0.1513 17:30:00 213.50 213.50 2254 6687 39 22.23 1117 21 33 38.10 44.185 240.393 Flare 240.393 73 0.1514 18:00:00 214.00 214.00 2272 6679 39 22.23 1138 21 33 38.10 44.580 241.318 Flare 241.318 4.830 75 1.208 28.980 336.074 3.622 86.940 2051.456 15832.36 7 168000 49.9 0.1515 18:00:00 214.00 214.00 API of condensate taken. API = 49.9 @ 60°F , Specific Gravity = 0.7799, H2S pull 0ppm.516 18:30:00 214.50 214.50 2198 6651 39 22.23 1138 22 33 38.10 44.836 242.249 Flare 242.249 75 0.1517 19:00:00 215.00 215.00 2137 6649 39 22.23 1138 21 33 38.10 44.580 243.181 Flare 243.181 4.880 75 1.220 29.280 337.294 3.660 87.840 2055.116 15828.70 7 166000 0.1518 19:30:00 215.50 215.50 1976 6640 39 22.23 1131 21 33 38.10 43.935 244.103 Flare 244.103 75 0.1519 20:00:00 216.00 216.00 1998 6617 38 22.23 1131 21 33 38.10 43.676 245.015 Flare 245.015 4.990 74 1.297 31.138 338.592 3.693 88.622 2058.808 15825.01 7 166000 0.1520 20:30:00 216.50 216.50 1984 6630 38 22.23 1124 21 33 38.10 43.805 245.927 Flare 245.927 74 0.1521 21:00:00 217.00 217.00 1996 6629 38 22.23 1172 21 33 38.10 45.232 246.854 Flare 246.854 4.510 75 1.128 27.060 339.719 3.382 81.180 2062.191 15821.63 7 166000 0.1522 21:30:00 217.50 217.50 2105 6617 38 22.23 1103 21 33 38.10 43.157 247.775 Flare 247.775 75 0.1523 22:00:00 218.00 218.00 2222 6599 38 22.23 1138 20 33 38.10 43.280 248.675 Flare 248.675 4.780 75 1.195 28.680 340.914 3.585 86.040 2065.776 15818.04 7 168000 49.9 0.1524 22:00:00 218.00 218.00 API of condensate taken. API = 49.9 @ 60°F , Specific Gravity = 0.7799, H2S pull 0ppm.525 22:30:00 218.50 218.50 2162 6591 37 22.23 1124 21 33 38.10 43.805 249.582 Flare 249.582 75 0.1526 23:00:00 219.00 219.00 2124 6579 37 22.23 1131 21 33 38.10 43.676 250.494 Flare 250.494 4.650 75 1.163 27.900 342.077 3.487 83.700 2069.263 15814.56 7 170000 0.1527 23:30:00 219.50 219.50 2129 6573 37 22.23 1117 21 33 38.10 43.675 251.404 Flare 251.404 75 0.1528 2015/11/05 00:00:00 220.00 220.00 2119 6569 37 22.23 1145 20 33 38.10 43.671 252.313 Flare 252.313 4.690 76 1.126 27.014 343.202 3.564 85.546 2072.828 15810.99 7 170000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Time Cum Row Tubing
Pres
CasingFlowChokeBshe Dg MIR
Pres TempSns Pres Pres Temp
GasRats CumGas Gas
To
TotalGas RdVd
Flared
BSWOIGanOilRale OiGum Wstw WsHr
Gain Rate
WaterGumleadLTRPH SalinilyAPI
WWlamlddhhmmss kPag kPag '0 mm kPag kPa '0 mm 1tym'Id IRm'tyap(I)m'''Idm'pm'API
2015HV05000000 22000 220000000hrsreadmg
FlowingTubmgpressure=2119kPa
ShutmCasingpressure=6569kPa
Flowingtemperature=3TC
Chokesize=56I64f2223mmi
GasRate=4623IOVP
TotaHluidrate=469 m'Ihr
Waterrecoveryrate=356m'Ihr
Condensaterate=I13m'Ihr
PH=7,Salinity=ITOXOppmBSSW=TSS
API=499@60'6,Separator=1145kPag8'6=0 ppmSand=00'I
Dailyhrsgowed=24hrs
Cumhrsflowed=220hrs
Dailygasproducedtoflarelast24hrs=4480ItPm'um
gasProducedtoflare=25231310VP
CondProducedlast24hrs= 3105m'um
CondProduced=34320m'ater
Recoveredlast24Hrs=9383m'otal
WaterRecovered=207283
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1581099
m'ercentageRecoveredfromInmalLoad= 11598
Chokeswashedin24bourn=g
Totalchokeswashed=0
531
003000
010000
013000
22050
22100
22150
22050 2091
22100 2003
22150 2189
6572
6558
6548
37 r J
37 2223
37 r J
1138
1172
1172
32 JcI'2
3810
32 Jc
I'4145
44791
44526
253228Flee 253228
254155Flare 254155
255085Flee 255085
4530 76 I 087 26093 344290 3443 826272076270 1580755 7 170XO 01
020000
020000
22200
22200
6536 37 222322200 2049
22200APIofcoedsnsatetaken API488@
1145
60'FSpecificG
32 3810
ravily=0 7799
44275
H26pullOppm
256010Flare 256010 4790 75 1197 28740 345487 3592 86220 207986315803967 170XO488 01
537
023000
030000
033000
040000
043000
050000
22250
22300
22350
22400
22450
22500
22250 1974
22300 2013
22350 2162
22400 2088
22450 1906
22500 1993
6529
6501
6504
6500
6490
6480
37 r J
37 2223
37 r J
37 2223
37 r J
37 2223
1158
1151
1145
1158
1117
32 JcI'2
3810
32 JcI'2
3810
32 JcI'2
3810
44142
44014
44006
43754
43366
256935Flee 256935
257859Flare 257859
258777Flee 25877T
259694Flare 259694
260608Flee 260608
261516Flare 261516
4340
4860
4660
76 I 042 24998 346529
75 I 215 29160 347744
76 1118 26842 348862
3298
3645
3542
79162
87480
84998
208316115800667
2086806 1579701 7
209034815793477
170XO
170XO
170XO
01
01
01
053000
060000
060000
22550
22600
22600
4396522550 1999
22600 1975
22600APIofcoeds
6478
6472
nsatetake
37 r J
37 2223
478@n API
1124
1131
60'FSpecificG
31 JcI'2
3810
ravily=0 7892
44273
H26pullOppm
262425Fice 262425
263344Flare 263344 4750 75 I 1 87 28500 350050 3563 85500 2093910 1578991 7 170XO 01
551
063000
070000
073000
080000
083000
090000
093000
100000
22650
22700
22750
22800
22850
22900
22950
23000
22650 2147
22700 2148
22750 2202
22800 2124
22850 2107
22900 2087
22950 2016
23000 1955
6441
6433
6432
6403
6409
6416
6409
6403
37 r J
37 2223
38 r J
38 2223
37 r J
37 2223
38 r J
38 2223
1117
1117
1138
1103
1117
1103
1103
31 JcI'1
3810
31 JcI'1
3810
31 JcI'1
3810
31 JcI'0
3810
43575
43834
44485
43185
42795
43053
42533
42611
264260Flee 264260
265170Flare 265170
266090Flee 266090
267003Flare 267003
267899Flee 267899
268793Flare 268793
269685Flee 269685
270572Flare 270572
4750
4660
4350
4710
76 I 140 27360 351190
75 1 165 27960 352355
76 I 044 25056 353399
75 1178 28260 354576
3610
3495
3306
3532
86640
83880
79344
84780
209752015786307
210101515782807
210432115779507
210785415775977
170XO
170XO
170XO
170XO
01
01
01
488 01
100000
103000
23000
23050
23000API=488@60'FSpecdicGravity=07849H26pullOppm
23050 2093 6399 37 iiii 1103 20 30 XI:42611 271459Flee 271459
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIMG,.IAweD2XSSHDOWSFlowTestlSQRP4
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 24
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %529 2015/11/05 00:00:00 220.00 220.00 00:00 hrs reading
Flowing Tubing pressure = 2119 kPaShut in Casing pressure = 6569 kPaFlowing temperature = 37°CChoke size = 56/64 (22.23mm)Gas Rate = 46.23 10³m³Total fluid rate = 4.69 m³/hrWater recovery rate = 3.56 m³/hrCondensate rate = 1.13 m³/hrPH =7 , Salinity = 170000 ppm, BS&W = 76 %API = 49.9 @ 60°F, Separator = 1145 kPag H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 220 hrsDaily gas produced to flare last 24 hrs = 44.80 10³m³Cum gas Produced to flare= 252.313 10³m³Cond Produced last 24 hrs = 31.05 m³Cum Cond Produced = 343.20 m³Water Recovered Last 24 Hrs = 93.83 m³Total Water Recovered = 2072.83 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15810.99 m³ Percentage Recovered from Initial Load = 11.59 %Chokes washed in 24 hours=0Total chokes washed =0
530 00:30:00 220.50 220.50 2091 6572 37 22.23 1138 21 32 38.10 44.145 253.228 Flare 253.228 76 0.1531 01:00:00 221.00 221.00 2003 6558 37 22.23 1172 21 32 38.10 44.791 254.155 Flare 254.155 4.530 76 1.087 26.093 344.290 3.443 82.627 2076.270 15807.55 7 170000 0.1532 01:30:00 221.50 221.50 2189 6548 37 22.23 1172 21 32 38.10 44.526 255.085 Flare 255.085 76 0.1533 02:00:00 222.00 222.00 2049 6536 37 22.23 1145 21 32 38.10 44.275 256.010 Flare 256.010 4.790 75 1.197 28.740 345.487 3.592 86.220 2079.863 15803.96 7 170000 48.8 0.1534 02:00:00 222.00 222.00 API of condensate taken. API = 48.8 @ 60°F , Specific Gravity = 0.7799, H2S pull 0ppm.535 02:30:00 222.50 222.50 1974 6529 37 22.23 1158 21 32 38.10 44.534 256.935 Flare 256.935 75 0.1536 03:00:00 223.00 223.00 2013 6501 37 22.23 1151 21 32 38.10 44.142 257.859 Flare 257.859 4.340 76 1.042 24.998 346.529 3.298 79.162 2083.161 15800.66 7 170000 0.1537 03:30:00 223.50 223.50 2162 6504 37 22.23 1145 21 32 38.10 44.014 258.777 Flare 258.777 76 0.1538 04:00:00 224.00 224.00 2088 6500 37 22.23 1158 20 32 38.10 44.006 259.694 Flare 259.694 4.860 75 1.215 29.160 347.744 3.645 87.480 2086.806 15797.01 7 170000 0.1539 04:30:00 224.50 224.50 1906 6490 37 22.23 1117 21 32 38.10 43.754 260.608 Flare 260.608 75 0.1540 05:00:00 225.00 225.00 1993 6480 37 22.23 1110 21 32 38.10 43.366 261.516 Flare 261.516 4.660 76 1.118 26.842 348.862 3.542 84.998 2090.348 15793.47 7 170000 0.1541 05:30:00 225.50 225.50 1999 6478 37 22.23 1124 21 31 38.10 43.965 262.425 Flare 262.425 76 0.1542 06:00:00 226.00 226.00 1975 6472 37 22.23 1131 21 32 38.10 44.273 263.344 Flare 263.344 4.750 75 1.187 28.500 350.050 3.563 85.500 2093.910 15789.91 7 170000 0.1543 06:00:00 226.00 226.00 API of condensate taken. API = 47.8 @ 60°F , Specific Gravity = 0.7892, H2S pull 0ppm.544 06:30:00 226.50 226.50 2147 6441 37 22.23 1117 21 31 38.10 43.575 264.260 Flare 264.260 75 0.1545 07:00:00 227.00 227.00 2148 6433 37 22.23 1117 21 31 38.10 43.834 265.170 Flare 265.170 4.750 76 1.140 27.360 351.190 3.610 86.640 2097.520 15786.30 7 170000 0.1546 07:30:00 227.50 227.50 2202 6432 38 22.23 1138 21 31 38.10 44.485 266.090 Flare 266.090 76 0.1547 08:00:00 228.00 228.00 2124 6403 38 22.23 1110 20 31 38.10 43.185 267.003 Flare 267.003 4.660 75 1.165 27.960 352.355 3.495 83.880 2101.015 15782.80 7 170000 0.1548 08:30:00 228.50 228.50 2107 6409 37 22.23 1103 20 31 38.10 42.795 267.899 Flare 267.899 75 0.1549 09:00:00 229.00 229.00 2087 6416 37 22.23 1117 20 31 38.10 43.053 268.793 Flare 268.793 4.350 76 1.044 25.056 353.399 3.306 79.344 2104.321 15779.50 7 170000 0.1550 09:30:00 229.50 229.50 2016 6409 38 22.23 1103 20 31 38.10 42.533 269.685 Flare 269.685 76 0.1551 10:00:00 230.00 230.00 1955 6403 38 22.23 1103 20 30 38.10 42.611 270.572 Flare 270.572 4.710 75 1.178 28.260 354.576 3.532 84.780 2107.854 15775.97 7 170000 48.8 0.1552 10:00:00 230.00 230.00 API = 48.8 @ 60°F , Specific Gravity = 0.7849, H2S pull 0ppm.553 10:30:00 230.50 230.50 2093 6399 37 22.23 1103 20 30 38.10 42.611 271.459 Flare 271.459 75 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Roid dume
2
Dale Time Cum Row Tubing0 ming
Pres Pres
Flow
Temp
ChokeBshe Dg
Sae Pres Pres
MIR Piste
TempGze
GasRateCumGas Gas
To
TotalGas
Flared
RdVdBSW08Fmn OilRale 01Cum Water
Gain
WaterWaterCumloadLTRPH SalinilyAPI Smd
IMM Dd
WWlnmlddhhmmasHrs Hrs kPag kPag mm kPag kPa '0 mm ltym'ld IMm'I)m''Idm'pm'API
554 2015IIV0511000023100 23100 2156 6392
11300023150 23150 2051 6386
120000 23200 23200 2043 6388
2223 1117 20
iiii 1117 20
2223 1131 20
30 3810
30
30 3810
42868 272350Flare
43132 273246Frse
43389 274147Flare
272350
273246
27414T
4520 75
4460 76
1 130
1 070
27120 355706 3390
25690 356777 3390
81360 211 1 244 1577258 7 ITOXO
81350 2114633 1576919 7 170XO
01
01
557 123000 23250 23250 2046 6372
130000 23300 23300 2121 6374
133000 23350 23350 2232 6377
iiii 1110 20
2223 1103 20
iiii 1117 20
30
30 3810
30
43003 275047Flee
42873 275941Flare
43394 276840Flee
27504T
275941
276840
5100 75 1 275 X600 358052 3825 91800 211845815765367 170XO 01
1400002340023400 2091 6312 2223 1207 22 30 3810 46657 277778Flare 2T7778 4810 76 1 154 27706 359206 3656 87734 21221 14 1576171 7 ITOXO488 0I
1400002340023400FPI=488@ aficG 26pull060'FSpe ravily=0 t849H ppm
1430002345023450 2127 6333
1500002350023500 2175 6351
1530002355023550 2169 6342
1600002360023600 2153 6321
1630002365023650 2189 6291
iiii 1103 20
2223 1138 20
riii 1117 21
2223 1138 20
iiii 1117 20
30
30 3810
30
30 3810
30
43134 278713Frse
43518 279616Flare
43655 280524Flee
43t82 281435Flare
43132 282340Flse
278713
279616
280524
281435
282340
4620 74
4240 75
I 201
I 060
28829 360407 3419
25440 361467 3 180
82051 212553315758297 170XO
76320 2128713 1575511 7 170XO
01
01
1700002370023700 2177 6294
1730002375023750 2212 6270
1800002380023800 2201 6299
2223 1138 21
iiii 1117 20
2223 1138 21
30 3810
30
30 3810
44307 283251Flare
43394 284164Flse
44046 285075Flare
283251
284164
285075
4020 76
4330 75
0965
I 083
23155 362432 3055
25980 363514 3247
73325213176815752057 170XO 01
77940 2135016 1574880 7 170XO488 0I
5TO 1800002380023800FPI=488@ aficG 26pull060'FSpe ravily=0 t849H ppm
5TI
5T4
5T5
576
1830002385023850 2210 6291
1900002390023900 2046 6278
1930002395023950 2110 6281
2000002400024000 2146 6272
2030002405024050 2100 6270
210000 24100 24100 2010 6268
213000 24150 24150 2011 6255
iiii 1117 20
2223 1110 20
iiii 1110 20
2223 1103 20
iiii 1103 20
2223 1103 20
iiii 1110 20
30
30 3810
30
30 3810
30
30 3810
30
43132 285983Flse
42t39 286878Flare
42739 287768Free
42873 288660Flare
42611 289551Free
42873 290441Flare
42739 291333Flee
285983
286878
287768
288660
289551
290441
291333
4210 73
4090 73
4160 72
1137
1 104
1 165
27281 364651 3073
26503 365755 2986
27955 366920 2995
73759 2138089 1574573 7 172XO
71657 2141075 1574275 7 I72XO
71885 2144070 1573975 7 172XO
01
01
01
578 2200002420024200 1916 6249 2223 1103 20 30 3810 42873 292225Flare 292225 4350 73 1 174 28188 368095 3 176 76212 2147245 1573657 7 I72XO487 0I
2200002420024200FPI=487@ aficG 26pull060'FSpe ravily=0 t854H ppm
2230002425024250 1910 6247
2300002430024300 1945 6279
2330002435024350 2001 6269
583 2015IIV060000002440024400 1919 6264
iiii 965 24
2223 951 25
iiii 958 25
2223 951 24
30
30 3810
30
30 3810
43717 293127Frse
44298 294043Flare
44232 294966Flee
43639 295881Flare
29312T
294043
294966
295881
4110 74
4010 75
1 069
1 002
25646 369163 3041
24060 370166 3008
72994 2150287 1573353 7 172XO
72180 2153294 1573053 7 I72XO
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAwell24864DOWBFlowTnstlSQRP5
ProdnctiontestingASchlumbergerOsmpany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 25
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %554 2015/11/05 11:00:00 231.00 231.00 2156 6392 37 22.23 1117 20 30 38.10 42.868 272.350 Flare 272.350 4.520 75 1.130 27.120 355.706 3.390 81.360 2111.244 15772.58 7 170000 0.1555 11:30:00 231.50 231.50 2051 6386 37 22.23 1117 20 30 38.10 43.132 273.246 Flare 273.246 75 0.1556 12:00:00 232.00 232.00 2043 6388 37 22.23 1131 20 30 38.10 43.389 274.147 Flare 274.147 4.460 76 1.070 25.690 356.777 3.390 81.350 2114.633 15769.19 7 170000 0.1557 12:30:00 232.50 232.50 2046 6372 38 22.23 1110 20 30 38.10 43.003 275.047 Flare 275.047 76 0.1558 13:00:00 233.00 233.00 2121 6374 38 22.23 1103 20 30 38.10 42.873 275.941 Flare 275.941 5.100 75 1.275 30.600 358.052 3.825 91.800 2118.458 15765.36 7 170000 0.1559 13:30:00 233.50 233.50 2232 6377 37 22.23 1117 20 30 38.10 43.394 276.840 Flare 276.840 75 0.1560 14:00:00 234.00 234.00 2091 6312 37 22.23 1207 22 30 38.10 46.657 277.778 Flare 277.778 4.810 76 1.154 27.706 359.206 3.656 87.734 2122.114 15761.71 7 170000 48.8 0.1561 14:00:00 234.00 234.00 API = 48.8 @ 60°F , Specific Gravity = 0.7849, H2S pull 0ppm.562 14:30:00 234.50 234.50 2127 6333 37 22.23 1103 20 30 38.10 43.134 278.713 Flare 278.713 76 0.1563 15:00:00 235.00 235.00 2175 6351 38 22.23 1138 20 30 38.10 43.518 279.616 Flare 279.616 4.620 74 1.201 28.829 360.407 3.419 82.051 2125.533 15758.29 7 170000 0.1564 15:30:00 235.50 235.50 2169 6342 38 22.23 1117 21 30 38.10 43.655 280.524 Flare 280.524 74 0.1565 16:00:00 236.00 236.00 2153 6321 38 22.23 1138 20 30 38.10 43.782 281.435 Flare 281.435 4.240 75 1.060 25.440 361.467 3.180 76.320 2128.713 15755.11 7 170000 0.1566 16:30:00 236.50 236.50 2189 6291 38 22.23 1117 20 30 38.10 43.132 282.340 Flare 282.340 75 0.1567 17:00:00 237.00 237.00 2177 6294 38 22.23 1138 21 30 38.10 44.307 283.251 Flare 283.251 4.020 76 0.965 23.155 362.432 3.055 73.325 2131.768 15752.05 7 170000 0.1568 17:30:00 237.50 237.50 2212 6270 38 22.23 1117 20 30 38.10 43.394 284.164 Flare 284.164 76 0.1569 18:00:00 238.00 238.00 2201 6299 38 22.23 1138 21 30 38.10 44.046 285.075 Flare 285.075 4.330 75 1.083 25.980 363.514 3.247 77.940 2135.016 15748.80 7 170000 48.8 0.1570 18:00:00 238.00 238.00 API = 48.8 @ 60°F , Specific Gravity = 0.7849, H2S pull 0ppm.571 18:30:00 238.50 238.50 2210 6291 38 22.23 1117 20 30 38.10 43.132 285.983 Flare 285.983 75 0.1572 19:00:00 239.00 239.00 2046 6278 38 22.23 1110 20 30 38.10 42.739 286.878 Flare 286.878 4.210 73 1.137 27.281 364.651 3.073 73.759 2138.089 15745.73 7 172000 0.1573 19:30:00 239.50 239.50 2110 6281 38 22.23 1110 20 30 38.10 42.739 287.768 Flare 287.768 73 0.1574 20:00:00 240.00 240.00 2146 6272 38 22.23 1103 20 30 38.10 42.873 288.660 Flare 288.660 4.090 73 1.104 26.503 365.755 2.986 71.657 2141.075 15742.75 7 172000 0.1575 20:30:00 240.50 240.50 2100 6270 38 22.23 1103 20 30 38.10 42.611 289.551 Flare 289.551 73 0.1576 21:00:00 241.00 241.00 2010 6268 38 22.23 1103 20 30 38.10 42.873 290.441 Flare 290.441 4.160 72 1.165 27.955 366.920 2.995 71.885 2144.070 15739.75 7 172000 0.1577 21:30:00 241.50 241.50 2011 6255 38 22.23 1110 20 30 38.10 42.739 291.333 Flare 291.333 72 0.1578 22:00:00 242.00 242.00 1916 6249 38 22.23 1103 20 30 38.10 42.873 292.225 Flare 292.225 4.350 73 1.174 28.188 368.095 3.176 76.212 2147.245 15736.57 7 172000 48.7 0.1579 22:00:00 242.00 242.00 API = 48.7 @ 60°F , Specific Gravity = 0.7854, H2S pull 0ppm.580 22:30:00 242.50 242.50 1910 6247 38 22.23 965 24 30 38.10 43.717 293.127 Flare 293.127 73 0.1581 23:00:00 243.00 243.00 1945 6279 38 22.23 951 25 30 38.10 44.298 294.043 Flare 294.043 4.110 74 1.069 25.646 369.163 3.041 72.994 2150.287 15733.53 7 172000 0.1582 23:30:00 243.50 243.50 2001 6269 38 22.23 958 25 30 38.10 44.232 294.966 Flare 294.966 74 0.1583 2015/11/06 00:00:00 244.00 244.00 1919 6264 38 22.23 951 24 30 38.10 43.639 295.881 Flare 295.881 4.010 75 1.002 24.060 370.166 3.008 72.180 2153.294 15730.53 7 172000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Time Cum Row Tubing6 ming
Pres Pres
FlowChokeBshe
TempSns Pres
Dg MIR Piste
Pres TempGze
GasRats CumGas Gas TotalGas RdVd
To Flared
BSWDlFmn OilRale OICumWater WaterWaterGum
Gain Rate
loarlLTRPH SalinilyAPI Smd
Cd
WWlmnldd
2015MV06
hhmmss
000000 24400 24400
kPag kPag
0000Irmmsdii10
'0 mm kPart kPa '0 mm 1tym'Id IRm'tyap(ljm''Idm'pm'API
FlowingTubmgpressure=1919kPa
ShutmCasingpressure=6264kPa
Flowingtemperature=38'0
Chokesize=56I6402223mmi
GasRate=4622IOVP
TotaHluidrate=401 m'Ihr
Waterrecoveryrate=301m'Ihr
Condensaterate= 1 00m'Ihr
PH=t,Salinity=172XOppmBSSW=75S
API=487@60'F,Separator=951kPagH'S=0 ppmSand=00%
Dailyhrsgowed=24hrs
Cumhrsflowed=244hrs
Dailygasproducedtoflarelast24hrs=43571tPm'um
gasProducedtoflare=295881IOVP
CondProducedlast24hrs= 2696m'um
CondProduced=37017
m'ater
Recoveredlast24Hrs=8047m'otal
WaterRecovered=215329
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1573053
m'ercentageRecoveredfromInmalLoad= 1204B
Chokeswashedin24bourn=g
Totalchokeswashed=0
003000
010000
013000
020000
24450
24500
24550
24600
24450
24500
24550
24600
1895 6227
1910 6219
1875 6189
1825 6118
iiii 931 24
2223 931 24
iiii 931 24
2223 924 24
42964
3810 43183
42964
3810 42812
296783Flee 296783
297680Flare 297680
298578Flee 298578
299471Flare 299471
4050 75
4030 74
I 012 24300 371178 3037
I 048 25147 372226 2982
72900
71573
2156332
2159314
1572749
1572451
7 174XO
7 174XO
01
487 01
020000 24600 24600 oficGAPI=487@ 25pull060'FSpe ravily=0 t854H ppm
591
597
023000
030000
033000
040000
043000
050000
053000
060000
24650
24700
24750
24800
24850
24900
24950
25000
24650
24T00
24T50
24800
24850
24900
24950
25000
1899 6105
1955 6107
1998 6110
1901 6097
1917 6096
1901 6092
1812 6089
1895 6086
iiii 924 24
2223 931 24
iiii 917 24
2223 924 24
iiii 903 24
2223 896 23
iiii 903 23
2223 896 23
43031
3810 42964
42507
3810 42877
42202
3810 41615
41548
3810 41615
300365Flee 3X365
301261Flare 301261
302152Ftze 302152
303041Flare 303041
303927Ftze 30392T
304800Flare 304800
305667Ftze 30566T
306533Flare 306533
3710 73
4090 73
3670 74
3900 73
I 002 24041 373228 2708
1 104 26503 374332 2986
0954 22901 375286 2716
I 053 25272 376339 2847
64999
71657
65179
68328
2162022
2165008
2167724
2170571
1572180
1571881
1571610
1571325
7 174XO
7 174XO
7 174XO
7 174XO
01
01
01
487 01
060000 25000 25000 oficGAPI=487@ 25pull060'FSpe ravily=0 t854H ppm
063000
070000
073000
080000
083000
090000
093000
100000
25050
25100
25150
25200
25250
25300
25350
25400
25050
25100
25150
25200
25250
25300
25350
25400
1789 6079
1894 6078
2013 6063
1977 6060
2025 6045
1931 6048
1989 6033
1924 6021
iiii 896 23
2223 896 23
iiii 910 23
2223 910 23
iiii 896 23
2223 931 23
iiii 910 23
2223 896 23
41397
3810 41397
41918
3810 41698
41105
3810 42294
41844
3810 41324
307398Ftze 307398
308260Flare 308260
309128F le e 309128
309999Flare 309999
310861Ftze 310861
311 730Flare 311 730
312607Ftze 31260T
313473Flare 313473
3680 74
3610 75
4370
3190 76
0957 22963 377296 2723
0902 21660 378199 2708
I 092 26220 379291 3278
0766 18374 380057 2424
65357
64980
78660
58186
2173294
2176001
2179279
2181703
1571053
1570782
1570454
1570212
7 174XO
7 174XO
7 174XO
7 174XO
01
01
01
485 01
100000
103000
25400
25450
25400
25450
Apl=485@60'6SpeoficGravily=07860H25pullgppm
2096 6013 36 iiii 896 23 33 XI: 41324 314334Flee 314334
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIMG,.IAweD24864DOWSFlowTestlSQRP6
PrndnctinntestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 26
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %584 2015/11/06 00:00:00 244.00 244.00 00:00 hrs reading
Flowing Tubing pressure = 1919 kPaShut in Casing pressure = 6264 kPaFlowing temperature = 38°CChoke size = 56/64 (22.23mm)Gas Rate = 46.22 10³m³Total fluid rate = 4.01 m³/hrWater recovery rate = 3.01 m³/hrCondensate rate = 1.00 m³/hrPH =7 , Salinity = 172000 ppm, BS&W = 75 %API = 48.7 @ 60°F, Separator = 951 kPag H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 244 hrsDaily gas produced to flare last 24 hrs = 43.57 10³m³Cum gas Produced to flare= 295.881 10³m³Cond Produced last 24 hrs = 26.96 m³Cum Cond Produced = 370.17 m³Water Recovered Last 24 Hrs = 80.47 m³Total Water Recovered = 2153.29 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15730.53 m³ Percentage Recovered from Initial Load = 12.04 %Chokes washed in 24 hours=0Total chokes washed =0
585 00:30:00 244.50 244.50 1895 6227 38 22.23 931 24 30 38.10 42.964 296.783 Flare 296.783 75 0.1586 01:00:00 245.00 245.00 1910 6219 38 22.23 931 24 30 38.10 43.183 297.680 Flare 297.680 4.050 75 1.012 24.300 371.178 3.037 72.900 2156.332 15727.49 7 174000 0.1587 01:30:00 245.50 245.50 1875 6189 38 22.23 931 24 30 38.10 42.964 298.578 Flare 298.578 75 0.1588 02:00:00 246.00 246.00 1825 6118 38 22.23 924 24 30 38.10 42.812 299.471 Flare 299.471 4.030 74 1.048 25.147 372.226 2.982 71.573 2159.314 15724.51 7 174000 48.7 0.1589 02:00:00 246.00 246.00 API = 48.7 @ 60°F , Specific Gravity = 0.7854, H2S pull 0ppm.590 02:30:00 246.50 246.50 1899 6105 38 22.23 924 24 30 38.10 43.031 300.365 Flare 300.365 74 0.1591 03:00:00 247.00 247.00 1955 6107 38 22.23 931 24 30 38.10 42.964 301.261 Flare 301.261 3.710 73 1.002 24.041 373.228 2.708 64.999 2162.022 15721.80 7 174000 0.1592 03:30:00 247.50 247.50 1998 6110 38 22.23 917 24 32 38.10 42.507 302.152 Flare 302.152 73 0.1593 04:00:00 248.00 248.00 1901 6097 38 22.23 924 24 32 38.10 42.877 303.041 Flare 303.041 4.090 73 1.104 26.503 374.332 2.986 71.657 2165.008 15718.81 7 174000 0.1594 04:30:00 248.50 248.50 1917 6096 38 22.23 903 24 32 38.10 42.202 303.927 Flare 303.927 73 0.1595 05:00:00 249.00 249.00 1901 6092 37 22.23 896 23 32 38.10 41.615 304.800 Flare 304.800 3.670 74 0.954 22.901 375.286 2.716 65.179 2167.724 15716.10 7 174000 0.1596 05:30:00 249.50 249.50 1812 6089 37 22.23 903 23 32 38.10 41.548 305.667 Flare 305.667 74 0.1597 06:00:00 250.00 250.00 1895 6086 37 22.23 896 23 32 38.10 41.615 306.533 Flare 306.533 3.900 73 1.053 25.272 376.339 2.847 68.328 2170.571 15713.25 7 174000 48.7 0.1598 06:00:00 250.00 250.00 API = 48.7 @ 60°F , Specific Gravity = 0.7854, H2S pull 0ppm.599 06:30:00 250.50 250.50 1789 6079 35 22.23 896 23 32 38.10 41.397 307.398 Flare 307.398 73 0.1600 07:00:00 251.00 251.00 1894 6078 36 22.23 896 23 32 38.10 41.397 308.260 Flare 308.260 3.680 74 0.957 22.963 377.296 2.723 65.357 2173.294 15710.53 7 174000 0.1601 07:30:00 251.50 251.50 2013 6063 37 22.23 910 23 32 38.10 41.918 309.128 Flare 309.128 74 0.1602 08:00:00 252.00 252.00 1977 6060 37 22.23 910 23 32 38.10 41.698 309.999 Flare 309.999 3.610 75 0.902 21.660 378.199 2.708 64.980 2176.001 15707.82 7 174000 0.1603 08:30:00 252.50 252.50 2025 6045 37 22.23 896 23 33 38.10 41.105 310.861 Flare 310.861 75 0.1604 09:00:00 253.00 253.00 1931 6048 37 22.23 931 23 33 38.10 42.294 311.730 Flare 311.730 4.370 75 1.092 26.220 379.291 3.278 78.660 2179.279 15704.54 7 174000 0.1605 09:30:00 253.50 253.50 1989 6033 37 22.23 910 23 33 38.10 41.844 312.607 Flare 312.607 75 0.1606 10:00:00 254.00 254.00 1924 6021 36 22.23 896 23 33 38.10 41.324 313.473 Flare 313.473 3.190 76 0.766 18.374 380.057 2.424 58.186 2181.703 15702.12 7 174000 48.5 0.1607 10:00:00 254.00 254.00 API = 48.5 @ 60°F , Specific Gravity = 0.7860, H2S pull 0ppm.608 10:30:00 254.50 254.50 2096 6013 36 22.23 896 23 33 38.10 41.324 314.334 Flare 314.334 76 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row Tubing
Pres
Well
Cming
Pres
FlowChoke%abc
TempSas Pres
Dg
Pres
OnficeDryRowMalar
MIR Piste GasRatsCumGasGas
TempGze To
TotalGas
Flared
RdVdBSWOIGanOilRale OIGum
Roid
Wstw
Gain
WaterCumloarlLTRPH
dume
2
SalinilyAPI Smd
CM
WWlemldd
bX2015IIV06
610
811
612
hhmmssHrs Hrs
1100002550025500
1130002555025550
120000 25600 25600
1230002565025650
kPag
2101
2021
1938
1917
kPag
6024
6025
6020
5991
'0 mm kPerr
37 2223 924
37 iiii 910
37 2223 896
37 iiii 910
'0 mm 1tym'ldIIPm'3
3810 42144 315203Flare
33 %1: 41844 316078Flee
33 3810 41324 316944Flare
33 %1: 41624 317809Flee
315203
316078
316944
317809
ii)m'
090
3680
m''Id m'
063 25522 381120
0994 23846 382114
3027
2686
72638
64474
21847301%99097
21874161%96407
ppm 'API
174XO
174XO
01
01
613
614
615
616
130000 25700 25700
133000 25750 25750
140000 25800 25800
140000 25800 25800
59831977
1992
1923
1=485@
5992
5975
60'FSpe
37 2223 896
37 iiii 931
37 2223 910
oficGravity=0 7860H25pull0
33 3810 41542 318675Flare
33 %1: 42294 319548Flee
33 3810 41624 320422Flare
ppm
318675
319548
320422
3800
3700
0950 22800 383064
0888 21312 383952
2850
2812
68400
67488
2190266 I%9355 7
21930781%90747
174XO 01
174XO485 01
617
618
619
1430002585025850
1500002590025900
1530002595025950
160000 26000 26000
163000 26050 26050
170000 26100 26100
173000 26150 26150
1944
2026
2015
2001
2008
1920
1979
5989
5988
5989
5985
5953
5950
5947
37 iiii 931
38 2223 910
37 iiii 910
38 2223 924
37 iiii 931
37 2223 910
37 iiii 910
33 %1: 42294 321296Flee
33 3810 41624 322171Flare
33 %1: 41624 323038Flee
33 3810 42144 323910Flare
33 %I: 42515 324792Flee
33 3810 41844 325671Flare
33 %1: 41844 326543Flee
321296
322171
323038
323910
324792
325671
326543
3880
3840
4150
I 009 24211 384960
0960 23040 385920
0996 23904 386916
2871
2880
3 154
68909
69120
75696
21959491%87877
2198829 I%8499 7
22019831%81847
174XO
174XO
174XO
01
01
01
180000 26200 26200
180000 26200 26200
2021
1=488@
5941
60'FSpe
37 2223 931
oficGravily=07849H25pull0
33 3810 42294 327419Flare
ppm
327419 3730 0970 23275 387886 2760 66245 2204744 I%7908 7 174XO488 01
631
183000 26250 26250
190000 26300 26300
1930002635026350
2000002640026400
2030002645026450
210000 26500 26500
213000 26550 26550
1991
1914
1901
2012
1997
1912
1921
5934
5XI
5898
5877
5869
5862
5861
37 iiii 951
37 2223 951
37 iiii 945
37 2223 945
37 iiii 917
37 2223 910
37 iiii 903
33 %1: 43185 328310Flss
33 3810 42963 329207Flare
33 %I: 42591 330098Flee
33 3810 42591 330985Flare
33 %1: 41994 331867Flss
33 3810 41624 332738Flare
33 %I: 41693 333605Flee
328310
32920T
3X098
3X985
33186T
332738
333605
2990
3140
2750
0748 17940 388634
0754 18086 389387
0715 17160 390102
2242
2386
2035
53820
57274
48840
2206986 I%7683 7
2209373 I%7445 7
2211 408 I%7241 7
174XO
174XO
174XO
01
01
01
220000 26600 26600
220000 26600 26600
5849 33 3810 41774 334475Flare1899 37 2223 917
oficGravily=07886H60'FSpe 25pull01=479@ ppm
334475 3830 0996 23899 391098 2834 68021 22142421%69587 174XO479 01
637
638 2015IIVOT
2230002665026650
230000 26700 26700
233000 26750 26750
0000002680026800
1902
1912
1969
1922
5837
5850
5849
5845
37 iiii 910
37 2223 896
37 iiii 910
37 2223 917
33 %1: 41844 335346Flee
33 3810 41324 336212Flare
33 %I: 41 181 337072Flee
33 3810 41552 337934Flare
335346
336212
337072
337934
3780
3830
0945 22680 392043
0996 23899 393039
2835
2834
68040
68021
22170771%66747
22199111%63917
174XO
174XO
01
01
PetroClassFlowTestVersion4.5.0.5
8:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAweD2%864DOWBFlowTestlSQRPT
ProdnctiontestingASchlumbergerOsmpany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 27
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %609 2015/11/06 11:00:00 255.00 255.00 2101 6024 37 22.23 924 23 33 38.10 42.144 315.203 Flare 315.203 4.090 74 1.063 25.522 381.120 3.027 72.638 2184.730 15699.09 7 174000 0.1610 11:30:00 255.50 255.50 2021 6025 37 22.23 910 23 33 38.10 41.844 316.078 Flare 316.078 74 0.1611 12:00:00 256.00 256.00 1938 6020 37 22.23 896 23 33 38.10 41.324 316.944 Flare 316.944 3.680 73 0.994 23.846 382.114 2.686 64.474 2187.416 15696.40 7 174000 0.1612 12:30:00 256.50 256.50 1917 5991 37 22.23 910 23 33 38.10 41.624 317.809 Flare 317.809 73 0.1613 13:00:00 257.00 257.00 1977 5983 37 22.23 896 23 33 38.10 41.542 318.675 Flare 318.675 3.800 75 0.950 22.800 383.064 2.850 68.400 2190.266 15693.55 7 174000 0.1614 13:30:00 257.50 257.50 1992 5992 37 22.23 931 23 33 38.10 42.294 319.548 Flare 319.548 75 0.1615 14:00:00 258.00 258.00 1923 5975 37 22.23 910 23 33 38.10 41.624 320.422 Flare 320.422 3.700 76 0.888 21.312 383.952 2.812 67.488 2193.078 15690.74 7 174000 48.5 0.1616 14:00:00 258.00 258.00 API = 48.5 @ 60°F , Specific Gravity = 0.7860, H2S pull 0ppm.617 14:30:00 258.50 258.50 1944 5989 37 22.23 931 23 33 38.10 42.294 321.296 Flare 321.296 76 0.1618 15:00:00 259.00 259.00 2026 5988 38 22.23 910 23 33 38.10 41.624 322.171 Flare 322.171 3.880 74 1.009 24.211 384.960 2.871 68.909 2195.949 15687.87 7 174000 0.1619 15:30:00 259.50 259.50 2015 5989 37 22.23 910 23 33 38.10 41.624 323.038 Flare 323.038 74 0.1620 16:00:00 260.00 260.00 2001 5985 38 22.23 924 23 33 38.10 42.144 323.910 Flare 323.910 3.840 75 0.960 23.040 385.920 2.880 69.120 2198.829 15684.99 7 174000 0.1621 16:30:00 260.50 260.50 2008 5953 37 22.23 931 24 33 38.10 42.515 324.792 Flare 324.792 75 0.1622 17:00:00 261.00 261.00 1920 5950 37 22.23 910 23 33 38.10 41.844 325.671 Flare 325.671 4.150 76 0.996 23.904 386.916 3.154 75.696 2201.983 15681.84 7 174000 0.1623 17:30:00 261.50 261.50 1979 5947 37 22.23 910 23 33 38.10 41.844 326.543 Flare 326.543 76 0.1624 18:00:00 262.00 262.00 2021 5941 37 22.23 931 23 33 38.10 42.294 327.419 Flare 327.419 3.730 74 0.970 23.275 387.886 2.760 66.245 2204.744 15679.08 7 174000 48.8 0.1625 18:00:00 262.00 262.00 API = 48.8 @ 60°F , Specific Gravity = 0.7849, H2S pull 0ppm.626 18:30:00 262.50 262.50 1991 5934 37 22.23 951 24 33 38.10 43.185 328.310 Flare 328.310 74 0.1627 19:00:00 263.00 263.00 1914 5901 37 22.23 951 24 33 38.10 42.963 329.207 Flare 329.207 2.990 75 0.748 17.940 388.634 2.242 53.820 2206.986 15676.83 7 174000 0.1628 19:30:00 263.50 263.50 1901 5898 37 22.23 945 23 33 38.10 42.591 330.098 Flare 330.098 75 0.1629 20:00:00 264.00 264.00 2012 5877 37 22.23 945 23 33 38.10 42.591 330.985 Flare 330.985 3.140 76 0.754 18.086 389.387 2.386 57.274 2209.373 15674.45 7 174000 0.1630 20:30:00 264.50 264.50 1997 5869 37 22.23 917 23 33 38.10 41.994 331.867 Flare 331.867 76 0.1631 21:00:00 265.00 265.00 1912 5862 37 22.23 910 23 33 38.10 41.624 332.738 Flare 332.738 2.750 74 0.715 17.160 390.102 2.035 48.840 2211.408 15672.41 7 174000 0.1632 21:30:00 265.50 265.50 1921 5861 37 22.23 903 23 33 38.10 41.693 333.605 Flare 333.605 74 0.1633 22:00:00 266.00 266.00 1899 5849 37 22.23 917 23 33 38.10 41.774 334.475 Flare 334.475 3.830 74 0.996 23.899 391.098 2.834 68.021 2214.242 15669.58 7 174000 47.9 0.1634 22:00:00 266.00 266.00 API = 47.9 @ 60°F , Specific Gravity = 0.7886, H2S pull 0ppm.635 22:30:00 266.50 266.50 1902 5837 37 22.23 910 23 33 38.10 41.844 335.346 Flare 335.346 74 0.1636 23:00:00 267.00 267.00 1912 5850 37 22.23 896 23 33 38.10 41.324 336.212 Flare 336.212 3.780 75 0.945 22.680 392.043 2.835 68.040 2217.077 15666.74 7 174000 0.1637 23:30:00 267.50 267.50 1969 5849 37 22.23 910 23 33 38.10 41.181 337.072 Flare 337.072 75 0.1638 2015/11/07 00:00:00 268.00 268.00 1922 5845 37 22.23 917 23 33 38.10 41.552 337.934 Flare 337.934 3.830 74 0.996 23.899 393.039 2.834 68.021 2219.911 15663.91 7 174000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Dale Time Cum Row
Well
Tubing0 ming
Pres Pres
FlowChoke%abc Dg
TempSae Pres Pres
OnficeDryRowMelar
MIR
Temp
CumGas Gas
To
TotalGas RdVd
Flared
Rnid
BSWOIGanOilRale OIGum Water
Gain
WaterWaterGum
IMM
inertLTR
dume
2
PH SalinilyAPI Smd
CM
WWlmnlddhhmmss
2015HVOT00000026800 26800
kPag kPag
0000Irmmsdir10
'0 mm kPan kPa mm lipm'id Ityap (I)m'''Idm'pm'API
FlowingTubmgpressure=1922kPa
ShutmCasingpressure=6845kPa
Flowingtemperature=38'0
Chokesize=56I64f2223mmi
GasRate=4402IOVP
Totalguidrate=383 m'Ihr
Waterrecoveryrate=283m'Ihr
Condensaterate= 1 00m'Ihr
PH=T,Salinity=172XOppmBXW=74'I
API=487@60'F,Separator=917kPagH'S=0 ppmSand=00H
Dailyhrsgowed=24hrs
Cumhrsflowed=268hrs
Dailygasproducedtoflarelast24hrs=42051tPm'um
gasProducedtoflare=33793410VP
CondProducedlast24hrs= 2287m'um
CondProduced=39304m'ater
Recoveredlast24Hrs=6662m'otal
WaterRecovered=221991
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1566391
m'ercentageRecoveredfromInmalLoad= 1240H
Chokeswashedin24bourn=g
Totalchokeswashed=0
003000
010000
013000
020000
26850
26900
26950
27000
26850
26900
26950
27000
1890 5837
1833 5836
1839 5833
1949 5846
iiii 896
2223 931
iiii 951
2223 924
3810
3810
41689 338801
42810 339681
42816 340573
42073 341457
Flze 338801
Flare 339681
Flze 340573
Flare 341457
3670 74
3420 74
0954
0889
22901 393993
21341 394882
2716
2531
65179
60739
2222627
2225158
1%61197
1%5866 7
174XO
176XO
01
481 01
020000 27000 27000 aficGAPI=481@ 25pull060'FSpe ravily=0 7879H ppm
651
023000
030000
033000
040000
043000
050000
053000
060000
27050
27100
27150
27200
27250
27300
27350
27400
27050
27100
27150
27200
27250
27300
27350
27400
1912 5844
1879 5842
1910 5841
1883 5833
1907 5832
1899 5831
1876 5829
1902 5827
iiii 931
2223 945
iiii 958
2223 958
iiii 958
2223 951
iiii 931
2223 951
3810
3810
3810
3810
41998 342333
42744 343215
42815 344107
42587 344996
42359 345881
42667 346767
42445 347653
42441 348538
Flze 342333
Flare 343215
Flze 344IOT
Flze 344996
Flee 345881
Flare 346767
Flze 347653
Flare 348538
3470 75
3690 74
3630 75
3650 75
0867
0959
0907
0912
20820 395750
23026 396709
21780 397617
21900 398529
2603
2731
2722
2738
62460
65534
65340
65700
2227760
2230491
2233213
2235951
1%56067
1%53337
1%50617
1%47877
176XO
176XO
176XO
176XO
01
01
01
479 01
060000 27400 27400 aficGravily=0 7886HAPI=479@ 25pull060'FSpe ppm
657
063000
070000
073000
080000
083000
090000
093000
100000
27450
27500
27550
27600
27650
27700
27750
27800
27450
27500
27550
27600
27650
27T00
27T50
27800
1713 5807
1980 5789
1627 5781
2001 5778
1873 5772
1950 5768
1731 5737
2047 5726
iiii 917
2223 896
iiii 945
2223 931
iiii 910
2223 951
iiii 910
2223 951
3810
3810
3810
3810
41477 349412
40358 350264
42293 351125
41546 351999
40878 352857
42667 353727
41551 354605
431 16 355487
FI-: 34941 2
Flare 350264
Ftze 351125
Flare 351999
Ftze 35285T
Flare 353727
Flze 354605
Flare 355487
3840
3450 72
3740 74
3480 75
0960
0966
0972
0870
23040 399489
23184 400455
23338 401428
20880 402298
2880
2484
2768
2610
69120
59616
66422
62640
2238831
2241315
2244082
2246692
1%44997
1%42517
1%39747
1%37137
176XO
176XO
176XO
176XO
01
01
01
475 01
100000
103000
27800
27850
27800
27850
Apl=475@60'7SpeaficGravily=07817H25pullgppm
2295 5697 36 iiii 931 23 31 %I: 42445 356378Flee 356378
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIMG,.IAweD2%864IOWSFlowTestlSQRP8
ProdnctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 28
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %639 2015/11/07 00:00:00 268.00 268.00 00:00 hrs reading
Flowing Tubing pressure = 1922 kPaShut in Casing pressure = 6845 kPaFlowing temperature = 38°CChoke size = 56/64 (22.23mm)Gas Rate = 44.02 10³m³Total fluid rate = 3.83 m³/hrWater recovery rate = 2.83 m³/hrCondensate rate = 1.00 m³/hrPH =7 , Salinity = 172000 ppm, BS&W = 74 %API = 48.7 @ 60°F, Separator = 917 kPag H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 268 hrsDaily gas produced to flare last 24 hrs = 42.05 10³m³Cum gas Produced to flare= 337.934 10³m³Cond Produced last 24 hrs = 22.87 m³Cum Cond Produced = 393.04 m³Water Recovered Last 24 Hrs = 66.62 m³Total Water Recovered = 2219.91 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15663.91 m³ Percentage Recovered from Initial Load = 12.40 %Chokes washed in 24 hours=0Total chokes washed =0
640 00:30:00 268.50 268.50 1890 5837 37 22.23 896 23 31 38.10 41.689 338.801 Flare 338.801 74 0.1641 01:00:00 269.00 269.00 1833 5836 37 22.23 931 24 32 38.10 42.810 339.681 Flare 339.681 3.670 74 0.954 22.901 393.993 2.716 65.179 2222.627 15661.19 7 174000 0.1642 01:30:00 269.50 269.50 1839 5833 37 22.23 951 23 32 38.10 42.816 340.573 Flare 340.573 74 0.1643 02:00:00 270.00 270.00 1949 5846 38 22.23 924 23 31 38.10 42.073 341.457 Flare 341.457 3.420 74 0.889 21.341 394.882 2.531 60.739 2225.158 15658.66 7 176000 48.1 0.1644 02:00:00 270.00 270.00 API = 48.1 @ 60°F , Specific Gravity = 0.7879, H2S pull 0ppm.645 02:30:00 270.50 270.50 1912 5844 38 22.23 931 23 31 38.10 41.998 342.333 Flare 342.333 74 0.1646 03:00:00 271.00 271.00 1879 5842 38 22.23 945 23 31 38.10 42.744 343.215 Flare 343.215 3.470 75 0.867 20.820 395.750 2.603 62.460 2227.760 15656.06 7 176000 0.1647 03:30:00 271.50 271.50 1910 5841 38 22.23 958 23 31 38.10 42.815 344.107 Flare 344.107 75 0.1648 04:00:00 272.00 272.00 1883 5833 37 22.23 958 23 31 38.10 42.587 344.996 Flare 344.996 3.690 74 0.959 23.026 396.709 2.731 65.534 2230.491 15653.33 7 176000 0.1649 04:30:00 272.50 272.50 1907 5832 37 22.23 958 23 31 38.10 42.359 345.881 Flare 345.881 74 0.1650 05:00:00 273.00 273.00 1899 5831 37 22.23 951 23 31 38.10 42.667 346.767 Flare 346.767 3.630 75 0.907 21.780 397.617 2.722 65.340 2233.213 15650.61 7 176000 0.1651 05:30:00 273.50 273.50 1876 5829 37 22.23 931 23 31 38.10 42.445 347.653 Flare 347.653 75 0.1652 06:00:00 274.00 274.00 1902 5827 37 22.23 951 23 31 38.10 42.441 348.538 Flare 348.538 3.650 75 0.912 21.900 398.529 2.738 65.700 2235.951 15647.87 7 176000 47.9 0.1653 06:00:00 274.00 274.00 API = 47.9 @ 60°F , Specific Gravity = 0.7886, H2S pull 0ppm.654 06:30:00 274.50 274.50 1713 5807 36 22.23 917 23 31 38.10 41.477 349.412 Flare 349.412 75 0.1655 07:00:00 275.00 275.00 1980 5789 37 22.23 896 22 31 38.10 40.358 350.264 Flare 350.264 3.840 75 0.960 23.040 399.489 2.880 69.120 2238.831 15644.99 7 176000 0.1656 07:30:00 275.50 275.50 1627 5781 37 22.23 945 23 31 38.10 42.293 351.125 Flare 351.125 75 0.1657 08:00:00 276.00 276.00 2001 5778 37 22.23 931 22 31 38.10 41.546 351.999 Flare 351.999 3.450 72 0.966 23.184 400.455 2.484 59.616 2241.315 15642.51 7 176000 0.1658 08:30:00 276.50 276.50 1873 5772 36 22.23 910 22 31 38.10 40.878 352.857 Flare 352.857 72 0.1659 09:00:00 277.00 277.00 1950 5768 36 22.23 951 23 31 38.10 42.667 353.727 Flare 353.727 3.740 74 0.972 23.338 401.428 2.768 66.422 2244.082 15639.74 7 176000 0.1660 09:30:00 277.50 277.50 1731 5737 36 22.23 910 23 31 38.10 41.551 354.605 Flare 354.605 74 0.1661 10:00:00 278.00 278.00 2047 5726 36 22.23 951 24 31 38.10 43.116 355.487 Flare 355.487 3.480 75 0.870 20.880 402.298 2.610 62.640 2246.692 15637.13 7 176000 47.5 0.1662 10:00:00 278.00 278.00 API = 47.5 @ 60°F , Specific Gravity = 0.7817, H2S pull 0ppm.663 10:30:00 278.50 278.50 2295 5697 36 22.23 931 23 31 38.10 42.445 356.378 Flare 356.378 75 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Roid dume
2
Dale Time Cum Row
WWfnmfddhhmmasHrs Hrs
TubingOwing
Pres Pres
kPag kPag
Flow
Temp
Choke%abc Dg
Sas Pres Pres
mm kPag kPa
MIR Piste
TempGze
'0 mm
GasRats CumGas Gas
To
1tym'id
Itym'otal
Gas RdVd
Flared
Ityop
(ljm'SWm''Id
m'IGan
OilRale OIGum Wstw
Gain
WaterGumleadLTRPH SalinilyAPI Smd
Dd
ppm 'API
664 2015RVOT1100002790027900
1130002795027950
1200002800028000
123000 28050 28050
1871 5713
1949 5748
2020 5757
2023 5712
2223 931 23
iiii 896 22
2223 910 22
iiii 958 23
31 3810
31 JcI'1
3810
31 Jc
I'1
998 357257Flare
40583 358118Flan
41104 358969Flare
42359 359838Flan
35725T 3760
3MI118
358969 3560
359838
0902 21658 403200
0890 21360 404090
2858
2670
68582
64080
2249550
2252220
1%3427
1%3160
176XO
176XO
01
01
BTO
130000 28100 28100
133000 28150 28150
140000 28200 28200
2053 5725
1832 5749
1938 5743
2223 931 22
iiii 910 22
2223 931 23
31 3810
31 JcI'1
3810
41546 360712Flare
41104 361573Frss
41772 362436Flare
360712 3800
361573
362436 3680
0988 23712 405078
0920 22080 405998
2812
2760
67488
66240
2255032
2257792
1%2879
1%2603
176XO 01
176XO486 01
BTI 140000 28200 28200 aficGAPI=486@ 25pull060'FSpe ravily=07855H ppm
BT4
BT5
BT6
143000 28250 28250
150000 28300 28300
1530002835028350
160000 28400 28400
163000 28450 28450
170000 28500 28500
1983 5737
1723 5731
1869 5733
1944 5727
1907 5716
1851 5697
iiii 931 23
2223 910 22
iiii 896 22
2223 924 22
iiii 938 23
2223 938 23
31 JcI'1
3810
31 JcI'1
3810
30
31 3810
41772 363306Flan
41104 3641 70Flare
40131 365016Fran
41172 365863Flare
41995 366729Flan
42146 367606Flare
363306
364170 3540
365016
365863 3430
366729
367606 3770
0920 22090 406918
0858 20580 407776
0943 22620 408718
2620
2572
2827
62870
61740
67860
2260411
2262984
2265811
1%2341
1%2084
1%1801
176XO
176XO
176XO
01
01
01
BTB 1730002855028550
1800002860028600
1800002860028600
1779 5667
1937 5641
iiii 910 23
2223 938 23
31 JcI'1
3810
aficG 25pull0API=489@60'FSpe ravily=07842H ppm
41328 368475Fran
42371 369347Flare
368475
369347 3650 0949 22776 409667 2701 64824 2268512 1%1531 176XO489 01
183000 28650 28650
190000 28700 28700
1930002875028750
200000 28800 28800
203000 28850 28850
2100002890028900
1850 5680
1750 5665
1705 5652
1758 5688
1923 5636
1787 5635
iiii 931 23
2223 917 22
iiii 910 22
2223 910 22
910 23
2223 910 22
31 JcI'0
3810
30
30 3810
28
28 3810
42098 370227Fran
40964 371092Flare
40815 371944Flan
40815 372794Flare
41551 373652Flan
40871 374511Flare
37022T
371092 3260
371944
372794 3300
373652
374511 3800
0815 19560 410482
0825 19800 411307
0950 22800 412257
2445
2475
2850
58680
59400
68400
2270957
2273432
2276282
1%1286
1%1039
1%0754
176XO
176XO
176XO
01
01
01
2130002895028950
2200002900029000
1862 5631
1863 5590
910 22
2223 910 22
29
31 3810
40798 375362Fran
40652 376210Flare
375362
376210 3590 0897 21540 413155 2693 64620 2278975 1%0485 176XO491 01
2200002900029000 aficGravily=07836HAPI=491@ 25pull060'FSpe ppm
2230002905029050
230000 29100 29100
2330002915029150
8% 2015MVOB000000 29200 29200
1824 5600
1767 5624
1821 5618
1781 5622
iiii 910 22
2223 910 22
910 22
2223 910 22
32 JcI'2
3810
32 JcI'2
3810
40579 377056Flan
40579 377902Flare
40579 378747Fran
40579 379592Flare
3TI056
3TI902 3120
37874T
379592 3480
0780 18720 413935
0870 20880 414805
2340
2610
56160
62640
2281315
2283925
1%0251
1559990
176XO
176XO
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAweD2%8649OWSFlowTestlib98999
ProdnctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 29
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %664 2015/11/07 11:00:00 279.00 279.00 1871 5713 36 22.23 931 23 31 38.10 41.998 357.257 Flare 357.257 3.760 76 0.902 21.658 403.200 2.858 68.582 2249.550 15634.27 7 176000 0.1665 11:30:00 279.50 279.50 1949 5748 37 22.23 896 22 31 38.10 40.583 358.118 Flare 358.118 76 0.1666 12:00:00 280.00 280.00 2020 5757 37 22.23 910 22 31 38.10 41.104 358.969 Flare 358.969 3.560 75 0.890 21.360 404.090 2.670 64.080 2252.220 15631.60 7 176000 0.1667 12:30:00 280.50 280.50 2023 5712 37 22.23 958 23 31 38.10 42.359 359.838 Flare 359.838 75 0.1668 13:00:00 281.00 281.00 2053 5725 37 22.23 931 22 31 38.10 41.546 360.712 Flare 360.712 3.800 74 0.988 23.712 405.078 2.812 67.488 2255.032 15628.79 7 176000 0.1669 13:30:00 281.50 281.50 1832 5749 37 22.23 910 22 31 38.10 41.104 361.573 Flare 361.573 74 0.1670 14:00:00 282.00 282.00 1938 5743 37 22.23 931 23 31 38.10 41.772 362.436 Flare 362.436 3.680 75 0.920 22.080 405.998 2.760 66.240 2257.792 15626.03 7 176000 48.6 0.1671 14:00:00 282.00 282.00 API = 48.6 @ 60°F , Specific Gravity = 0.7855, H2S pull 0ppm.672 14:30:00 282.50 282.50 1983 5737 37 22.23 931 23 31 38.10 41.772 363.306 Flare 363.306 75 0.1673 15:00:00 283.00 283.00 1723 5731 37 22.23 910 22 31 38.10 41.104 364.170 Flare 364.170 3.540 74 0.920 22.090 406.918 2.620 62.870 2260.411 15623.41 7 176000 0.1674 15:30:00 283.50 283.50 1869 5733 37 22.23 896 22 31 38.10 40.131 365.016 Flare 365.016 74 0.1675 16:00:00 284.00 284.00 1944 5727 37 22.23 924 22 31 38.10 41.172 365.863 Flare 365.863 3.430 75 0.858 20.580 407.776 2.572 61.740 2262.984 15620.84 7 176000 0.1676 16:30:00 284.50 284.50 1907 5716 36 22.23 938 23 30 38.10 41.995 366.729 Flare 366.729 75 0.1677 17:00:00 285.00 285.00 1851 5697 36 22.23 938 23 31 38.10 42.146 367.606 Flare 367.606 3.770 75 0.943 22.620 408.718 2.827 67.860 2265.811 15618.01 7 176000 0.1678 17:30:00 285.50 285.50 1779 5667 36 22.23 910 23 31 38.10 41.328 368.475 Flare 368.475 75 0.1679 18:00:00 286.00 286.00 1937 5641 36 22.23 938 23 31 38.10 42.371 369.347 Flare 369.347 3.650 74 0.949 22.776 409.667 2.701 64.824 2268.512 15615.31 7 176000 48.9 0.1680 18:00:00 286.00 286.00 API = 48.9 @ 60°F , Specific Gravity = 0.7842, H2S pull 0ppm.681 18:30:00 286.50 286.50 1850 5680 36 22.23 931 23 31 38.10 42.098 370.227 Flare 370.227 74 0.1682 19:00:00 287.00 287.00 1750 5665 36 22.23 917 22 30 38.10 40.964 371.092 Flare 371.092 3.260 75 0.815 19.560 410.482 2.445 58.680 2270.957 15612.86 7 176000 0.1683 19:30:00 287.50 287.50 1705 5652 36 22.23 910 22 30 38.10 40.815 371.944 Flare 371.944 75 0.1684 20:00:00 288.00 288.00 1758 5688 36 22.23 910 22 30 38.10 40.815 372.794 Flare 372.794 3.300 75 0.825 19.800 411.307 2.475 59.400 2273.432 15610.39 7 176000 0.1685 20:30:00 288.50 288.50 1923 5636 34 22.23 910 23 28 38.10 41.551 373.652 Flare 373.652 75 0.1686 21:00:00 289.00 289.00 1787 5635 34 22.23 910 22 28 38.10 40.871 374.511 Flare 374.511 3.800 75 0.950 22.800 412.257 2.850 68.400 2276.282 15607.54 7 176000 0.1687 21:30:00 289.50 289.50 1862 5631 34 22.23 910 22 29 38.10 40.798 375.362 Flare 375.362 75 0.1688 22:00:00 290.00 290.00 1863 5590 36 22.23 910 22 31 38.10 40.652 376.210 Flare 376.210 3.590 75 0.897 21.540 413.155 2.693 64.620 2278.975 15604.85 7 176000 49.1 0.1689 22:00:00 290.00 290.00 API = 49.1 @ 60°F , Specific Gravity = 0.7836, H2S pull 0ppm.690 22:30:00 290.50 290.50 1824 5600 36 22.23 910 22 32 38.10 40.579 377.056 Flare 377.056 75 0.1691 23:00:00 291.00 291.00 1767 5624 34 22.23 910 22 32 38.10 40.579 377.902 Flare 377.902 3.120 75 0.780 18.720 413.935 2.340 56.160 2281.315 15602.51 7 176000 0.1692 23:30:00 291.50 291.50 1821 5618 34 22.23 910 22 32 38.10 40.579 378.747 Flare 378.747 75 0.1693 2015/11/08 00:00:00 292.00 292.00 1781 5622 34 22.23 910 22 32 38.10 40.579 379.592 Flare 379.592 3.480 75 0.870 20.880 414.805 2.610 62.640 2283.925 15599.90 7 176000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well GnficeDryRowMalar Rnid dume
2
Dale Time Cum Row TubingCmingFlow
Pres Pres Temp
Qeks
$ns
Bshe Dg MIR Piste
Pres Pres TempGze
GasRats CumGas Gas
To
TotalGas RdVd
Flared
BSW06Fmn OilRale 01Cum Water
Gain
WahnWaterCumloarlLTR
IMH
PH SalinilyAPI Smd
CM
WWlamlddhhmmss
694 2015HV0$00000029200
Hrs kPag kPag '0
292000000hrsreadmg
mm kPag kPa '0 mm Ityapid I'm' tyap (I)m''Idm'APIFlowingTubmgpressure=1781kPa
ShutmCasingpressure=5622kPa
Flowingtemperature=34'0
Chokesize=56I64f2223mmi
GasRate=429910'm'otaHluid
rate=348 m'Ihr
Waterrecoveryrate=261m'Ihr
Condensaterate=087m'Ihr
PH=7,Salinity=176XOppmBSSW=75S
API=491@60'F,Separator=910kPagH'8=0 ppmSand=01'I
Dailyhrsgowed=24hrs
Cumhrsflowed=292hrs
Dailygasproduced10flarelast24hrs=41661tPm'um
gasProducedtoflare=37959210VP
CondProducedlast24hrs= 2177m'um
CondProduced=41480m'ater
Recoveredlast24Hrs=6401
m'otal
WaterRecovered=228392
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLetttoRecover= 1559990
m'ercentageRecoveredfromInmalLoad=1277 H
Chokeswashedin24bourn=g
Totalchokeswashed=0
003000
010000
013000
020000
29250
29300
29350
29400
29250 1892
29300 1937
29350 1821
29400 1955
5606 34 iiii5599 34 2223
5604 34 iiii
5597 34 2223
910
910
910
910
22 32 XI: 40672
22 32 3810 40672
22 28 XI: 40965
22 28 3810 40965
380439
381286
382136
382990
Ftze
Flare
Ftze
Flare
380439
381286 3 170 75 0793 19020
382136
382990 3280 75 0820 19680
415597
416417
2377 57060
2460 59040
2286302
2288762
1559752 7
1559506 7
176XO
176XO
01
495 01
020000 29400 29400 60'FSpeoficGravityAPI=495@ 2$pullgppm0 7818H
701
707
023000
030000
033000
040000
043000
050000
053000
060000
29450
29500
29550
29600
29650
29700
29750
29800
29450 1981
29500 1926
29550 1995
29600 1746
29650 1741
29700 1885
29750 1790
29800 1852
5585 35 iiii
5573 35 2223
5571 34 iiii
5576 34 2223
5567 34 iiii
5502 34 2223
5560 34 iiii
5565 34 2223
910
910
910
910
910
910
910
910
22 28 XI: 40965
22 31 3810 40744
22 31 XI: 40744
22 32 3810 40672
22 32 XI: 40672
22 32 3810 40672
21 32 XI: 40122
21 32 3810 40122
383843
384694
385543
3X391
387239
3MISi
388928
389764
Ftze
Flare
Ftze
Flare
Ftze
Flare
Ftze
Flare
383843
384694 3390 75 0848 20340
385543
386391 3 170 75 0793 19020
387239
388086 3230 75 0808 19380
388928
389764 3240 75 0810 19440
417265
418057
418865
419675
2543 61020
2377 57060
2422 58140
2430 58320
2291305
2293682
2296105
2298535
1559252 7
1559014 7
1558772 7
1558529 7
176XO
176XO
176XO
176XO
01
01
01
497 01
710
060000
063000
070000
29800
29850
29900
29800 2$pullgppmAPI=497@
29850 1950
29900 1736
60'FSpeoficGravity=
5567 34 iiii
5555 36 2223
07811H
924
896
21 32 XI: 40410
21 33 3810 39304
390602
391433
Ftze
Flare
390602
391433 3480 75 0870 20880 420545 2610 62640 23011451558267 7 176XO 01
711
712
713
714
715
716
073000
080000
083000
090000
093000
100000
29950
30000
30050
30100
30150
30200
29950 2058
30000 1723
30050 1765
30100 1837
30150 1609
30200 1784
5548 36 iiii5517 36 2223
5520 36 iiii
5524 36 2223
5535 37 iiii
5523 36 2223
938
931
931
910
910
951
22 33 XI: 41316
21 33 3810 40481
21 33 XI: 40481
21 33 3810 39590
21 33 XI: 39821
22 33 3810 41834
392273
393125
393968
394802
395629
396480
Ftze
Flare
Ftze
Flare
Ftze
Flare
392273
393125 3260 76 0782 18778
393968
394802 3200 76 0768 18432
395629
396480 3520 74 0915 21965
421327
422095
423011
2478 59462
2432 58368
2605 62515
2303623
2306055
2308659
1558020 7
1557777 7
1557516 7
176XO
176XO
176XO
01
01
01
717
718
100000
103000
30200
30250
30200FPI=485@60'FSpeoficGravily=07861H2$pullgppm
30250 1855 5530 36 iiii 931 22 33 XI: 41 171 397344Flee 397344
PetroClassFlowTestVersion4.5.0.5
0:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTIHG,.IAweD24864IOWSFlowTestldbggs80
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 30
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %694 2015/11/08 00:00:00 292.00 292.00 00:00 hrs reading
Flowing Tubing pressure =1781 kPaShut in Casing pressure =5622 kPaFlowing temperature =34 °CChoke size = 56/64 (22.23mm)Gas Rate =42.99 10³m³Total fluid rate =3.48 m³/hrWater recovery rate =2.61 m³/hrCondensate rate = 0.87 m³/hrPH =7 , Salinity = 176000 ppm, BS&W = 75 %API =49.1 @ 60°F, Separator =910 kPag H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 292 hrsDaily gas produced t0 flare last 24 hrs = 41.66 10³m³Cum gas Produced to flare= 379.592 10³m³Cond Produced last 24 hrs = 21.77 m³Cum Cond Produced = 414.80 m³Water Recovered Last 24 Hrs = 64.01 m³Total Water Recovered = 2283.92 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15599.90 m³ Percentage Recovered from Initial Load = 12.77 %Chokes washed in 24 hours=0Total chokes washed =0
695 00:30:00 292.50 292.50 1892 5606 34 22.23 910 22 32 38.10 40.672 380.439 Flare 380.439 75 0.1696 01:00:00 293.00 293.00 1937 5599 34 22.23 910 22 32 38.10 40.672 381.286 Flare 381.286 3.170 75 0.793 19.020 415.597 2.377 57.060 2286.302 15597.52 7 176000 0.1697 01:30:00 293.50 293.50 1821 5604 34 22.23 910 22 28 38.10 40.965 382.136 Flare 382.136 75 0.1698 02:00:00 294.00 294.00 1955 5597 34 22.23 910 22 28 38.10 40.965 382.990 Flare 382.990 3.280 75 0.820 19.680 416.417 2.460 59.040 2288.762 15595.06 7 176000 49.5 0.1699 02:00:00 294.00 294.00 API = 49.5 @ 60°F , Specific Gravity = 0.7818, H2S pull 0ppm.700 02:30:00 294.50 294.50 1981 5585 35 22.23 910 22 28 38.10 40.965 383.843 Flare 383.843 75 0.1701 03:00:00 295.00 295.00 1926 5573 35 22.23 910 22 31 38.10 40.744 384.694 Flare 384.694 3.390 75 0.848 20.340 417.265 2.543 61.020 2291.305 15592.52 7 176000 0.1702 03:30:00 295.50 295.50 1995 5571 34 22.23 910 22 31 38.10 40.744 385.543 Flare 385.543 75 0.1703 04:00:00 296.00 296.00 1746 5576 34 22.23 910 22 32 38.10 40.672 386.391 Flare 386.391 3.170 75 0.793 19.020 418.057 2.377 57.060 2293.682 15590.14 7 176000 0.1704 04:30:00 296.50 296.50 1741 5567 34 22.23 910 22 32 38.10 40.672 387.239 Flare 387.239 75 0.1705 05:00:00 297.00 297.00 1885 5502 34 22.23 910 22 32 38.10 40.672 388.086 Flare 388.086 3.230 75 0.808 19.380 418.865 2.422 58.140 2296.105 15587.72 7 176000 0.1706 05:30:00 297.50 297.50 1790 5560 34 22.23 910 21 32 38.10 40.122 388.928 Flare 388.928 75 0.1707 06:00:00 298.00 298.00 1852 5565 34 22.23 910 21 32 38.10 40.122 389.764 Flare 389.764 3.240 75 0.810 19.440 419.675 2.430 58.320 2298.535 15585.29 7 176000 49.7 0.1708 06:00:00 298.00 298.00 API = 49.7 @ 60°F , Specific Gravity = 0.7811, H2S pull 0ppm.709 06:30:00 298.50 298.50 1950 5567 34 22.23 924 21 32 38.10 40.410 390.602 Flare 390.602 75 0.1710 07:00:00 299.00 299.00 1736 5555 36 22.23 896 21 33 38.10 39.304 391.433 Flare 391.433 3.480 75 0.870 20.880 420.545 2.610 62.640 2301.145 15582.67 7 176000 0.1711 07:30:00 299.50 299.50 2058 5548 36 22.23 938 22 33 38.10 41.316 392.273 Flare 392.273 75 0.1712 08:00:00 300.00 300.00 1723 5517 36 22.23 931 21 33 38.10 40.481 393.125 Flare 393.125 3.260 76 0.782 18.778 421.327 2.478 59.462 2303.623 15580.20 7 176000 0.1713 08:30:00 300.50 300.50 1765 5520 36 22.23 931 21 33 38.10 40.481 393.968 Flare 393.968 76 0.1714 09:00:00 301.00 301.00 1837 5524 36 22.23 910 21 33 38.10 39.590 394.802 Flare 394.802 3.200 76 0.768 18.432 422.095 2.432 58.368 2306.055 15577.77 7 176000 0.1715 09:30:00 301.50 301.50 1609 5535 37 22.23 910 21 33 38.10 39.821 395.629 Flare 395.629 76 0.1716 10:00:00 302.00 302.00 1784 5523 36 22.23 951 22 33 38.10 41.834 396.480 Flare 396.480 3.520 74 0.915 21.965 423.011 2.605 62.515 2308.659 15575.16 7 176000 0.1717 10:00:00 302.00 302.00 API = 48.5 @ 60°F , Specific Gravity = 0.7861, H2S pull 0ppm.718 10:30:00 302.50 302.50 1855 5530 36 22.23 931 22 33 38.10 41.171 397.344 Flare 397.344 74 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Dale Time Cum Row Tubing
Pres
CmingFlow
Pres Temp
Qmks
$as
Gabe Dg MIR
Pres Pres Temp
GasRats CumGas Gas TolalGasRdVdBSWOIGan
To Flared
OilRale OICumWater WaterWaterCumloadLTRPH Salinily
Gain Rate
API
WWlnmlddbbmmss
2015HVOB110000719 30300 30300
kPag
IW3
kPag '0
5541 37
mm
2223
kPag kPa '0
938 22 33
ttynyid I'm'm
41316 3982043810
ttpop (I)m'
m'lare
398204 3460 'I 0900
m'Id
21590
m'23
910 2560 61450 2311 220 1557260 I I76XO
'API
01
721
724
113000
120000
123000
130000
133000
140000
3035tl
30400
30450
30500
30550
30600
30350
30400
30450
30500
30550
30600
1935
1846
1906
1663
1975
1869
5549 37
5548 36
5508 36
5505 37
5495 36
5470 36
2223
2223
2223
931 22 33
951 22 33
910 21 32
931 21 32
938 22 32
910 21 33
Jc I
'810
Jc I
'810
Jc I
'810
40712 399058
41373 399913
39660 400757
40553 401593
40928 402442
40051 403285
Flss 399058
Flare 399913 3240 76 0778
Flan 4X75T
Flare 401593 3410 72 0955
Ftss 402442
Flare 403285 3280 74 0853
18662
22915
20467
424688 2462 59098 2313682 1557014 I I76XO
425643 2455 5892523161371556768I 176XO
426495 2427 58253 2318565 1556526 I I76XO485
01
01
01
140000 30600 30600 aficG60'FSpe1=485@ ravily0 t861H2$pullgppm
731
143000
150000
153000
160000
163000
170000
30650
30700
3075tl
30800
30850
30900
30650
30T00
30T50
30800
30850
30900
1820
1686
1789
1989
1919
IMI
5441 37
5408 37
5429 36
5446 36
5474 36
5137 36
2223
2223
2223
931 21 32
938 22 32
931 21 33
951 22 32
931 21 32
951 22 32
Jc I
'810
Jc I
'810
Jc I
'810
40553 404125
40928 404974
40481 405822
41447 406675
40553 407529
41909 408388
F la s 404125
Flare 404974 3670 75 0917
Ftss 405822
Flare 406675 3280 73 0886
Ftss 407529
Flare 408388 3280 75 0820
22020
21254
19680
427413 2752 66060 2321317 1556250 I I76XO
428298 2394 57466 2323711 1556011 I I76XO
429118 2460 59040 23261 71 1555765 I I76XO
01
01
01
173000
180000
180000
183000
30950
31000
31000
31050
30950
31000
31000
31050
1617
1793
1=491@
1735
Bttt 36
5459 36
60'FSpeaficG
5405 36
2223
ravily
931 22 32
938 22 32
0 t836H2$pullgppm
924 22 32
Jc I
'810
Jc I
'0785 409250
41160 410103
40641 410955
Flss 409250
Flare 410103 3320 72 0930
Ftss 410955
22310 430048 2390 57370 2328562 1555526 I I76XO491 01
737
741
190000
193000
200000
203000
210000
31100
31150
31200
31250
31300
31100
31150
31200
31250
31300
1835
1889
1881
1840
1741
5370 36
5370 36
5361 36
5362 35
53fil 35
2223
2223
2223
931 22 31
931 22 28
917 22 28
931 22 30
924 22 30
3810
Jc I
'810
Jc I
'810
41088 411 807
41311 412665
41018 413522
41162 414379
41017 415235
Flare 411807 3340 74 0868
Ftss 412665
Flare 413522 3410 73 0921
Ftss 414379
Flare 415235 3380 73 0913
20842
22097
21902
430916 2472 59318 2331033 1555279 I ITBXO
431837 2489 59743 2333523 1555030 I 178XO
432750 2467 59218 2335990 1554783 I IBOXO
01
01
01
742 213000
220000
220000
223000
31350
31400
31400
31450
31350
31400
31400
31450
1946
1785
1=492@
1877
5351 35
5345 35
60'FSpeaficG
5330 35
2223
ravily
924 22 29
924 22 30
0 t832H2$pullgppm
931 22 29
Jc I
'810
Jc I
'1091 416090
41017 416945
41236 417802
Ftss 416090
Flare 416945 3 130 74 0814
Ftss 417802
19531 433564 2316 55589 2338306 1554551 I IBOXO492 01
747
230000
233000
2015MV09000000
31500
31550
31600
31500
31550
31600
1704
1760
1810
5320 35
5317 35
5316 35
2223
2223
931 22 29
931 22 28
931 22 28
3810
Jc I
'810
41236 418661
41311 419521
41311 420382
Flare 418661 3260 74 0848
Ftss 419521
Flare 420382 3270 73 0883
20342
21190
434411 2412 5789823407191554310I IBOXO
435294 2387 57290 2343106 1554071 I ITBXO
01
01
PetroClassFlowTestVersion4.5.0.5
C:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD24864DOWBFlowTestllbggsBS
ProdnctiontestingAScblumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 31
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %719 2015/11/08 11:00:00 303.00 303.00 1943 5541 37 22.23 938 22 33 38.10 41.316 398.204 Flare 398.204 3.460 74 0.900 21.590 423.910 2.560 61.450 2311.220 15572.60 7 176000 0.1720 11:30:00 303.50 303.50 1935 5549 37 22.23 931 22 33 38.10 40.712 399.058 Flare 399.058 74 0.1721 12:00:00 304.00 304.00 1846 5548 36 22.23 951 22 33 38.10 41.373 399.913 Flare 399.913 3.240 76 0.778 18.662 424.688 2.462 59.098 2313.682 15570.14 7 176000 0.1722 12:30:00 304.50 304.50 1906 5508 36 22.23 910 21 32 38.10 39.660 400.757 Flare 400.757 76 0.1723 13:00:00 305.00 305.00 1663 5505 37 22.23 931 21 32 38.10 40.553 401.593 Flare 401.593 3.410 72 0.955 22.915 425.643 2.455 58.925 2316.137 15567.68 7 176000 0.1724 13:30:00 305.50 305.50 1975 5495 36 22.23 938 22 32 38.10 40.928 402.442 Flare 402.442 72 0.1725 14:00:00 306.00 306.00 1869 5470 36 22.23 910 21 33 38.10 40.051 403.285 Flare 403.285 3.280 74 0.853 20.467 426.495 2.427 58.253 2318.565 15565.26 7 176000 48.5 0.1726 14:00:00 306.00 306.00 API = 48.5 @ 60°F , Specific Gravity = 0.7861, H2S pull 0ppm.727 14:30:00 306.50 306.50 1820 5441 37 22.23 931 21 32 38.10 40.553 404.125 Flare 404.125 74 0.1728 15:00:00 307.00 307.00 1686 5408 37 22.23 938 22 32 38.10 40.928 404.974 Flare 404.974 3.670 75 0.917 22.020 427.413 2.752 66.060 2321.317 15562.50 7 176000 0.1729 15:30:00 307.50 307.50 1789 5429 36 22.23 931 21 33 38.10 40.481 405.822 Flare 405.822 75 0.1730 16:00:00 308.00 308.00 1989 5446 36 22.23 951 22 32 38.10 41.447 406.675 Flare 406.675 3.280 73 0.886 21.254 428.298 2.394 57.466 2323.711 15560.11 7 176000 0.1731 16:30:00 308.50 308.50 1919 5474 36 22.23 931 21 32 38.10 40.553 407.529 Flare 407.529 73 0.1732 17:00:00 309.00 309.00 1841 5437 36 22.23 951 22 32 38.10 41.909 408.388 Flare 408.388 3.280 75 0.820 19.680 429.118 2.460 59.040 2326.171 15557.65 7 176000 0.1733 17:30:00 309.50 309.50 1617 5411 36 22.23 931 22 32 38.10 40.785 409.250 Flare 409.250 75 0.1734 18:00:00 310.00 310.00 1793 5459 36 22.23 938 22 32 38.10 41.160 410.103 Flare 410.103 3.320 72 0.930 22.310 430.048 2.390 57.370 2328.562 15555.26 7 176000 49.1 0.1735 18:00:00 310.00 310.00 API = 49.1 @ 60°F , Specific Gravity = 0.7836, H2S pull 0ppm.736 18:30:00 310.50 310.50 1735 5405 36 22.23 924 22 32 38.10 40.641 410.955 Flare 410.955 72 0.1737 19:00:00 311.00 311.00 1835 5370 36 22.23 931 22 31 38.10 41.088 411.807 Flare 411.807 3.340 74 0.868 20.842 430.916 2.472 59.318 2331.033 15552.79 7 178000 0.1738 19:30:00 311.50 311.50 1889 5370 36 22.23 931 22 28 38.10 41.311 412.665 Flare 412.665 74 0.1739 20:00:00 312.00 312.00 1881 5361 36 22.23 917 22 28 38.10 41.018 413.522 Flare 413.522 3.410 73 0.921 22.097 431.837 2.489 59.743 2333.523 15550.30 7 178000 0.1740 20:30:00 312.50 312.50 1840 5362 35 22.23 931 22 30 38.10 41.162 414.379 Flare 414.379 73 0.1741 21:00:00 313.00 313.00 1741 5361 35 22.23 924 22 30 38.10 41.017 415.235 Flare 415.235 3.380 73 0.913 21.902 432.750 2.467 59.218 2335.990 15547.83 7 180000 0.1742 21:30:00 313.50 313.50 1946 5351 35 22.23 924 22 29 38.10 41.091 416.090 Flare 416.090 73 0.1743 22:00:00 314.00 314.00 1785 5345 35 22.23 924 22 30 38.10 41.017 416.945 Flare 416.945 3.130 74 0.814 19.531 433.564 2.316 55.589 2338.306 15545.51 7 180000 49.2 0.1744 22:00:00 314.00 314.00 API = 49.2 @ 60°F , Specific Gravity = 0.7832, H2S pull 0ppm.745 22:30:00 314.50 314.50 1877 5330 35 22.23 931 22 29 38.10 41.236 417.802 Flare 417.802 74 0.1746 23:00:00 315.00 315.00 1704 5320 35 22.23 931 22 29 38.10 41.236 418.661 Flare 418.661 3.260 74 0.848 20.342 434.411 2.412 57.898 2340.719 15543.10 7 180000 0.1747 23:30:00 315.50 315.50 1760 5317 35 22.23 931 22 28 38.10 41.311 419.521 Flare 419.521 74 0.1748 2015/11/09 00:00:00 316.00 316.00 1810 5316 35 22.23 931 22 28 38.10 41.311 420.382 Flare 420.382 3.270 73 0.883 21.190 435.294 2.387 57.290 2343.106 15540.71 7 178000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMelar Rnid dume
2
Dale Time Cum Row Tubing
Pres
OwingFlow
Pres Temp
ChokeBabe Dg
Sae Pres Pres
MIR
Temp
CumGas Gas
To
TotalGas
Flared
RdydBSWDilGanOrtgndOlCum Water
Gain
WahnWaterCumloarlLTRPH
IMM
SalinilyAPI Smd
Cd
WWlamlddhhmmss
749 2015HII0900000031600
kPag '0kPag
316000000hrsreadmg
mm IPag kpe mm 1tym'id (llm' m''Idm'APIFlowingTubmgpressure= 1810kPa
ShutmCasingpressure= 5316kPa
Flowingtemperature=35'0
Chokesize=56I64f2223mml
GasRate=4375Ighip
Totalguidrate=327m'Ihr
Waterrecoveryrate=239m'Ihr
Condensaterate= 0 88m'Ihr
PH=T,Salinity=178XOppmBSSW=73'I
API=492@60'F,Separator=931kPagH'S=0 ppmSand=01%
Dailyhrsgowed=24hrs
Cumhrsflowed=316hrs
Dailygasproduced10flarelast24hrs=40791tPm'um
gasProducedtoflare=420382105ip
CondProducedlast24hrs= 2049m'um
CondProduced=43529m'ater
Recoveredlast24Hrs=5918
m'otal
WaterRecovered=
234311m'nnalLoad
FluidtoRecover=1788382m'oad
FluidLefttoRecover= 1554071
m'ercentageRecoveredfromInnalLoad=1310'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
751
003000
010000
013000
020000
31650
31700
31750
31800
31650 17X
31700 1909
31750 IM3
31800 1928
5331 35 iiii5335 35 2223
5340 35 iiii
5326 35 2223
931
931
931
931
22 29
22 29 3810
22 29
22 30 3810
41005 421239
41005 422093
41005 422948
41162 423803
Fize
Flare
Fize
Flare
421239
422093 3340
422948
423803 3640
73 0902
75 0910
21643
21840
436196
437106
2438 58517 2345544
2730 65520 2348274
1553828 7
1553555 7
180XO
ISOXO
01
498 01
020000 31800 31800 60'FSpeaficGravityAPI=498@ 0 7803H26pullgppm
757
761
762
023000
030000
033000
040000
043000
050000
053000
060000
31850
31900
31950
32000
32050
32100
32150
32200
31850 1735
31900 1912
31950 1652
32000 1780
32050 1781
32100 1732
32150 1763
32200 1704
5295 35 iiii
5294 35 2223
5307 35 iiii
5297 35 2223
5304 34 iiii
5286 35 2223
5294 35 iiii
5288 35 2223
931
931
931
931
931
931
931
931
21 30
21 29 3810
21 29
21 29 3810
21 28
21 29 3810
21 29
21 29 3810
40699 424656
40772 425505
40776 426354
40776 427204
40846 428054
40772 428904
40772 429754
40772 430603
Fize
Flare
Fize
Flare
Fize
Flare
Fize
Flare
424656
425505 3320
426354
427204 3270
428054
428904 3200
429754
4X603 3260
74 0863
75 0817
75 0800
74 0848
20717
19620
19200
20342
437969
438787
439587
440434
2457 58963 2350731
2453 58860 2353183
2400 57600 2355583
2412 57898 2357996
1553309 7
1553064 7
15528247
1552582 7
ISOXO
ISOXO
IIMXO
ISOXO
01
01
01
498 01
060000
063000
070000
32200
32250
32300
API=498@32200
32250 1846
32300 1915
60'FSpeaficGravity=
5234 34 iiii
5290 35 2223
0 7803H
931
931
26pullgppm
21 28
22 28 3810
40471 431449
41410 432302
Fize
Flare
431449
432302 3330 75 0833 19980 441267 2498 59940 2360493 1552333 7 ISOXO 01
767
7TO
7TI
073000
080000
083000
090000
093000
100000
32350
32400
32450
32500
32550
32600
32350 1812
32400 1769
32450 1746
32500 1795
32550 1668
32600 1712
5265 35 iiii5271 35 2223
5261 36 iiii
5255 36 2223
5255 36 iiii
5238 36 2223
910
931
931
931
910
931
21 28
21 28 3810
21 28
22 28 3810
21 28
22 28 3810
40034 4331 51
40471 433989
40471 434832
41410 435685
40034 436534
41410 437382
Fize
Flare
Fize
Flare
Fize
Flare
433151
433989 3670
434832
435685 3360
436534
437382 2990
75 0917
76 0806
72 0837
22020
19354
20093
442184
442991
443828
2752 66060 2363246
2554 61286 2365799
2 153 51667 2367952
1552057 7
15518027
15515877
IIMXO
181XO
181XO
01
01
504 01
100000
103000
32600
32650
32600881=504@60'FSpeaficGravily=07780H26pullgppm
32650 1683 5229 36 iiii 931 22 28 XI: 41410 438245Flze 438245
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIMG,.IAweD24864IOWSFlowTestlibgga82
ProdnctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 32
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %749 2015/11/09 00:00:00 316.00 316.00 00:00 hrs reading
Flowing Tubing pressure = 1810 kPaShut in Casing pressure = 5316 kPaFlowing temperature = 35°CChoke size = 56/64 (22.23mm)Gas Rate = 43.75 10³m³Total fluid rate = 3.27 m³/hrWater recovery rate = 2.39 m³/hrCondensate rate = 0.88 m³/hrPH =7 , Salinity = 178000 ppm, BS&W = 73%API = 49.2 @ 60°F, Separator = 931 kPag H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 316 hrsDaily gas produced t0 flare last 24 hrs = 40.79 10³m³Cum gas Produced to flare= 420.382 10³m³Cond Produced last 24 hrs = 20.49 m³Cum Cond Produced = 435.29 m³Water Recovered Last 24 Hrs = 59.18 m³Total Water Recovered = 2343.11 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15540.71 m³ Percentage Recovered from Initial Load = 13.10%Chokes washed in 24 hours=0Total chokes washed =0
750 00:30:00 316.50 316.50 1796 5331 35 22.23 931 22 29 38.10 41.005 421.239 Flare 421.239 73 0.1751 01:00:00 317.00 317.00 1909 5335 35 22.23 931 22 29 38.10 41.005 422.093 Flare 422.093 3.340 73 0.902 21.643 436.196 2.438 58.517 2345.544 15538.28 7 180000 0.1752 01:30:00 317.50 317.50 1843 5340 35 22.23 931 22 29 38.10 41.005 422.948 Flare 422.948 73 0.1753 02:00:00 318.00 318.00 1928 5326 35 22.23 931 22 30 38.10 41.162 423.803 Flare 423.803 3.640 75 0.910 21.840 437.106 2.730 65.520 2348.274 15535.55 7 180000 49.8 0.1754 02:00:00 318.00 318.00 API = 49.8 @ 60°F , Specific Gravity = 0.7803, H2S pull 0ppm.755 02:30:00 318.50 318.50 1735 5295 35 22.23 931 21 30 38.10 40.699 424.656 Flare 424.656 75 0.1756 03:00:00 319.00 319.00 1912 5294 35 22.23 931 21 29 38.10 40.772 425.505 Flare 425.505 3.320 74 0.863 20.717 437.969 2.457 58.963 2350.731 15533.09 7 180000 0.1757 03:30:00 319.50 319.50 1652 5307 35 22.23 931 21 29 38.10 40.776 426.354 Flare 426.354 74 0.1758 04:00:00 320.00 320.00 1780 5297 35 22.23 931 21 29 38.10 40.776 427.204 Flare 427.204 3.270 75 0.817 19.620 438.787 2.453 58.860 2353.183 15530.64 7 180000 0.1759 04:30:00 320.50 320.50 1781 5304 34 22.23 931 21 28 38.10 40.846 428.054 Flare 428.054 75 0.1760 05:00:00 321.00 321.00 1732 5286 35 22.23 931 21 29 38.10 40.772 428.904 Flare 428.904 3.200 75 0.800 19.200 439.587 2.400 57.600 2355.583 15528.24 7 180000 0.1761 05:30:00 321.50 321.50 1763 5294 35 22.23 931 21 29 38.10 40.772 429.754 Flare 429.754 75 0.1762 06:00:00 322.00 322.00 1704 5288 35 22.23 931 21 29 38.10 40.772 430.603 Flare 430.603 3.260 74 0.848 20.342 440.434 2.412 57.898 2357.996 15525.82 7 180000 49.8 0.1763 06:00:00 322.00 322.00 API = 49.8 @ 60°F , Specific Gravity = 0.7803, H2S pull 0ppm.764 06:30:00 322.50 322.50 1846 5234 34 22.23 931 21 28 38.10 40.471 431.449 Flare 431.449 74 0.1765 07:00:00 323.00 323.00 1915 5290 35 22.23 931 22 28 38.10 41.410 432.302 Flare 432.302 3.330 75 0.833 19.980 441.267 2.498 59.940 2360.493 15523.33 7 180000 0.1766 07:30:00 323.50 323.50 1812 5265 35 22.23 910 21 28 38.10 40.034 433.151 Flare 433.151 75 0.1767 08:00:00 324.00 324.00 1769 5271 35 22.23 931 21 28 38.10 40.471 433.989 Flare 433.989 3.670 75 0.917 22.020 442.184 2.752 66.060 2363.246 15520.57 7 180000 0.1768 08:30:00 324.50 324.50 1746 5261 36 22.23 931 21 28 38.10 40.471 434.832 Flare 434.832 75 0.1769 09:00:00 325.00 325.00 1795 5255 36 22.23 931 22 28 38.10 41.410 435.685 Flare 435.685 3.360 76 0.806 19.354 442.991 2.554 61.286 2365.799 15518.02 7 181000 0.1770 09:30:00 325.50 325.50 1668 5255 36 22.23 910 21 28 38.10 40.034 436.534 Flare 436.534 76 0.1771 10:00:00 326.00 326.00 1712 5238 36 22.23 931 22 28 38.10 41.410 437.382 Flare 437.382 2.990 72 0.837 20.093 443.828 2.153 51.667 2367.952 15515.87 7 181000 50.4 0.1772 10:00:00 326.00 326.00 API = 50.4 @ 60°F , Specific Gravity = 0.7780, H2S pull 0ppm.773 10:30:00 326.50 326.50 1683 5229 36 22.23 931 22 28 38.10 41.410 438.245 Flare 438.245 72 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
TubingCmingFlow
Pres Pres Temp
Qmks
$as
OnficeDryRowMalar
Gabe Dg MIR
Pres Pres Temp
CumGas
DataSummary
Gas TolalGasRdVd
To Flared
BSWWIGanOilRale 00Cum
Rnid
Wstw WsHr
Gain Rate
WaterGumleadLTRPH SalinilyAPI
dume
2
7T4
7T5
776
778
WWlmnldd
2015H909
lbmmes
110000
113000
120000
123000
130000
133000
140000
32700
32750
32000
32050
32900
32950
33000
32T00
32T50
32800
32850
32900
32950
33000
kPag kPag '0
1720 5227 36
1549 5235 35
1773 5243 36
1983 5213 36
1618 5236 36
1645 5236 36
1703 5247 36
mm
2223
2223
2223
2223
kPag kPa '0
931 21 20
951 22 20
931 22 20
931 22 20
951 22 20
931 22 20
931 22 20
mm 1tym'id
3010 40471
41832
3010 41410
41079
3010 41747
41079
3010 41079
439098
439955
440022
441681
442544
443407
444263
Itpop(ljm'lare
439098 3250
Ftse 439955
Flare 440022 3510
Flse 441681
Flare 4425M 3710
Flse 44340T
Flare 444263 3810
m''Id73 0078 21060
75 0078 21060
74 0965 23150
75 0952 22860
m'44
705
445583
446547
447500
2373 56940
2633 63180
2745 65890
2857 60500
2370325
2372957
2375703
2378560
1551350
1551086
1550812
1550526
ppm 'API
181XO
181XO
181XO
181XO505
01
01
01
01
781 140000
143000
33000
33050
33000
33050
aficG1=505@60'FSpe ravily
1656 5241 35
0 7774H2$pull0ppm
931 21 20 40846 445116Flse 445116
787
150000
153000
160000
163000
170000
173000
33100
33150
33200
33250
33300
33350
33100
33150
33200
33250
33300
33350
1673 5235 35
1744 5227 36
1925 5193 35
1682 5185 35
1872 5185 35
1667 5182 35
2223
2223
2223
931 21 20
951 22 20
951 22 20
931 21 20
917 21 20
931 21 27
3010 40846
41747
3010 41747
40611
3010 40556
40920
445967
446027
447697
MB555
449400
450249
Flare 445967 3640
Flse 44602T
Flare 447697 3750
Flse 440555
Flare 449400 3740
Flan 450249
75 0910 21840
72 I 050 25200
72 I 047 25133
440410
449460
450507
2730 65520
2700 64800
2693 64627
2381290
2383990
2386683
1550253
1549983
1549714
181XO
181XO
182XO
01
01
01
791
100000
100000
103000
33400
33400
33450
33400
33400
33450
22231727 5175
1=499@60'FSpe
1743 5153
aficGravily
931 22 27
0 7799H2$pull0ppm
931 21 27
3010 41154
40920
451104
451959
Flare 451104 3640
Ftse 451959
74 0946 22714 451453 2694 64646 2389376 1549444 182XO499 01
797
190000
193000
200000
203000
210000
213000
220000
33500
3355tl
33600
33650
33700
33750
33000
33500
33550
33600
33650
33T00
33T50
33800
1850 5152
1760 5162 33
1792 5134 33
1634 5149 35
1690 5104 34
1776 5110 33
1734 5110 34
2223
2223
2223
2223
931 21 27
958 21 27
910 21 27
931 21 27
910 21 27
931 21 27
931 21 20
3010 40920
41495
3010 40484
40920
3010 40484
40920
3010 40846
452012
453670
454524
455372
456220
457068
457920
Flare 452012 3750
Flse 453670
Flare 454524 3890
Flan 455372
Flare 456220 3650
Ftse 457068
Flare 457920 3900
75 0938 22500
74 I 011 24274
72 I 022 24528
74 I 014 24336
452391
453402
454424
455430
2812 67500
2879 69086
2628 63072
2806 69264
2392189
2395068
2397696
2400582
1549163
154MI75
1548612
1548324
182XO
182XO
182XO
IBOXO493
01
01
01
01
220000 33000 33800 aficG1=493@60'FSpe ravily0 7825H2$pull0ppm
2015M910
223000
230000
233000
000000
33050
33900
33950
34000
33850
33900
33950
34000
1712 5124 33
1771 5116 34
1711 5121
1748 5109 33
2223
2223
931 22 20
924 21 20
924 21 20
924 21 20
41311
3010 40701
40701
3010 40701
458775
459630
460478
461326
Flse 450775
Flare 459630 3990
Flse 460478
Flare 461326 3870
74 I 037 24898
73 I 045 25078
456476
457521
2953 70862
2825 67802
2403534
2406359
1548029
1547746
IBOXO
IBOXO
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD24864DOWBFlowTestldtggs83
ProdnctiontestingAScblumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 33
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %774 2015/11/09 11:00:00 327.00 327.00 1720 5227 36 22.23 931 21 28 38.10 40.471 439.098 Flare 439.098 3.250 73 0.878 21.060 444.705 2.373 56.940 2370.325 15513.50 7 181000 0.1775 11:30:00 327.50 327.50 1549 5235 35 22.23 951 22 28 38.10 41.832 439.955 Flare 439.955 73 0.1776 12:00:00 328.00 328.00 1773 5243 36 22.23 931 22 28 38.10 41.410 440.822 Flare 440.822 3.510 75 0.878 21.060 445.583 2.633 63.180 2372.957 15510.86 7 181000 0.1777 12:30:00 328.50 328.50 1983 5213 36 22.23 931 22 28 38.10 41.079 441.681 Flare 441.681 75 0.1778 13:00:00 329.00 329.00 1618 5236 36 22.23 951 22 28 38.10 41.747 442.544 Flare 442.544 3.710 74 0.965 23.150 446.547 2.745 65.890 2375.703 15508.12 7 181000 0.1779 13:30:00 329.50 329.50 1645 5236 36 22.23 931 22 28 38.10 41.079 443.407 Flare 443.407 74 0.1780 14:00:00 330.00 330.00 1703 5247 36 22.23 931 22 28 38.10 41.079 444.263 Flare 444.263 3.810 75 0.952 22.860 447.500 2.857 68.580 2378.560 15505.26 7 181000 50.5 0.1781 14:00:00 330.00 330.00 API = 50.5 @ 60°F , Specific Gravity = 0.7774, H2S pull 0ppm.782 14:30:00 330.50 330.50 1656 5241 35 22.23 931 21 28 38.10 40.846 445.116 Flare 445.116 75 0.1783 15:00:00 331.00 331.00 1673 5235 35 22.23 931 21 28 38.10 40.846 445.967 Flare 445.967 3.640 75 0.910 21.840 448.410 2.730 65.520 2381.290 15502.53 7 181000 0.1784 15:30:00 331.50 331.50 1744 5227 36 22.23 951 22 28 38.10 41.747 446.827 Flare 446.827 75 0.1785 16:00:00 332.00 332.00 1925 5193 35 22.23 951 22 28 38.10 41.747 447.697 Flare 447.697 3.750 72 1.050 25.200 449.460 2.700 64.800 2383.990 15499.83 7 181000 0.1786 16:30:00 332.50 332.50 1682 5185 35 22.23 931 21 28 38.10 40.611 448.555 Flare 448.555 72 0.1787 17:00:00 333.00 333.00 1872 5185 35 22.23 917 21 28 38.10 40.556 449.400 Flare 449.400 3.740 72 1.047 25.133 450.507 2.693 64.627 2386.683 15497.14 7 182000 0.1788 17:30:00 333.50 333.50 1667 5182 35 22.23 931 21 27 38.10 40.920 450.249 Flare 450.249 72 0.1789 18:00:00 334.00 334.00 1727 5175 34 22.23 931 22 27 38.10 41.154 451.104 Flare 451.104 3.640 74 0.946 22.714 451.453 2.694 64.646 2389.376 15494.44 7 182000 49.9 0.1790 18:00:00 334.00 334.00 API = 49.9 @ 60°F , Specific Gravity = 0.7799, H2S pull 0ppm.791 18:30:00 334.50 334.50 1743 5153 34 22.23 931 21 27 38.10 40.920 451.959 Flare 451.959 74 0.1792 19:00:00 335.00 335.00 1850 5152 34 22.23 931 21 27 38.10 40.920 452.812 Flare 452.812 3.750 75 0.938 22.500 452.391 2.812 67.500 2392.189 15491.63 7 182000 0.1793 19:30:00 335.50 335.50 1760 5162 33 22.23 958 21 27 38.10 41.495 453.670 Flare 453.670 75 0.1794 20:00:00 336.00 336.00 1792 5134 33 22.23 910 21 27 38.10 40.484 454.524 Flare 454.524 3.890 74 1.011 24.274 453.402 2.879 69.086 2395.068 15488.75 7 182000 0.1795 20:30:00 336.50 336.50 1634 5149 35 22.23 931 21 27 38.10 40.920 455.372 Flare 455.372 74 0.1796 21:00:00 337.00 337.00 1690 5104 34 22.23 910 21 27 38.10 40.484 456.220 Flare 456.220 3.650 72 1.022 24.528 454.424 2.628 63.072 2397.696 15486.12 7 182000 0.1797 21:30:00 337.50 337.50 1776 5110 33 22.23 931 21 27 38.10 40.920 457.068 Flare 457.068 72 0.1798 22:00:00 338.00 338.00 1734 5110 34 22.23 931 21 28 38.10 40.846 457.920 Flare 457.920 3.900 74 1.014 24.336 455.438 2.886 69.264 2400.582 15483.24 7 180000 49.3 0.1799 22:00:00 338.00 338.00 API = 49.3 @ 60°F , Specific Gravity = 0.7825, H2S pull 0ppm.800 22:30:00 338.50 338.50 1712 5124 33 22.23 931 22 28 38.10 41.311 458.775 Flare 458.775 74 0.1801 23:00:00 339.00 339.00 1771 5116 34 22.23 924 21 28 38.10 40.701 459.630 Flare 459.630 3.990 74 1.037 24.898 456.476 2.953 70.862 2403.534 15480.29 7 180000 0.1802 23:30:00 339.50 339.50 1711 5121 34 22.23 924 21 28 38.10 40.701 460.478 Flare 460.478 74 0.1803 2015/11/10 00:00:00 340.00 340.00 1748 5109 33 22.23 924 21 28 38.10 40.701 461.326 Flare 461.326 3.870 73 1.045 25.078 457.521 2.825 67.802 2406.359 15477.46 7 180000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Dale Time Cum Row Tubing0 ming
Pres Pres
Flow
Temp
QmksShdw
$as Pma
Dg MIR Piste
Pres TempGze
GasRats CumGas Gas
To
TotalGas
Flared
RdVdBSW08Fmn OilRale 09Cum Water
Gain
WahuWaterCumloarlLTRPH
IMH
$8lrrrrVAPI Smd
Cd
WWlamlddhhmmasHrs Hrs kPag kPag
2015HVIO00000034000340000000hrsreadmg
mm kPag kPa '0 mm ltpm'ld IMm'I)m''Idm'APIFlowingTubmgpressure= 1748kPa
ShutmCasingpressure=5109kPa
Flowingtemperature=33'0
Chokesize=56I64f2223mml
GasRate=4311 IOVP
Totaltluidrate=387m'Ihr
Waterrecoveryrate=283m'Ihr
Condensaterate= I 04m'Ihr
PH=t,Salinity=180XOppmBSSW=73$
API=493@60'F,Separator=924kPagH'S=0 ppmSand=01%
Dailyhrstlowed=24hrs
Cumhrsflowed=340hrs
Dailygasproduced10flarelast24hrs=40941tPm'um
gasProducedtoflare=46132610VP
CondProducedlast24hrs= 2223m'um
CondProduced=45t52m'ater
Recoveredlast24Hrs=6325m'otal
WaterRecovered=240636
m'naalLoadFluidtoRecover=1788382m'oad
FluidLetttoRecover= 1547746
m'ercentageRecoveredfromInaalLoad=1345'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
0030003405034050 1835
01000034100 34100 1836
01300034150 34150 1890
020000 34200 34200 1804
5104
5095 33
5106 33
5080 33
2223
2223
910 21
910 21
910 21
910 21
40266 462169F la e 462169
3810 40411 463009Flare 463009 3990
40484 463852Flee 463852
3810 40338 464694Flare 464694 4050
75 0998
73 1 094
23940 458518
459612
2992 71820 2409352
2956 70956 2412308
1547447I
1547151I
180XO
180XO
01
492 01
020000 34200 34200 eoficG 7832,H26tl'F,Sp Spullg891=492@ ravel=0 ppm
810
811
812
813
814
815
816
817
023000 34250 34250 1737
030000 34300 34300 1766
033000 34350 34350 1932
040000 34400 34400 1943
0430003445034450 1881
050000 34500 34500 1746
053000 34550 34550 1821
060000 34600 34600 1768
5087 33
5094 33
5091 33
5064 34
5050 32
5062 32
5054 32
5052 32
2223
2223
2223
2223
910 21
910 21
924 21
924 21
924 21
931 21
931 21
931 21
40018 465531Flee 465531
3810 40018 466365Flare 466365 4100
40305 467201Flae467201
3810 40379 468042Flare 468042 4080
40379 468883Flee 468883
3810 40685 469727Flare 469727 3850
40685 470575Flee 470575
3810 40685 471423Flare 471423 3900
74 I 066
73 1 102
72 I 078
74 I 014
25584
26438
25872
24336
460678
461779
462857
463871
3034 72816 2415342
2978 71482 2418321
2772 665282421093
2886 69264 2423979
1546848I
1546550I
1546273 I
1545984 I
180XO
180XO
180XO
180XO
01
01
01
493 01
818 0600003460034600 eoficG6tl'F,Sp Spullg891=493@ 7825,H2ravel=0 ppm
819 0630003465034650 1836
0700003470034700 1704
0730003475034750 1889
080000 34800 34800 2043
0830003485034850 1774
0900003490034900 1618
0930003495034950 1760
100000 35000 35000 1709
5059 32
5049 33
5027 33
5019 33
5016
5021 34
5036 35
5030 35
2223
2223
2223
2223
931 21
931 21
938 22
931 21
931 21
910 21
910 21
931 21
40920 472273Flee 472273
3810 40920 473125Flare 473125 4 160
41299 473982Flee 473982
3810 40920 474838Flare 474838 3790
40920 475691Flee 475691
3810 40252 476536Flare 476536 3640
40252 477375Flae 4TI375
3810 40920 478220Flare 478220 3660
75 1 040
74 0985
75 0910
75 0915
24960
23650
21840
21960
464911
465897
466807
467722
3 120 74880 2427099
2805 67310 2429903
2730 65520 2432633
2745 65880 2435378
1545672 I
1545392 I
15MI19 I
1544844I
180XO
180XO
180XO
180XO
01
01
01
498 01
1000003500035000API=498@6tl'F,SpeoficGravW=07805,H2$pullgppm
1030003505035050 1676 5022 35 iiii 931 21 27 XI:40920 479073Flee 479073
PetroCtassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAwetl2XSSHIOWSFlowTestligggs84
ProdoctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 34
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %804 2015/11/10 00:00:00 340.00 340.00 00:00 hrs reading
Flowing Tubing pressure = 1748 kPaShut in Casing pressure = 5109 kPaFlowing temperature = 33°CChoke size = 56/64 (22.23mm)Gas Rate = 43.11 10³m³Total fluid rate = 3.87 m³/hrWater recovery rate = 2.83 m³/hrCondensate rate = 1.04 m³/hrPH =7 , Salinity = 180000 ppm, BS&W = 73 %API = 49.3 @ 60°F, Separator = 924 kPag H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 340 hrsDaily gas produced t0 flare last 24 hrs = 40.94 10³m³Cum gas Produced to flare= 461.326 10³m³Cond Produced last 24 hrs = 22.23 m³Cum Cond Produced = 457.52 m³Water Recovered Last 24 Hrs = 63.25 m³Total Water Recovered = 2406.36 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15477.46 m³ Percentage Recovered from Initial Load = 13.45%Chokes washed in 24 hours=0Total chokes washed =0
805 00:30:00 340.50 340.50 1835 5104 34 22.23 910 21 30 38.10 40.266 462.169 Flare 462.169 73 0.1806 01:00:00 341.00 341.00 1836 5095 33 22.23 910 21 28 38.10 40.411 463.009 Flare 463.009 3.990 75 0.998 23.940 458.518 2.992 71.820 2409.352 15474.47 7 180000 0.1807 01:30:00 341.50 341.50 1890 5106 33 22.23 910 21 27 38.10 40.484 463.852 Flare 463.852 75 0.1808 02:00:00 342.00 342.00 1804 5080 33 22.23 910 21 29 38.10 40.338 464.694 Flare 464.694 4.050 73 1.094 26.244 459.612 2.956 70.956 2412.308 15471.51 7 180000 49.2 0.1809 02:00:00 342.00 342.00 API = 49.2@ 60°F , Specific Gravity = 0.7832, H2S pull 0ppm.810 02:30:00 342.50 342.50 1737 5087 33 22.23 910 21 27 38.10 40.018 465.531 Flare 465.531 73 0.1811 03:00:00 343.00 343.00 1766 5094 33 22.23 910 21 27 38.10 40.018 466.365 Flare 466.365 4.100 74 1.066 25.584 460.678 3.034 72.816 2415.342 15468.48 7 180000 0.1812 03:30:00 343.50 343.50 1932 5091 33 22.23 924 21 27 38.10 40.305 467.201 Flare 467.201 74 0.1813 04:00:00 344.00 344.00 1943 5064 34 22.23 924 21 26 38.10 40.379 468.042 Flare 468.042 4.080 73 1.102 26.438 461.779 2.978 71.482 2418.321 15465.50 7 180000 0.1814 04:30:00 344.50 344.50 1881 5050 32 22.23 924 21 26 38.10 40.379 468.883 Flare 468.883 73 0.1815 05:00:00 345.00 345.00 1746 5062 32 22.23 931 21 27 38.10 40.685 469.727 Flare 469.727 3.850 72 1.078 25.872 462.857 2.772 66.528 2421.093 15462.73 7 180000 0.1816 05:30:00 345.50 345.50 1821 5054 32 22.23 931 21 27 38.10 40.685 470.575 Flare 470.575 72 0.1817 06:00:00 346.00 346.00 1768 5052 32 22.23 931 21 27 38.10 40.685 471.423 Flare 471.423 3.900 74 1.014 24.336 463.871 2.886 69.264 2423.979 15459.84 7 180000 49.3 0.1818 06:00:00 346.00 346.00 API = 49.3@ 60°F , Specific Gravity = 0.7825, H2S pull 0ppm.819 06:30:00 346.50 346.50 1836 5059 32 22.23 931 21 27 38.10 40.920 472.273 Flare 472.273 74 0.1820 07:00:00 347.00 347.00 1704 5049 33 22.23 931 21 27 38.10 40.920 473.125 Flare 473.125 4.160 75 1.040 24.960 464.911 3.120 74.880 2427.099 15456.72 7 180000 0.1821 07:30:00 347.50 347.50 1889 5027 33 22.23 938 22 27 38.10 41.299 473.982 Flare 473.982 75 0.1822 08:00:00 348.00 348.00 2043 5019 33 22.23 931 21 27 38.10 40.920 474.838 Flare 474.838 3.790 74 0.985 23.650 465.897 2.805 67.310 2429.903 15453.92 7 180000 0.1823 08:30:00 348.50 348.50 1774 5016 34 22.23 931 21 27 38.10 40.920 475.691 Flare 475.691 74 0.1824 09:00:00 349.00 349.00 1618 5021 34 22.23 910 21 27 38.10 40.252 476.536 Flare 476.536 3.640 75 0.910 21.840 466.807 2.730 65.520 2432.633 15451.19 7 180000 0.1825 09:30:00 349.50 349.50 1760 5036 35 22.23 910 21 27 38.10 40.252 477.375 Flare 477.375 75 0.1826 10:00:00 350.00 350.00 1709 5030 35 22.23 931 21 27 38.10 40.920 478.220 Flare 478.220 3.660 75 0.915 21.960 467.722 2.745 65.880 2435.378 15448.44 7 180000 49.8 0.1827 10:00:00 350.00 350.00 API = 49.8@ 60°F , Specific Gravity = 0.7805, H2S pull 0ppm.828 10:30:00 350.50 350.50 1676 5022 35 22.23 931 21 27 38.10 40.920 479.073 Flare 479.073 75 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Roid dume
2
Dale Time Cum Row TubingCmingFlowChoke
Pres Pres TempSns
Dg MIR
Pres Temp
CumGas Gas TolalGasRdVd
To Flared
BSWOIGanOilRale 00Cum Wstw Wshr
Gain Rate
WaterGumleadLTRPH SalinilyAPI
WWlamlddhhmmss
2015HVIO110000
113000
35100
3515tl
35100
35150
kPag kPag '0 mm
1844 5010 34 2223
2012 5017 35 iiii931
931
kPa '0
21 27
22 27
mm 1tym'id
3010 40920
41154
479925
480780
Itlap (D
m'lare
479925 3780
Flse 480780
m''Id74 0983 23507
m'60
704 2797 67133 24381751544564
ppm 'API
180XO 01
831 120000
123000
130000
133000
35200
35250
35300
35350
35200
35250
35300
35350
1669 5012 34 2223
1761 4997 35 iiii
1747 5021 34 2223
1697 5023 35 iiii
938
938
931
931
22 27
22 27
21 27
21 27
3010 41299
41299
3010 40920
40920
481639
482499
4633%
484208
Flare 481639 3840
Fice 482499
Flare 483356 3520
Flse 484208
74 0998 23962
75 0080 21120
469703
470503
2842 60190
2640 63360
2441017
2443657
1544280
1544016
180XO
180XO
01
01
140000
140000
35400
35400
35400
35400
1571 5014 35 2223
1
=496@60'6SpeoficGravity=
910
0 7812H
21 27
26pullgppm
3010 40010 485052Flare 485052 3470 74 0902 21653 471485 2568 61627 2446225 1543760 180XO496 01
837 143000
150000
153000
160000
163000
170000
173000
100000
35450
35500
35550
35600
35650
35700
35750
35000
35450
35500
35550
35600
35650
35T00
35T50
35800
1694 5010 35 iiii
1708 5005 35 2223
1681 4985 35 iiii
1574 4975 35 2223
1520 4983 35 iiii
1652 4995 35 2223
1616 5012 35 iiii
1725 4999 35 2223
931
931
931
931
931
945
945
931
21 27
21 27
21 27
21 27
21 27
22 27
22 27
21 27
40685
3010 40685
40920
3010 40920
40920
3010 41444
41444
3010 40920
485092
486740
487590
488442
489295
4X153
491016
491074
Flse 485092
Flare 486740 3520
Fice 487590
Flare 480442 3500
Fise 489295
Flare 490153 3480
Fice 491016
Flare 491074 3740
74 0915 21965
72 I 002 24058
74 0905 21715
73 I 010 24235
472400
473403
474307
475317
2605 62515
2578 61862
2575 61805
2730 65525
2448030
2451407
2453982
2456713
1543499
1543241
1542984
1542711
180XO
180XO
180XO
180XO495
01
01
01
01
100000
103000
35000
35050
35800
35850
26pullgppm1=495@60'6SpeoficGravily=
1687 4971 35 iiii
0 7818H
924 21 27 40541 492723Fice 492723
851
190000
193000
200000
203000
210000
213000
220000
35900
35950
36000
36050
36100
36150
36200
35900
35950
36000
36050
36100
36150
36200
1854 4956 34 2223
1677 4952 33 iiii
1901 4964 32 2223
1785 4964 32 iiii
1686 4957 34 2223
1750 4946 34 iiii1737 4945 33 2223
896
896
896
896
896
896
896
21 27
21 27
21 26
20 26
20 26
20 27
20 27
3010 39720
39720
3010 39801
39331
3010 39331
39259
3010 39259
493559
494387
495215
496039
496059
497677
498495
Flare 493559 3560
Flee 49438T
Flare 495215 3810
Flee 496039
Flare 496059 3780
Fice 49767T
Flare 490495 3490
74 0926 22214
72 I 067 25603
74 0983 23507
73 0942 22615
476243
477310
470292
479235
2634 63226
2743 65837
2797 67133
2548 61145
2459347
2462090
2464087
2467435
1542447
1542173
1541893
1541630
180XO
HHXO
182XO
182XO408
01
01
01
01
220000 36200 36200 1=488@60'6SpeoficGravily0 7846H26pullgppm
857
223000
230000
233000
2015MVll000000
36250
36300
36350
36400
36250
36300
36350
36400
1760 4950 33 iiii
1803 4920 33 2223
1815 4915 33 iiii
1734 4912 33 2223
896
910
910
910
20 26
20 26
20 26
20 26
39331
3010 39617
39617
3010 39617
499314
500136
500962
501787
Flee 499314
Flare 5X136 3560
Flee 5X962
Flare 501787 3770
75 0090 21360
74 0980 23525
480125
481105
2670 64080
2790 66955
2470105
2472095
1511371
1541092
182XO
182XO
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAwell24804DOWSFlowTestldtggs85
ProdnctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 35
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %829 2015/11/10 11:00:00 351.00 351.00 1844 5018 34 22.23 931 21 27 38.10 40.920 479.925 Flare 479.925 3.780 74 0.983 23.587 468.704 2.797 67.133 2438.175 15445.64 7 180000 0.1830 11:30:00 351.50 351.50 2012 5017 35 22.23 931 22 27 38.10 41.154 480.780 Flare 480.780 74 0.1831 12:00:00 352.00 352.00 1669 5012 34 22.23 938 22 27 38.10 41.299 481.639 Flare 481.639 3.840 74 0.998 23.962 469.703 2.842 68.198 2441.017 15442.80 7 180000 0.1832 12:30:00 352.50 352.50 1761 4997 35 22.23 938 22 27 38.10 41.299 482.499 Flare 482.499 74 0.1833 13:00:00 353.00 353.00 1747 5021 34 22.23 931 21 27 38.10 40.920 483.356 Flare 483.356 3.520 75 0.880 21.120 470.583 2.640 63.360 2443.657 15440.16 7 180000 0.1834 13:30:00 353.50 353.50 1697 5023 35 22.23 931 21 27 38.10 40.920 484.208 Flare 484.208 75 0.1835 14:00:00 354.00 354.00 1571 5014 35 22.23 910 21 27 38.10 40.018 485.052 Flare 485.052 3.470 74 0.902 21.653 471.485 2.568 61.627 2446.225 15437.60 7 180000 49.6 0.1836 14:00:00 354.00 354.00 API = 49.6 @ 60°F , Specific Gravity = 0.7812, H2S pull 0ppm.837 14:30:00 354.50 354.50 1694 5010 35 22.23 931 21 27 38.10 40.685 485.892 Flare 485.892 74 0.1838 15:00:00 355.00 355.00 1708 5005 35 22.23 931 21 27 38.10 40.685 486.740 Flare 486.740 3.520 74 0.915 21.965 472.400 2.605 62.515 2448.830 15434.99 7 180000 0.1839 15:30:00 355.50 355.50 1681 4985 35 22.23 931 21 27 38.10 40.920 487.590 Flare 487.590 74 0.1840 16:00:00 356.00 356.00 1574 4975 35 22.23 931 21 27 38.10 40.920 488.442 Flare 488.442 3.580 72 1.002 24.058 473.403 2.578 61.862 2451.407 15432.41 7 180000 0.1841 16:30:00 356.50 356.50 1520 4983 35 22.23 931 21 27 38.10 40.920 489.295 Flare 489.295 72 0.1842 17:00:00 357.00 357.00 1652 4995 35 22.23 945 22 27 38.10 41.444 490.153 Flare 490.153 3.480 74 0.905 21.715 474.307 2.575 61.805 2453.982 15429.84 7 180000 0.1843 17:30:00 357.50 357.50 1616 5012 35 22.23 945 22 27 38.10 41.444 491.016 Flare 491.016 74 0.1844 18:00:00 358.00 358.00 1725 4999 35 22.23 931 21 27 38.10 40.920 491.874 Flare 491.874 3.740 73 1.010 24.235 475.317 2.730 65.525 2456.713 15427.11 7 180000 49.5 0.1845 18:00:00 358.00 358.00 API = 49.5 @ 60°F , Specific Gravity = 0.7818, H2S pull 0ppm.846 18:30:00 358.50 358.50 1687 4971 35 22.23 924 21 27 38.10 40.541 492.723 Flare 492.723 73 0.1847 19:00:00 359.00 359.00 1854 4956 34 22.23 896 21 27 38.10 39.728 493.559 Flare 493.559 3.560 74 0.926 22.214 476.243 2.634 63.226 2459.347 15424.47 7 180000 0.1848 19:30:00 359.50 359.50 1677 4952 33 22.23 896 21 27 38.10 39.728 494.387 Flare 494.387 74 0.1849 20:00:00 360.00 360.00 1901 4964 32 22.23 896 21 26 38.10 39.801 495.215 Flare 495.215 3.810 72 1.067 25.603 477.310 2.743 65.837 2462.090 15421.73 7 180000 0.1850 20:30:00 360.50 360.50 1785 4964 32 22.23 896 20 26 38.10 39.331 496.039 Flare 496.039 72 0.1851 21:00:00 361.00 361.00 1686 4957 34 22.23 896 20 26 38.10 39.331 496.859 Flare 496.859 3.780 74 0.983 23.587 478.292 2.797 67.133 2464.887 15418.93 7 182000 0.1852 21:30:00 361.50 361.50 1750 4946 34 22.23 896 20 27 38.10 39.259 497.677 Flare 497.677 74 0.1853 22:00:00 362.00 362.00 1737 4945 33 22.23 896 20 27 38.10 39.259 498.495 Flare 498.495 3.490 73 0.942 22.615 479.235 2.548 61.145 2467.435 15416.38 7 182000 48.8 0.1854 22:00:00 362.00 362.00 API = 48.8 @ 60°F , Specific Gravity = 0.7846, H2S pull 0ppm.855 22:30:00 362.50 362.50 1760 4950 33 22.23 896 20 26 38.10 39.331 499.314 Flare 499.314 73 0.1856 23:00:00 363.00 363.00 1803 4920 33 22.23 910 20 26 38.10 39.617 500.136 Flare 500.136 3.560 75 0.890 21.360 480.125 2.670 64.080 2470.105 15413.71 7 182000 0.1857 23:30:00 363.50 363.50 1815 4915 33 22.23 910 20 26 38.10 39.617 500.962 Flare 500.962 75 0.1858 2015/11/11 00:00:00 364.00 364.00 1734 4912 33 22.23 910 20 26 38.10 39.617 501.787 Flare 501.787 3.770 74 0.980 23.525 481.105 2.790 66.955 2472.895 15410.92 7 182000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Dale Time Cum Row Tubing
Pres
WWlamlddhhmmasHrs Hrs kPag
Casing
Pres
kPag
Flow
Temp
QmksShdm
$ne Pms
mm kPag
Dg MIR
Pres Temp
kPa '0
Piste GasRateCumGas
Gm
mm 1tym'id
ID'm'as
To
TotalGas RdVd BSW
Flared
Ityap (ljm'''Idm'IGan
OilRale OIGum Wstw
Gain
WahnWaterCumloarlLTRPH
IMH
SalinilyAPI Smd
Cd
ppm 'API
2015HVII00000036400364000000hrsreadmg
FlowingTubmgpressure=1734kPa
ShutmCasingpressure=4912kPa
Flowingtemperature=33'0
Chokesize=56I64f2223mmi
GasRate=4195IOVP
Totalguidrate=377m'Ihr
Waterrecoveryrate=279m'Ihr
Condensaterate=098m'Ihr
PH=t,Salinity=182XOppmBSSW=74$
API=488@60'F,Separator=910kPagH'S=0 ppmSand=01%
Dailyhrsgowed=24hrs
Cumhrsflowed=364hrs
Dailygasproduced10flarelast24hrs=40461tPm'um
gasProducedtoflare=501tgyIggy
CondProducedlast24hrs= 2358m'um
CondProduced=48110
m'ater
Recoveredlast24Hrs=6654m'otal
WaterRecovered=247289
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1541092
m'ercentageRecoveredfromInmalLoad=1383 'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
0030003645036450 1748
0100003650036500 1827
0130003655036550 1715
020000 36600 36600 1732
4934 32
4930 33
4923
4925 34
J'J 910 20 28 XI: 39474 504257
2223 910 20 28 3810 39474 505079
iiii 910 20 27 XI:39545 502612
2223 910 20 28 3810 39474 503435
Ftze
Flare
Ftze
Flare
502612
503435 3580 74 0931
50425T
505079 3800 76 0912
22339
21888
482036
482948
2649 63581 2475544 1540828 7
2888 69312 2478432 1540539 7
182XO
182XO
01
495 01
0200003660036600 oficG60'FSpe ravily=0 t818H2$pull0ppmAPI=495@
0230003665036650 1787 4911 J'J 910 20 27 XI: 39545 505903Ftze 505903
030000 36700 36700 1730 4914 34 2223 910 20 28 3810 39474 506726Flare 506726 3710 73 1 002 24041 483949 2708 64999 24811411540268 7 182XO 01
0330003675036750 1758 4904 J'J 910 20 28 XI: 39474 507548Ftze 507548
040000 36800 36800 1802 4X5 2223 910 20 28 3810 39474 508370Flare 508370 3660 75 0915 21960 484864 2745 65880 2483885 1539993 7 182XO 01
0430003685036850 1809 4910 J'J 910 20 28 XI: 39083 509189Ftze 509189
870
871
0500003690036900 1741
0530003695036950 1718
060000 37000 37000 1762
4910 33
4904 33
4915 33
2223 910 20 27 3810 39154 510004
iiii 910 20 27 XI:39154 510819
2223 910 20 27 391 0 39154 511 635
Flare
Ftze
Flare
510004 3720 73 1 004
510819
511635 3780 74 0983
24106
23587
485869
486852
2716 65174 2486601 1539722 7
2797 67133 2489398 1539442 7
186COO
186COO
01
495 01
0600003700037000 oficG60'FSpe ravily=0 t818H2$pull0ppmAPI=495@
874
875
876
878
0630003705037050 1641
070000 37100 37100 1493
073000 37150 37150 1633
080000 37200 37200 1709
083000 37250 37250 1587
090000 37300 37300 1801
093000 37350 37350 1582
100000 37400 37400 1571
4903
4899 35
4900 35
4899 35
4INI 35
4890 35
4893 35
4878 35
J'J 910 20 27 XI: 39545 512455
2223 910 20 28 3810 39474 513278
iiii 910 20 28 XI:38996 514095
2223 910 20 28 3810 39474 514913
iiii 924 21 28 Xl: 40232 515743
2223 924 21 28 3810 40232 516581
iiii 910 21 28 XI:39710 517414
2223 910 20 28 3810 39474 518239
Ftze
Flare
Ftze
Flare
Ftze
Flare
Ftze
Flare
512455
513278 3640 73 0983
514095
514913 3860 75 0965
515743
516581 3660 73 0988
517414
518239 3550 74 0923
23587
23160
23717
22152
487834
488799
489788
490711
2657 63773 2492055 1539176 7
2895 69480 2494950 1538887 7
2672 64123 249762215386207
2627 63048 2500249 1538357 7
184XO
184XO
184XO
184XO
01
01
01
488 01
1000003740037400API=488@60'FSpeoficGravily=07849H2$pullgppm
1030003745037450 1664 4878 35 iiii 910 20 28 XI:39474 519061FIze519061
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD24864DIWSFlowTestldkgga66
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 36
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %859 2015/11/11 00:00:00 364.00 364.00 00:00 hrs reading
Flowing Tubing pressure = 1734 kPaShut in Casing pressure = 4912 kPaFlowing temperature = 33°CChoke size = 56/64 (22.23mm)Gas Rate = 41.95 10³m³Total fluid rate = 3.77 m³/hrWater recovery rate = 2.79 m³/hrCondensate rate = 0.98 m³/hrPH =7 , Salinity = 182000 ppm, BS&W = 74 %API = 48.8 @ 60°F, Separator = 910 kPag H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 364 hrsDaily gas produced t0 flare last 24 hrs = 40.46 10³m³Cum gas Produced to flare= 501.787 10³m³Cond Produced last 24 hrs = 23.58 m³Cum Cond Produced = 481.10 m³Water Recovered Last 24 Hrs = 66.54 m³Total Water Recovered = 2472.89 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15410.92 m³ Percentage Recovered from Initial Load = 13.83 %Chokes washed in 24 hours=0Total chokes washed =0
860 00:30:00 364.50 364.50 1748 4934 32 22.23 910 20 27 38.10 39.545 502.612 Flare 502.612 74 0.1861 01:00:00 365.00 365.00 1827 4930 33 22.23 910 20 28 38.10 39.474 503.435 Flare 503.435 3.580 74 0.931 22.339 482.036 2.649 63.581 2475.544 15408.28 7 182000 0.1862 01:30:00 365.50 365.50 1715 4923 34 22.23 910 20 28 38.10 39.474 504.257 Flare 504.257 74 0.1863 02:00:00 366.00 366.00 1732 4925 34 22.23 910 20 28 38.10 39.474 505.079 Flare 505.079 3.800 76 0.912 21.888 482.948 2.888 69.312 2478.432 15405.39 7 182000 49.5 0.1864 02:00:00 366.00 366.00 API = 49.5 @ 60°F , Specific Gravity = 0.7818, H2S pull 0ppm.865 02:30:00 366.50 366.50 1787 4911 34 22.23 910 20 27 38.10 39.545 505.903 Flare 505.903 76 0.1866 03:00:00 367.00 367.00 1730 4914 34 22.23 910 20 28 38.10 39.474 506.726 Flare 506.726 3.710 73 1.002 24.041 483.949 2.708 64.999 2481.141 15402.68 7 182000 0.1867 03:30:00 367.50 367.50 1758 4904 34 22.23 910 20 28 38.10 39.474 507.548 Flare 507.548 73 0.1868 04:00:00 368.00 368.00 1802 4905 34 22.23 910 20 28 38.10 39.474 508.370 Flare 508.370 3.660 75 0.915 21.960 484.864 2.745 65.880 2483.885 15399.93 7 182000 0.1869 04:30:00 368.50 368.50 1809 4910 34 22.23 910 20 28 38.10 39.083 509.189 Flare 509.189 75 0.1870 05:00:00 369.00 369.00 1741 4910 33 22.23 910 20 27 38.10 39.154 510.004 Flare 510.004 3.720 73 1.004 24.106 485.869 2.716 65.174 2486.601 15397.22 7 186000 0.1871 05:30:00 369.50 369.50 1718 4904 33 22.23 910 20 27 38.10 39.154 510.819 Flare 510.819 73 0.1872 06:00:00 370.00 370.00 1762 4915 33 22.23 910 20 27 38.10 39.154 511.635 Flare 511.635 3.780 74 0.983 23.587 486.852 2.797 67.133 2489.398 15394.42 7 186000 49.5 0.1873 06:00:00 370.00 370.00 API = 49.5 @ 60°F , Specific Gravity = 0.7818, H2S pull 0ppm.874 06:30:00 370.50 370.50 1641 4903 34 22.23 910 20 27 38.10 39.545 512.455 Flare 512.455 74 0.1875 07:00:00 371.00 371.00 1493 4899 35 22.23 910 20 28 38.10 39.474 513.278 Flare 513.278 3.640 73 0.983 23.587 487.834 2.657 63.773 2492.055 15391.76 7 184000 0.1876 07:30:00 371.50 371.50 1633 4900 35 22.23 910 20 28 38.10 38.996 514.095 Flare 514.095 73 0.1877 08:00:00 372.00 372.00 1709 4899 35 22.23 910 20 28 38.10 39.474 514.913 Flare 514.913 3.860 75 0.965 23.160 488.799 2.895 69.480 2494.950 15388.87 7 184000 0.1878 08:30:00 372.50 372.50 1587 4881 35 22.23 924 21 28 38.10 40.232 515.743 Flare 515.743 75 0.1879 09:00:00 373.00 373.00 1801 4890 35 22.23 924 21 28 38.10 40.232 516.581 Flare 516.581 3.660 73 0.988 23.717 489.788 2.672 64.123 2497.622 15386.20 7 184000 0.1880 09:30:00 373.50 373.50 1582 4893 35 22.23 910 21 28 38.10 39.710 517.414 Flare 517.414 73 0.1881 10:00:00 374.00 374.00 1571 4878 35 22.23 910 20 28 38.10 39.474 518.239 Flare 518.239 3.550 74 0.923 22.152 490.711 2.627 63.048 2500.249 15383.57 7 184000 48.8 0.1882 10:00:00 374.00 374.00 API = 48.8 @ 60°F , Specific Gravity = 0.7849, H2S pull 0ppm.883 10:30:00 374.50 374.50 1664 4878 35 22.23 910 20 28 38.10 39.474 519.061 Flare 519.061 74 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Dale Time
WWlmnlddhhmmss
2015IIVII110000
113000
120000
123000
130000
Cum Row
Hrs Hrs
3750037500
3755037550
3760037600
3765037650
3770037700
Tubing
Pres
kPag
1697
1810
1716
1683
1598
OwingFlow
Pres Temp
kPag '0
4883 35
4871
4865 35
4870 35
4867 35
Omks
$ns
mm
2223
2223
2223
924
924
910
924
924
Dg
Pres
MIR
Temp
Piste GasRats CumGas Gas
Gm To
mm lipm'id10'm'0
10 40060 519090Flare
39995 520724Flee
3010 39474 521551Flare
39995 522379Flee
3010 39995 523212Flare
TotalGas RdVd
Flared
Itpap (I)m'19
890 3750
520724
521551 3780
522379
523212 3990
BSWOIGan
75 0938
74 0983
1 037
OilRale OlCum
m'Idm'2
500 491640
23507 492631
24898 493660
Wstw
Gain
2812
2797
2953
WahnWaterCumloarlLTRPH
IMM
67500 2503062 1538076 7
67133 2505059 1537796 7
70862 2508012 1537501 7
SelrrrrV
184XO
184XO
182XO
API
'API
01
01
01
133000
150000
150000
3775037700$hutmwelltorunmandsetremrders
37900 37700Openwelltofrowlhrough2233mm(56164"dualchokesetup)
37900 37700 6878 6954 2223 0 0 0 XI: tl tlgg 523212Flee 523212 0000 'I0Otlg 0Ogtl 493660 0Ogtl 0tlgg 25tlg012 1537501
150500
151000
37908 37708 1303 6650 I9 iiii
3791t37717Fluidtocurses
Jc I'lee523304
1510003791737717stermservicethrougha 30Imm)15")onficeplateM
151000
151500
153000
154500
160000
163000
170000
3791737717 1275 6707
37925 37T25 1855 6579
3795037750 2292 6340
37975 37T75 2381 5595
3800037800 2123 5441
38050 37850 1663 4981
38100 37900 1707 4894
26 2223 931 8 19
33 r J
38 2223 1600 50 29
32 r J
36 2223 1103 47 24
34 iiii 803 35 25
34 2223 896 25 25
3010
Jc I
'010
Jc I
'010
Jc I
'010
26233
80987
65301
50851
43870
523395Flare 523395
Ftse 523581
5241 39Flare 524139
Ftse 524902
525664Flare 525664
526075Ftse 526875
527061Flare 527861
4750 72
3530
1 330 31920
0988 23722
494990
495987
3420
2542
82080
60990
2512232 1537159
2514773 1536905
7 179XO
7 186XO
00
03
38150 37950 1703 4910
3820038000 1714 4880
173000
100000
3820038000FPI=501@100000 60'FSpe
3825038050 1712 4903
38300 38100 1741 4892
103000
190000
35 iiii 951 19 26
35 2223 931 20 26
oficGravity=0 7793H2$pulllppm
35 iiii 951 19 25
34 2223 910 19 25
Jc I
'010
Jc I
'010
39480
39802
39552
38723
528730Flee 528730
529555Flare 529555
530382Flee 5X382
531197Flare 531197
3730 74
3560 73
0970 23275
0961 23069
496957
497910
2760
2599
66245
62371
25175331536629
2520132 1536369 7 186XO 01
7 186XO501 01
910
911
193000
200000
203000
210000
213000
38350 38150 1729 4912
38400 38200 1702 4883
38450 38250 1700 4877
38500 38300 1685 4862
30550 38350 1715 4864
34 iiii 910 19 27
33 2223 924 19 27
33 iiii 924 19 26
34 2223 924 19 26
34 iiii 924 19 20
Jc I
'010
Jc I
'010
Jc I
'8502
38859
38436
38436
38296
532003Ftse 532003
532009Flare 532809
533614Flee 533614
534415Flare 534415
535214Flee 535214
3480 75
3330 74
0070 20800
0066 20779
490780
499654
2610
2464
62640
59141
2522742 1536100
2525206 1535861
7 HMXO
7 186XO
01
01
912 220000 38600 38400 1738 4855 34 2223 924 19 20 3010 38296 536012Flare 536012 3290 0055 20530 500509 2435 50430252764115356107 IBBXO493 01
913 220000 3860038400API=493@ oficGravity=0 t826H2$pull0ppm60'FSpe
914
915
916
917
223000
230000
233000
2015IIV12000000
38650 38450 1728 4856
3870038500 1711 4840
3875038550 1726 4845
3800038600 1704 4836
34 iiii 924 18 27
34 2223 924 18 27
34 iiii 924 18 27
34 2223 924 18 27
Jc I
'010
Jc I
'010
37864
37IM4
37864
37IM4
536006Flee 536806
537594Flare 537594
530383Flee 538383
5391 72Flare 539172
3400 73
3420 75
0918 22032
0055 20520
501427
502282
2402
2565
59560
61560
25301231535370
2532688 1535113
7 IBBXO
7 IBBXO
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAweD24864DOWBFlowTestllgggsBT
ProdnctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 37
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %884 2015/11/11 11:00:00 375.00 375.00 1697 4883 35 22.23 924 21 27 38.10 40.068 519.890 Flare 519.890 3.750 75 0.938 22.500 491.648 2.812 67.500 2503.062 15380.76 7 184000 0.1885 11:30:00 375.50 375.50 1810 4871 34 22.23 924 21 28 38.10 39.995 520.724 Flare 520.724 75 0.1886 12:00:00 376.00 376.00 1716 4865 35 22.23 910 20 28 38.10 39.474 521.551 Flare 521.551 3.780 74 0.983 23.587 492.631 2.797 67.133 2505.859 15377.96 7 184000 0.1887 12:30:00 376.50 376.50 1683 4878 35 22.23 924 21 28 38.10 39.995 522.379 Flare 522.379 74 0.1888 13:00:00 377.00 377.00 1598 4867 35 22.23 924 21 28 38.10 39.995 523.212 Flare 523.212 3.990 74 1.037 24.898 493.668 2.953 70.862 2508.812 15375.01 7 182000 0.1889 13:30:00 377.50 377.00 Shut in well to run in and set recorders.890 15:00:00 379.00 377.00 Open well to flow through 22.33mm (56/64" dual choke setup)891 15:00:00 379.00 377.00 6878 6954 22.23 0 0 0 38.10 0.000 523.212 Flare 523.212 0.000 74 0.000 0.000 493.668 0.000 0.000 2508.812 15375.01 0.1892 15:05:00 379.08 377.08 1303 6658 19 22.23 38.10 Flare 523.304 74 0.1893 15:10:00 379.17 377.17 Fluid to surface894 15:10:00 379.17 377.17 Meter in service through a 38.1mm (1.5") orifice plate895 15:10:00 379.17 377.17 1275 6707 26 22.23 931 8 19 38.10 26.233 523.395 Flare 523.395 74 0.1896 15:15:00 379.25 377.25 1855 6579 33 22.23 38.10 Flare 523.581 74 0.1897 15:30:00 379.50 377.50 2292 6340 38 22.23 1600 50 29 38.10 80.987 524.139 Flare 524.139 74 0.1898 15:45:00 379.75 377.75 2381 5595 32 22.23 38.10 Flare 524.902 74 0.1899 16:00:00 380.00 378.00 2123 5441 36 22.23 1103 47 24 38.10 65.381 525.664 Flare 525.664 4.750 72 1.330 31.920 494.998 3.420 82.080 2512.232 15371.59 7 179000 0.0900 16:30:00 380.50 378.50 1663 4981 34 22.23 883 35 25 38.10 50.851 526.875 Flare 526.875 72 0.0901 17:00:00 381.00 379.00 1707 4894 34 22.23 896 25 25 38.10 43.870 527.861 Flare 527.861 3.530 72 0.988 23.722 495.987 2.542 60.998 2514.773 15369.05 7 186000 0.3902 17:30:00 381.50 379.50 1703 4910 35 22.23 951 19 26 38.10 39.480 528.730 Flare 528.730 72 0.3903 18:00:00 382.00 380.00 1714 4888 35 22.23 931 20 26 38.10 39.802 529.555 Flare 529.555 3.730 74 0.970 23.275 496.957 2.760 66.245 2517.533 15366.29 7 186000 50.1 0.1904 18:00:00 382.00 380.00 API = 50.1 @ 60°F , Specific Gravity = 0.7793, H2S pull 0ppm.905 18:30:00 382.50 380.50 1712 4903 35 22.23 951 19 25 38.10 39.552 530.382 Flare 530.382 74 0.1906 19:00:00 383.00 381.00 1741 4892 34 22.23 910 19 25 38.10 38.723 531.197 Flare 531.197 3.560 73 0.961 23.069 497.918 2.599 62.371 2520.132 15363.69 7 186000 0.1907 19:30:00 383.50 381.50 1729 4912 34 22.23 910 19 27 38.10 38.582 532.003 Flare 532.003 73 0.1908 20:00:00 384.00 382.00 1702 4883 33 22.23 924 19 27 38.10 38.859 532.809 Flare 532.809 3.480 75 0.870 20.880 498.788 2.610 62.640 2522.742 15361.08 7 186000 0.1909 20:30:00 384.50 382.50 1700 4877 33 22.23 924 19 26 38.10 38.436 533.614 Flare 533.614 75 0.1910 21:00:00 385.00 383.00 1685 4862 34 22.23 924 19 26 38.10 38.436 534.415 Flare 534.415 3.330 74 0.866 20.779 499.654 2.464 59.141 2525.206 15358.61 7 186000 0.1911 21:30:00 385.50 383.50 1715 4864 34 22.23 924 19 28 38.10 38.296 535.214 Flare 535.214 74 0.1912 22:00:00 386.00 384.00 1738 4855 34 22.23 924 19 28 38.10 38.296 536.012 Flare 536.012 3.290 74 0.855 20.530 500.509 2.435 58.430 2527.641 15356.18 7 188000 49.3 0.1913 22:00:00 386.00 384.00 API = 49.3 @ 60°F , Specific Gravity = 0.7826, H2S pull 0ppm.914 22:30:00 386.50 384.50 1728 4856 34 22.23 924 18 27 38.10 37.864 536.806 Flare 536.806 74 0.1915 23:00:00 387.00 385.00 1711 4840 34 22.23 924 18 27 38.10 37.864 537.594 Flare 537.594 3.400 73 0.918 22.032 501.427 2.482 59.568 2530.123 15353.70 7 188000 0.1916 23:30:00 387.50 385.50 1726 4845 34 22.23 924 18 27 38.10 37.864 538.383 Flare 538.383 73 0.1917 2015/11/12 00:00:00 388.00 386.00 1704 4836 34 22.23 924 18 27 38.10 37.864 539.172 Flare 539.172 3.420 75 0.855 20.520 502.282 2.565 61.560 2532.688 15351.13 7 188000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Dale Time Cum Row
Well
Tubing0 ming
Pres Pres
Flow
Temp
OnficeDryRowMalar
ChokeBshe Dg MIR
Sws Pres Pres Temp
CumGas Gas
To
TraaiGasRdydSSWDilGan
Flared
OilRale OICum
Rnid
Wstw Wsdr
Gain Rate
WaterGumloadLTRPH SelrrrrV
dume
2
API Smd
Cd
WWfamfddhhmmss
918 2015MH12 000000 38800
kPag kPag
386000000hrsreadmg
mm kPag kPa '0 mm 1tym'ld Ryap (I)m' m''Idm'APIFlowingTubmgpressure=1704kPa
ShutmCasingpressure=4836kPa
Flowingtemperature=34'0
Chokesize=56I64f2223mml
GasRate=4010Ighip
Totaltluidrate=342m'Ihr
Waterrecoveryrate=257m'Ihr
Condensaterate= 0 85m'Ihr
PH=T,Salinity=IBBXOppmBSBW=75S
API=493@60'F,Separator=924kPagH'S=0 ppmSand=01%
Dailyhrstlowed=22hrs
Cumhrsflowed=386hrs
Dailygasproduced10flarelast24hrs=37391tPm'um
gasProducedtoflare=53917210hip
CondProducedlast24hrs= 2118m'um
CondProduced=50228m'ater
Recoveredlast24Hrs=5979m'otal
WaterRecovered=253269
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1535113
m'ercentageRecoveredfromInmalLoad=1416'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
919
921
003000
010000
013000
020000
38850
38900
38950
39000
38650 1743
38700 1700
38750 1711
38800 1696
4850
4841
4840 33
4863 33
924 18
2223 924 18
iiii 924 18
2223 924 18
28 XI:37793 539960Flee
28 3810 37793 540748Flare
27 XI:37862 541536Flee
26 3810 37931 542325Flare
539960
540748 3410
541536
542325 3350
74 0887 21278
74 0871 20904
503169 2523
504040 2479
60562 2535211
59496 2537690
15348617
15346137
ISBXO
ISBXO
01
497 01
020000 39000 38800 oficG60'FSpe 26pull0API=497@ ravily=07808H ppm
924
931
023000
030000
033000
040000
043000
050000
053000
060000
39050
39100
39150
39200
39250
39300
39350
39400
38850 1652
38900 1694
38950 1703
39000 1742
39050 1758
39100 1722
39150 1695
39200 1702
4842 33
4870 33
4871 33
4857 34
4843
4842 34
4836
4831
iiii 931 18
2223 910 18
iiii 910 18
2223 931 18
931 18
2223 938 18
938 18
2223 938 18
26 XI:38066 543117Flee
26 3810 37155 543900Flare
26 XI:37661 544680Flee
26 3810 38066 545469Flare
27 XI: 37572 546256Flee
27 3810 37704 547041Flare
27 XI:37704 547826Flee
27 3810 37704 548612Flare
54311T
543900 3260
544680
545469 3400
546256
547041 3250
547826
548612 3370
75 0815 19560
73 0918 22032
74 0845 20280
74 0876 21029
504855 2445
505773 2482
506618 2405
507494 2494
586802540135
59568 2542617
577202545022
59851 2547516
15343687
15341207
1533880 7
1533630 7
ISBXO
ISBXO
ISBXO
ISBXO
01
01
01
495 01
060000 39400 39200 oficG60'FSpe 26pull0API=495@ ravily=07818H ppm
937
063000
070000
073000
080000
083000
090000
093000
100000
39450
39500
39550
39600
39650
39700
39750
39800
39250 1737
39300 1635
39350 1623
39400 1622
39450 1648
39500 1591
39550 1520
39600 1494
4816 33
4817 35
4816 36
4824 35
4804 35
4800 36
4799
4811 34
iiii 931 18
2223 938 18
iiii 938 18
2223 938 18
iiii 931 18
2223 931 18
931 18
2223 910 18
27 XI:37742 549397Flee
28 3810 38061 550187Flare
28 XI:38061 550980Flee
28 3810 38061 551773Flare
27 XI:37996 552565Flee
27 3810 37742 553354Flare
28 XI:37927 554142Flee
27 3810 37087 554924Flare
54939T
550IBT 3390
550980
551773 3420
552565
553354 4410
554142
554924 4330
75 0848 20340
74 0889 21341
72 I 235 29635
71 I 256 X137
508341 2543
509230 2531
510465 3 175
511721 3074
61020 2550059
60739 2552590
76205 2555765
73783 2558839
1533376 7
15331237
1532806 7
1532498 7
ISBXO
ISBXO
ISBXO
ISBXO
01
01
01
496 01
100000
103000
39800
39850
39600API=496@60'FSpeoficGravily=07812H26pullgppm
39650 1611 4802 34 iiii 910 18 27 XI:36832 555694Flee 555694
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIMG,.IAwell24884IOWBFlowTestldbggat38
ProductiontestItgASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 38
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %918 2015/11/12 00:00:00 388.00 386.00 00:00 hrs reading
Flowing Tubing pressure = 1704 kPaShut in Casing pressure = 4836 kPaFlowing temperature = 34°CChoke size = 56/64 (22.23mm)Gas Rate = 40.10 10³m³Total fluid rate = 3.42 m³/hrWater recovery rate = 2.57 m³/hrCondensate rate = 0.85 m³/hrPH =7 , Salinity = 188000 ppm, BS&W = 75 %API = 49.3 @ 60°F, Separator = 924 kPag H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 22 hrs Cum hrs flowed = 386 hrsDaily gas produced t0 flare last 24 hrs = 37.39 10³m³Cum gas Produced to flare= 539.172 10³m³Cond Produced last 24 hrs = 21.18 m³Cum Cond Produced = 502.28 m³Water Recovered Last 24 Hrs = 59.79 m³Total Water Recovered = 2532.69 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15351.13 m³ Percentage Recovered from Initial Load = 14.16 %Chokes washed in 24 hours=0Total chokes washed =0
919 00:30:00 388.50 386.50 1743 4850 34 22.23 924 18 28 38.10 37.793 539.960 Flare 539.960 75 0.1920 01:00:00 389.00 387.00 1700 4841 34 22.23 924 18 28 38.10 37.793 540.748 Flare 540.748 3.410 74 0.887 21.278 503.169 2.523 60.562 2535.211 15348.61 7 188000 0.1921 01:30:00 389.50 387.50 1711 4840 33 22.23 924 18 27 38.10 37.862 541.536 Flare 541.536 74 0.1922 02:00:00 390.00 388.00 1696 4863 33 22.23 924 18 26 38.10 37.931 542.325 Flare 542.325 3.350 74 0.871 20.904 504.040 2.479 59.496 2537.690 15346.13 7 188000 49.7 0.1923 02:00:00 390.00 388.00 API = 49.7 @ 60°F , Specific Gravity = 0.7808, H2S pull 0ppm.924 02:30:00 390.50 388.50 1652 4842 33 22.23 931 18 26 38.10 38.066 543.117 Flare 543.117 74 0.1925 03:00:00 391.00 389.00 1694 4870 33 22.23 910 18 26 38.10 37.155 543.900 Flare 543.900 3.260 75 0.815 19.560 504.855 2.445 58.680 2540.135 15343.68 7 188000 0.1926 03:30:00 391.50 389.50 1703 4871 33 22.23 910 18 26 38.10 37.661 544.680 Flare 544.680 75 0.1927 04:00:00 392.00 390.00 1742 4857 34 22.23 931 18 26 38.10 38.066 545.469 Flare 545.469 3.400 73 0.918 22.032 505.773 2.482 59.568 2542.617 15341.20 7 188000 0.1928 04:30:00 392.50 390.50 1758 4843 34 22.23 931 18 27 38.10 37.572 546.256 Flare 546.256 73 0.1929 05:00:00 393.00 391.00 1722 4842 34 22.23 938 18 27 38.10 37.704 547.041 Flare 547.041 3.250 74 0.845 20.280 506.618 2.405 57.720 2545.022 15338.80 7 188000 0.1930 05:30:00 393.50 391.50 1695 4836 34 22.23 938 18 27 38.10 37.704 547.826 Flare 547.826 74 0.1931 06:00:00 394.00 392.00 1702 4831 34 22.23 938 18 27 38.10 37.704 548.612 Flare 548.612 3.370 74 0.876 21.029 507.494 2.494 59.851 2547.516 15336.30 7 188000 49.5 0.1932 06:00:00 394.00 392.00 API = 49.5 @ 60°F , Specific Gravity = 0.7818, H2S pull 0ppm.933 06:30:00 394.50 392.50 1737 4816 33 22.23 931 18 27 38.10 37.742 549.397 Flare 549.397 74 0.1934 07:00:00 395.00 393.00 1635 4817 35 22.23 938 18 28 38.10 38.061 550.187 Flare 550.187 3.390 75 0.848 20.340 508.341 2.543 61.020 2550.059 15333.76 7 188000 0.1935 07:30:00 395.50 393.50 1623 4816 36 22.23 938 18 28 38.10 38.061 550.980 Flare 550.980 75 0.1936 08:00:00 396.00 394.00 1622 4824 35 22.23 938 18 28 38.10 38.061 551.773 Flare 551.773 3.420 74 0.889 21.341 509.230 2.531 60.739 2552.590 15331.23 7 188000 0.1937 08:30:00 396.50 394.50 1648 4804 35 22.23 931 18 27 38.10 37.996 552.565 Flare 552.565 74 0.1938 09:00:00 397.00 395.00 1591 4800 36 22.23 931 18 27 38.10 37.742 553.354 Flare 553.354 4.410 72 1.235 29.635 510.465 3.175 76.205 2555.765 15328.06 7 188000 0.1939 09:30:00 397.50 395.50 1520 4799 34 22.23 931 18 28 38.10 37.927 554.142 Flare 554.142 72 0.1940 10:00:00 398.00 396.00 1494 4811 34 22.23 910 18 27 38.10 37.087 554.924 Flare 554.924 4.330 71 1.256 30.137 511.721 3.074 73.783 2558.839 15324.98 7 188000 49.6 0.1941 10:00:00 398.00 396.00 API = 49.6 @ 60°F , Specific Gravity = 0.7812, H2S pull 0ppm.942 10:30:00 398.50 396.50 1611 4802 34 22.23 910 18 27 38.10 36.832 555.694 Flare 555.694 71 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Dale Time Cum Row Tubing
Pres
Well
Owing
Pres
FlowChoke
TempSne
OnficeDryRowMalar
Bshe Dg MIR Piste GasRateCumGas
Pres Pres TempGze
Gas TolalGasRdVd
To Flared
BSWOIGanOilRale OtGum
Rnid
Wstw
Gain
WaterCumloarlLTRPH SalinilyAPI
dume
2
WW)umlddhhmmss
2015HV12110000
113000
39900
39950
39T00
39T50
kPag
1785
1631
kPag
4790
4803
'0 mm
35 2223
35 r'r
kPag kPa '0 mm 1tym'id10'm'10
18 20 3010 37020 556463
910 18 27 XI: 37087 557235
I(pop (I)
m'lare
556463 3870
Ftse 557235
70 1 165
m'Id
27957
m'12
886 2705 64923 2561544 1532220 I IBBXO
'API
01
120000
123000
130000
133000
140000
40000
40050
40100
40150
40200
39800
39850
39900
39950
40000
1605
1638
1609
1679
1660
4797
4811
4791
4791
4786
35 2223
35 r'r35 2223
35 2223
910 18 27 3010 37341 558010
910 18 20 XI: 37273 558788
924 18 20 3010 37793 559569
924 18 20 XI: 37793 560357
924 18 20 3010 37286 561139
Flare 550010 4090
Flse 550788
Flare 559569 4080
Flse 56035T
Flare 561139 4090
70 I 227
70 I 240
68 1 327
29448
29748
31843
514113
515352
516679
2863
2840
2763
60712
60172
66317
2564407 1531941 I
2567248 1531657 I
2570011 1531381 I
IBBXO
IBBXO
IBBXO
01
01
01
951
140000
141500
40200
40225
40000API=496@60'6SpenficGravily=07812H28pullgppm
40025Decreasechokesizeto2137mm (53BI64"dualchokesetup)
957
143000
150000
153000
160000
163000
170000
173000
40250
40300
40350
40400
40450
40500
40550
40050 1709
40100 1754
40150 1592
40200 1661
40250 1740
40300 1505
40350 1703
4901
4833
4822
4797
4780
4792
4796
34 2137
35 2137
33 2137
33 r".
33 2137
803 17
803 17
910 17
910 17
910 17
896 17
910 17
3000
3010
3010
35274 561095Flse 561095
35084 562628Flare 562628
35599 563364Flee 563364
35t92 564108Flare 564108
35792 564053Flee 564053
35534 565596Flare 565596
35792 566339Flee 566339
3700 68
3930 69
4010 68
I 200 28807 517879 2500 59993 2572511 1 5311 31
I 230 29522 519110 2700 64790 2575210 1530861
I 278 X601 520300 2732 65559 2577942 1530580
IBBXO
IBBXO
IBBXO
01
01
01
173500
100000
100000
103000
190000
192500
40558
40600
40600
40650
40700
40742
40358Decreasechokesizeto2003mm (504I64"dualchokesetup)
40400 1658 4836 35 2003 910 16 27 3010 34991 567077Flare567077 3730 6t 1230 29524 521610 2500 59996258044215303307 184XO498 01
40400Apl=498@60'6SpenficGravity=0 7805H28pullgppm
40450 1722 4822 35 I:X 979 16 27 XI: 36784 567024Flee 567024
40500 1741 4816 34 2003 965 16 25 301 0 361 16 568584Flare 560584 3990 68 I 290 X959 522900 2700 64801 2583142 1530060 7 IBOXO 0I
40542DecreasechokesizetoI8 93mm (477I64"dualchokesetup)
193000
200000
203000
210000
213000
40750
40000
40050
40900
40950
40550 1769
40600 1867
40650 1779
40700 1813
40T50 1934
5000
4931
4850
4846
4847
31 1893
33 1893
32 I;cr
33 1893
34 14or
965
965
979
979
965
13 23 XI: 32t09 569300Flare 569300
16 23 3010 36250 570019Flare 570019 3710 6t
16 25 XI:36920 570781Flee 570781
16 26 3010 36295 571544Flare 5715M 3680 68
16 27 XI:35984 572297Flee 57229T
1 210 29036
1 180 28324
524110 2500
525290 2500
60004
59996
25856421529810I
2588142 1529560 I
IBOXO
186000
01
01
9TO 220000 41000 40800 1972 4830 34 1893 979 16 27 3010 36784 573055Flare 573055 3810 68 1 210 29041 526500 2600 62399 2590742 1529300 I IBBXO498 01
9TI 220000
221500
41000
41025
40800Apl=498@60'6SpenficGravity=0 7805H28pullgppm
40825DecreasechokesizetoI826mm(46I64"singlechokesetup)
9T4
9T5
976
223000
230000
233000
2015HV13000000
41050
41100
41150
41200
40850
40900
40950
41000
1927
1982
1960
2003
4865
4852
4855
4862
35 1826
33 1826
34
34 1826
965 16
979 16
970 16
964 16
3010
3010
36469 573018
36784 574581
36151 575340
36044 576092
Fisc 573018
Flare 574581
Ftse 575340
Flare 576092
3880 67
3720 67
1280 X730527789 2600 6239025933411529040
I 236 29668 529025 2404 59612 2595025 1528799
IBBXO
IBBXO
01
01
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAwell248049OWSFlowTestlibggs99
ProdnctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 39
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %943 2015/11/12 11:00:00 399.00 397.00 1785 4798 35 22.23 910 18 28 38.10 37.020 556.463 Flare 556.463 3.870 70 1.165 27.957 512.886 2.705 64.923 2561.544 15322.28 7 188000 0.1944 11:30:00 399.50 397.50 1631 4803 35 22.23 910 18 27 38.10 37.087 557.235 Flare 557.235 70 0.1945 12:00:00 400.00 398.00 1605 4797 35 22.23 910 18 27 38.10 37.341 558.010 Flare 558.010 4.090 70 1.227 29.448 514.113 2.863 68.712 2564.407 15319.41 7 188000 0.1946 12:30:00 400.50 398.50 1638 4811 35 22.23 910 18 28 38.10 37.273 558.788 Flare 558.788 70 0.1947 13:00:00 401.00 399.00 1609 4791 35 22.23 924 18 28 38.10 37.793 559.569 Flare 559.569 4.080 70 1.240 29.748 515.352 2.840 68.172 2567.248 15316.57 7 188000 0.1948 13:30:00 401.50 399.50 1679 4791 34 22.23 924 18 28 38.10 37.793 560.357 Flare 560.357 70 0.1949 14:00:00 402.00 400.00 1660 4786 35 22.23 924 18 28 38.10 37.286 561.139 Flare 561.139 4.090 68 1.327 31.843 516.679 2.763 66.317 2570.011 15313.81 7 188000 0.1950 14:00:00 402.00 400.00 API = 49.6 @ 60°F , Specific Gravity = 0.7812, H2S pull 0ppm.951 14:15:00 402.25 400.25 Decrease choke size to 21.37mm (53.8/64" dual choke setup)952 14:30:00 402.50 400.50 1709 4901 34 21.37 883 17 27 38.10 35.274 561.895 Flare 561.895 68 0.1953 15:00:00 403.00 401.00 1754 4833 35 21.37 883 17 27 38.00 35.084 562.628 Flare 562.628 3.700 68 1.200 28.807 517.879 2.500 59.993 2572.511 15311.31 7 188000 0.1954 15:30:00 403.50 401.50 1592 4822 34 21.37 910 17 27 38.00 35.599 563.364 Flare 563.364 68 0.1955 16:00:00 404.00 402.00 1661 4797 33 21.37 910 17 27 38.10 35.792 564.108 Flare 564.108 3.930 69 1.230 29.522 519.110 2.700 64.798 2575.210 15308.61 7 188000 0.1956 16:30:00 404.50 402.50 1740 4788 33 21.37 910 17 27 38.10 35.792 564.853 Flare 564.853 69 0.1957 17:00:00 405.00 403.00 1505 4792 33 21.37 896 17 27 38.10 35.534 565.596 Flare 565.596 4.010 68 1.278 30.681 520.388 2.732 65.559 2577.942 15305.88 7 188000 0.1958 17:30:00 405.50 403.50 1703 4796 34 21.37 910 17 27 38.10 35.792 566.339 Flare 566.339 68 0.1959 17:35:00 405.58 403.58 Decrease choke size to 20.03mm (50.4/64" dual choke setup)960 18:00:00 406.00 404.00 1658 4836 35 20.03 910 16 27 38.10 34.991 567.077 Flare 567.077 3.730 67 1.230 29.524 521.618 2.500 59.996 2580.442 15303.38 7 184000 49.8 0.1961 18:00:00 406.00 404.00 API = 49.8 @ 60°F , Specific Gravity = 0.7805, H2S pull 0ppm.962 18:30:00 406.50 404.50 1722 4822 35 20.03 979 16 27 38.10 36.784 567.824 Flare 567.824 67 0.1963 19:00:00 407.00 405.00 1741 4816 34 20.03 965 16 25 38.10 36.116 568.584 Flare 568.584 3.990 68 1.290 30.959 522.908 2.700 64.801 2583.142 15300.68 7 180000 0.1964 19:25:00 407.42 405.42 Decrease choke size to 18.93mm (47.7/64" dual choke setup)965 19:30:00 407.50 405.50 1769 5008 31 18.93 965 13 23 38.10 32.709 569.300 Flare 569.300 68 0.1966 20:00:00 408.00 406.00 1867 4931 33 18.93 965 16 23 38.10 36.250 570.019 Flare 570.019 3.710 67 1.210 29.036 524.118 2.500 60.004 2585.642 15298.18 7 180000 0.1967 20:30:00 408.50 406.50 1779 4850 32 18.93 979 16 25 38.10 36.920 570.781 Flare 570.781 67 0.1968 21:00:00 409.00 407.00 1813 4846 33 18.93 979 16 26 38.10 36.295 571.544 Flare 571.544 3.680 68 1.180 28.324 525.298 2.500 59.996 2588.142 15295.68 7 186000 0.1969 21:30:00 409.50 407.50 1934 4847 34 18.93 965 16 27 38.10 35.984 572.297 Flare 572.297 68 0.1970 22:00:00 410.00 408.00 1972 4838 34 18.93 979 16 27 38.10 36.784 573.055 Flare 573.055 3.810 68 1.210 29.041 526.508 2.600 62.399 2590.742 15293.08 7 188000 49.8 0.1971 22:00:00 410.00 408.00 API = 49.8 @ 60°F , Specific Gravity = 0.7805, H2S pull 0ppm.972 22:15:00 410.25 408.25 Decrease choke size to 18.26mm (46/64" single choke setup)973 22:30:00 410.50 408.50 1927 4865 35 18.26 965 16 28 38.10 36.469 573.818 Flare 573.818 68 0.1974 23:00:00 411.00 409.00 1982 4852 33 18.26 979 16 27 38.10 36.784 574.581 Flare 574.581 3.880 67 1.280 30.730 527.789 2.600 62.390 2593.341 15290.48 7 188000 0.1975 23:30:00 411.50 409.50 1960 4855 34 18.26 970 16 27 38.10 36.151 575.340 Flare 575.340 67 0.1976 2015/11/13 00:00:00 412.00 410.00 2003 4862 34 18.26 964 16 27 38.10 36.044 576.092 Flare 576.092 3.720 67 1.236 29.668 529.025 2.484 59.612 2595.825 15287.99 7 188000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
TubingOwingFlowChoke
Pres Pres TempSae
OnficeDryRowMelar
Dg MIR Plate GasRate
Pres TempWze
DataSummary
CumGasGas TolalGasRdVd
To Flared
BSWOIGanOilRale 01Cum
Rnid
Watw
Gain
WaterGumleadLTRPH SalinilyAPI
dume
2
WWlamldd
977 2015HV13
hhmmss
000000 41200 41000
kPag kPag '0 mm
0000Irmmsdir10
kPa '0 mm 1tym'id ftpup (ljm''Idm'pm'API
FlowingTubmgpressure=2003kPa
ShutmCasingpressure=4862kPa
Flowingtemperature=34'0
Chokesize= 46I64"(1826mmi
GasRate=3816IOVP
Totalguidrate=372m'Ihr
Waterrecoveryrate=248m'Ihr
Condensaterate= 124m'Ihr
PH=T,Salinity=IBBXOppmBSSW=BTS
API=498@60'F,Separator=964kPagH'S=0 ppmSand=01%
Dailyhrsgowed=24hrs
Cumhrsflowed=410hrs
Dailygasproduced10flarelast24hrs=36921tPm'um
gasProducedtoflare=57609210VP
CondProducedlast24hrs= 2674m'um
CondProduced=52902m'ater
Recoveredlast24Hrs=6314
m'otal
WaterRecovered=259583
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLefttoRecover= 1528799
m'ercentageRecoveredfromInmalLoad=1451 'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
978 003000
010000
013000
41250
41300
41350
41050
41100
41150
1930 4852
1932 4833
1923 4854
33 1825 965
33 1826 965
33 1825 965
Jc I
'810
Jc I
'5984
35984
35984
576843Flee
577592Flare
578342Flse
576043
5TI592
570342
3660 68 1160 27836 530185 2500 6000425983251528549I IBBXO 01
020000 41400 41200 1873 4840 34 1826 965 3810 35423 579086Flare 579086 3850 68 1 220 29282 531405 2630 63118 2600955 1528286 I IBBXO491 0I
020000
023000
41400
41450
41200
41250
API=491@60'FSpeaficGravity=0 7837H26pull0ppm
33 1825 965 15 26 XI:35488 579825Flee 5790251940 4836
030000
033000
033000
41500
41550
41550
41300
41350
41350
34 1 826 965 16 27 381 0 35984 580569Flare 580569 3840 68 I 240 29758 532645 2600 62402 2603555 1528026 I IBBXO 0I1923 4852
1911 4884 34 1825 979 16 27 XI: 36228 581321Flse 581321
1746mm(44I64"singlechokesetup)okesizetoDecreasech
040000
043000
050000
053000
060000
41600
41650
41700
41750
41800
41400
41450
41500
41550
41600
1931 4957
2099 4957
2178 4954
2238 4944
2201 4945
34 1746
32
33 1746
33
33 1746
896 14 26 3810 33148 582044
965 15 26 XI: 34917 582753
945 15 26 3810 34842 583480
951 15 27 XI: 34899 584206
951 15 26 3810 34678 584931
Flare
Ftse
Flare
Ftse
Flare
582044 3560
582753
583480 3740
584206
584931 3300
67 1 160
67 1 240
67 1 100
27836
26397
533IC4
535045
536144
2400 57604
2500 59996
2200 52803
2605956
2608455
2610656
1527786
1527536
1527316
IBBXO
IBBXO
IBBXO
01
01
502 01
060000 41800 41600Apl=502@ aficGravity=0 7789H26pull0ppm60'FSpe
063000
070000
070500
41850
41900
41908
41650
41700
41708
2245 4950 33 I li 951 15 26 XI:34678 585653Flee 585653
2156 4950 35 I746 951 15 26 381 0 34678 586376Flare 586376 3970 68 I 270 X480 537414 2700 64800 2613356 1527046 I IBBXO 0I
I6 67mm (42I64"singlechokesetup)okesizetoDecreasech
073000
080000
083000
090000
41950
42000
42050
42100
41750
41800
41850
41900
1971 4908
2162 4905
2094 4908
2132 4903
34 1667 951
35 166 951
35 166 951
34 166 951
Jc I
'810
Jc I'c
I
'4678
34101
34678
31101
587098Flee 587098
587815Flare 587015
588531Flee 580531
589248Flee 589248
3420 67
3720 67
1 120 26881 538534 2300
1 220 29284 539755 2500
55199 2615656
59996 2618155
1526816 I IBBXO
1526566
01
IXI
091500
093000
42125
42150
41925
41950
DecreasechokesizetoI588mm(40I64"singlechokesetup)
2035 4995 34 1 588 965 12 26 XI: 31262 589928Flee 589928
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIMG,.IAweD24864IOWSFlowTestlhggn((((
ProductiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 40
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %977 2015/11/13 00:00:00 412.00 410.00 00:00 hrs reading
Flowing Tubing pressure = 2003 kPaShut in Casing pressure = 4862 kPaFlowing temperature = 34°CChoke size = 46/64" (18.26mm)Gas Rate = 38.16 10³m³Total fluid rate = 3.72 m³/hrWater recovery rate = 2.48 m³/hrCondensate rate = 1.24 m³/hrPH =7 , Salinity = 188000 ppm, BS&W = 67 %API = 49.8 @ 60°F, Separator = 964 kPag H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 410 hrsDaily gas produced t0 flare last 24 hrs = 36.92 10³m³Cum gas Produced to flare= 576.092 10³m³Cond Produced last 24 hrs = 26.74 m³Cum Cond Produced = 529.02 m³Water Recovered Last 24 Hrs = 63.14 m³Total Water Recovered = 2595.83 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15287.99 m³ Percentage Recovered from Initial Load = 14.51 %Chokes washed in 24 hours=0Total chokes washed =0
978 00:30:00 412.50 410.50 1930 4852 33 18.26 965 16 27 38.10 35.984 576.843 Flare 576.843 67 0.1979 01:00:00 413.00 411.00 1932 4833 33 18.26 965 16 27 38.10 35.984 577.592 Flare 577.592 3.660 68 1.160 27.836 530.185 2.500 60.004 2598.325 15285.49 7 188000 0.1980 01:30:00 413.50 411.50 1923 4854 33 18.26 965 16 27 38.10 35.984 578.342 Flare 578.342 68 0.1981 02:00:00 414.00 412.00 1873 4840 34 18.26 965 15 27 38.10 35.423 579.086 Flare 579.086 3.850 68 1.220 29.282 531.405 2.630 63.118 2600.955 15282.86 7 188000 49.1 0.1982 02:00:00 414.00 412.00 API = 49.1 @ 60°F , Specific Gravity = 0.7837, H2S pull 0ppm.983 02:30:00 414.50 412.50 1940 4836 33 18.26 965 15 26 38.10 35.488 579.825 Flare 579.825 68 0.1984 03:00:00 415.00 413.00 1923 4852 34 18.26 965 16 27 38.10 35.984 580.569 Flare 580.569 3.840 68 1.240 29.758 532.645 2.600 62.402 2603.555 15280.26 7 188000 0.1985 03:30:00 415.50 413.50 1911 4884 34 18.26 979 16 27 38.10 36.228 581.321 Flare 581.321 68 0.1986 03:30:00 415.50 413.50 Decrease choke size to 17.46mm (44/64" single choke setup)987 04:00:00 416.00 414.00 1931 4957 34 17.46 896 14 26 38.10 33.148 582.044 Flare 582.044 3.560 67 1.160 27.836 533.804 2.400 57.604 2605.956 15277.86 7 188000 0.1988 04:30:00 416.50 414.50 2099 4957 32 17.46 965 15 26 38.10 34.917 582.753 Flare 582.753 67 0.1989 05:00:00 417.00 415.00 2178 4954 33 17.46 945 15 26 38.10 34.842 583.480 Flare 583.480 3.740 67 1.240 29.764 535.045 2.500 59.996 2608.455 15275.36 7 188000 0.1990 05:30:00 417.50 415.50 2238 4944 33 17.46 951 15 27 38.10 34.899 584.206 Flare 584.206 67 0.1991 06:00:00 418.00 416.00 2201 4945 33 17.46 951 15 26 38.10 34.678 584.931 Flare 584.931 3.300 67 1.100 26.397 536.144 2.200 52.803 2610.656 15273.16 7 188000 50.2 0.1992 06:00:00 418.00 416.00 API = 50.2 @ 60°F , Specific Gravity = 0.7789, H2S pull 0ppm.993 06:30:00 418.50 416.50 2245 4950 33 17.46 951 15 26 38.10 34.678 585.653 Flare 585.653 67 0.1994 07:00:00 419.00 417.00 2156 4950 35 17.46 951 15 26 38.10 34.678 586.376 Flare 586.376 3.970 68 1.270 30.480 537.414 2.700 64.800 2613.356 15270.46 7 188000 0.1995 07:05:00 419.08 417.08 Decrease choke size to 16.67mm (42/64" single choke setup)996 07:30:00 419.50 417.50 1971 4908 34 16.67 951 15 26 38.10 34.678 587.098 Flare 587.098 68 0.1997 08:00:00 420.00 418.00 2162 4905 35 16.67 951 14 26 38.10 34.101 587.815 Flare 587.815 3.420 67 1.120 26.881 538.534 2.300 55.199 2615.656 15268.16 7 188000 0.1998 08:30:00 420.50 418.50 2094 4908 35 16.67 951 15 26 38.10 34.678 588.531 Flare 588.531 67 0.1999 09:00:00 421.00 419.00 2132 4903 34 16.67 951 14 26 38.10 34.101 589.248 Flare 589.248 3.720 67 1.220 29.284 539.755 2.500 59.996 2618.155 15265.66 0.1
1000 09:15:00 421.25 419.25 Decrease choke size to 15.88mm (40/64" single choke setup)1001 09:30:00 421.50 419.50 2035 4995 34 15.88 965 12 26 38.10 31.262 589.928 Flare 589.928 67 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeOryRowMalar Rnid dume
2
Time Cum Row Tubing
Pres
CmingFlow
Pres Temp
Qmks
$ns
Og MIR
Pres Temp
CumGas Gas TolalGasRdVd
To Flared
BSWOIGanOilRale 08Cum Wstw WsMr
Gain Rate
WaterGumleadLTRPH SalinilyAPI
WW(umfdd
2015HV13
hhmmss
100000 42200 42000
kPag
2101
kPag '0
5061 34
mm
951
kPa '0
12 26
mm 1tym'id
3810 31368 590581
I(pop(ljm'lare
590581 3470
m''Id66 1 170 28082
m'40
925 2300 55198 2620455 1526336 7 IBBXO
'API
499 01
100000 42200 42000 oficG60'FSpe1=499@ ravily07799H2$pulllppm
ID07
IDIO
1011
103000
110000
113000
120000
123000
130000
133000
140000
42250
42300
42350
42400
42450
42500
42550
42600
42050
42100
42150
42200
42250
42300
42350
42400
2185
2379
2416
2264
2332
2165
2065
2303
5100 34
5129 34
5121 34
5148 34
5147 35
5151 35
5141
5136 34
1585
1585
1585
1585
972
979
979
993
1020
1020
1020
1020
12 26
12 26
12 26
12 26
12 27
12 27
12 26
12 27
31691
381 0 321 18
31798
3810 32011
32699
3810 32373
32433
3810 32373
591238
591902
592568
593233
593907
594585
595260
595935
Ftse 591238
Flare 591902 3460
Ftse 592568
Flare 593233 3 180
Ftse 59390T
Flare 594585 3620
Ftse 595260
Flare 595935 3490
66 1160 27843
66 I 080 25926
66 1 220 29287
65 1 225 29400
542085
543165
544385
545610
2300 55197
2 100 50394
2400 57593
2265 54360
2622755 1526106
2624855 1525097
2627255 1525657
2629520 1525430
7 IBBXO
7 IBBXO
7 IBBXO
7 IBBXO499
01
01
01
01
ID12 140000 42600 42400 oficG60'FSpe1=499@ ravily07799H2$pulllppm
ID13
ID14
ID15
ID16
ID17
143000
150000
153000
160000
163000
42650
42700
42750
42800
42850
42450
42500
42550
42600
42650
1938
2221
2439
2176
1864
5160 33
5179 34
5156 34
5161 33
5086 32
1585
15 85
1585
1007
1020
1020
1007
1007
12 27
12 27
11 27
12 26
12 25
31836
3810 32044
31375
3810 31895
32282
596604
597269
597930
598589
599257
Flse 596604
Flare 597269 3 130
Ftse 597930
Flare 590589 3310
Flse 59925T
67 I 030 24722
66 1 110 26644
546641
547751
2 100 50398
2200 52796
2631619 1525220
2633819 1525000
7 IBBXO
7 IBBXO
01
01
IDIB
ID19
ID20
ID21
ID22
ID23
163500
170000
171500
173000
180000
180000
42858
42900
42925
42950
43000
43000
42658Decreasechokesizeto1349mm(34(64"singlechokesetup)
42700 1680 5125 33 1 349 1000 II 25 381 0 31184 599918Flare 599918 3600 6t I 200 28806 548951 2400 57594 2636219 1524760 7 IBBXO 0I
42725DecreaseonficeplatesizetoI 25(3175mmi
42T50 1883 5229 33 13ll 862 25 25 3175 29364 600549Flee 6X549
42800DecreasechokesizetoII91mm (30(64"singlechokesetup)
42800 2515 5354 35 II 91 931 22 25 3175 28668 6011 54Flare 601154 3040 66 I 040 2496t 549991 2000 47993 2630219 1524560 7 IBBXO504 0I
ID24 180000 43000 42800 60'FSpeoficGravity=0 7780H2$pull0ppmApl=504@
ID25
ID26
ID27
ID28
ID29
IDX
ID31
ID32
183000
190000
193000
200000
203000
210000
213000
220000
43050
43100
43150
43200
43250
43300
43350
43400
42850
42900
42950
43000
43050
43100
43150
43200
2322
2741
2801
2845
2903
2860
2929
2959
5491 33 I c
5559 32 1191
5576 31 I c
5602 32 1191
5607 31 I c
5634 30 1191
5627 30 I c
5659 31 1191
951
945
951
965
993
1007
993
1007
22 22
21 22
21 24
21 23
21 23
21 22
20 21
20 22
28902
3175 28638
28467
3175 28883
29108
3175 29186
28530
3175 28841
601753
602353
602947
603545
604149
604756
605357
605955
Ftse 601753
Flare 602353 2980
Ftse 60294T
Flare 603545 2450
Flee 604149
Flare 604756 2650
Ftse 60535T
Flare 605955 2640
64 I 080 25919
65 0850 20398
64 0950 22801
64 0940 22562
551071
551921
552871
553611
1 900 45601
1600 38402
1700 40799
1 700 40798
2640119
2641719
2643419
2645119
1524370
1524210
1524040
1523070
7 IBBXO
7 IBBXO
7 IBBXO
7 IBBXO502
01
01
01
01
ID33 220000 43400 43200 60'FSpeoficGravity1=502@ 07786H2$pulllppm
ID34
ID35
ID36
ID372015MV14
223000
230000
233000
000000
43450
43500
43550
43600
43250
43300
43350
43400
2999
3011
3005
2998
5667 31 I c
5675 31 1191
5625 31 I c
5672 30 1191
986
1000
986
993
20 22
20 22
21 22
20 22
28302
3175 28745
28725
3175 28650
606551
607146
607745
608342
Flse 606551
Flare 607146 2800
Ftse 607745
Flare 600342 2660
64 I 000 23997
64 0960 23040
554811
555771
1800 43203
1700 40800
2646919
2648619
1523690
1523520
7 IBBXO
7 IBBXO
01
01
PetroClassFlowTestVersion4.5.D.5
0:iDOLLCOWELLDATASUSAMIOOLLCOWELLDATASERVICESIPROOUCTIOMTESTIMG,.IAweg24864IOWBFlowTestldtggn(l(
ProdnctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 41
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %1002 2015/11/13 10:00:00 422.00 420.00 2101 5061 34 15.88 951 12 26 38.10 31.368 590.581 Flare 590.581 3.470 66 1.170 28.082 540.925 2.300 55.198 2620.455 15263.36 7 188000 49.9 0.11003 10:00:00 422.00 420.00 API = 49.9 @ 60°F , Specific Gravity = 0.7799, H2S pull 0ppm.1004 10:30:00 422.50 420.50 2185 5100 34 15.88 972 12 26 38.10 31.691 591.238 Flare 591.238 66 0.11005 11:00:00 423.00 421.00 2379 5129 34 15.88 979 12 26 38.10 32.118 591.902 Flare 591.902 3.460 66 1.160 27.843 542.085 2.300 55.197 2622.755 15261.06 7 188000 0.11006 11:30:00 423.50 421.50 2416 5121 34 15.88 979 12 26 38.10 31.798 592.568 Flare 592.568 66 0.11007 12:00:00 424.00 422.00 2264 5148 34 15.88 993 12 26 38.10 32.011 593.233 Flare 593.233 3.180 66 1.080 25.926 543.165 2.100 50.394 2624.855 15258.97 7 188000 0.11008 12:30:00 424.50 422.50 2332 5147 35 15.88 1020 12 27 38.10 32.699 593.907 Flare 593.907 66 0.11009 13:00:00 425.00 423.00 2165 5151 35 15.88 1020 12 27 38.10 32.373 594.585 Flare 594.585 3.620 66 1.220 29.287 544.385 2.400 57.593 2627.255 15256.57 7 188000 0.11010 13:30:00 425.50 423.50 2065 5141 34 15.88 1020 12 26 38.10 32.433 595.260 Flare 595.260 66 0.11011 14:00:00 426.00 424.00 2303 5136 34 15.88 1020 12 27 38.10 32.373 595.935 Flare 595.935 3.490 65 1.225 29.400 545.610 2.265 54.360 2629.520 15254.30 7 188000 49.9 0.11012 14:00:00 426.00 424.00 API = 49.9 @ 60°F , Specific Gravity = 0.7799, H2S pull 0ppm.1013 14:30:00 426.50 424.50 1938 5160 33 15.88 1007 12 27 38.10 31.836 596.604 Flare 596.604 65 0.11014 15:00:00 427.00 425.00 2221 5179 34 15.88 1020 12 27 38.10 32.044 597.269 Flare 597.269 3.130 67 1.030 24.722 546.641 2.100 50.398 2631.619 15252.20 7 188000 0.11015 15:30:00 427.50 425.50 2439 5156 34 15.88 1020 11 27 38.10 31.375 597.930 Flare 597.930 67 0.11016 16:00:00 428.00 426.00 2176 5161 33 15.88 1007 12 26 38.10 31.895 598.589 Flare 598.589 3.310 66 1.110 26.644 547.751 2.200 52.796 2633.819 15250.00 7 188000 0.11017 16:30:00 428.50 426.50 1864 5086 32 15.88 1007 12 25 38.10 32.282 599.257 Flare 599.257 66 0.11018 16:35:00 428.58 426.58 Decrease choke size to 13.49mm (34/64" single choke setup)1019 17:00:00 429.00 427.00 1680 5125 33 13.49 1000 11 25 38.10 31.184 599.918 Flare 599.918 3.600 67 1.200 28.806 548.951 2.400 57.594 2636.219 15247.60 7 188000 0.11020 17:15:00 429.25 427.25 Decrease orifice plate size to 1.25' (31.75mm)1021 17:30:00 429.50 427.50 1883 5229 33 13.49 862 25 25 31.75 29.364 600.549 Flare 600.549 67 0.11022 18:00:00 430.00 428.00 Decrease choke size to 11.91mm (30/64" single choke setup)1023 18:00:00 430.00 428.00 2515 5354 35 11.91 931 22 25 31.75 28.668 601.154 Flare 601.154 3.040 66 1.040 24.967 549.991 2.000 47.993 2638.219 15245.60 7 188000 50.4 0.11024 18:00:00 430.00 428.00 API = 50.4 @ 60°F , Specific Gravity = 0.7780, H2S pull 0ppm.1025 18:30:00 430.50 428.50 2322 5491 33 11.91 951 22 22 31.75 28.902 601.753 Flare 601.753 66 0.11026 19:00:00 431.00 429.00 2741 5559 32 11.91 945 21 22 31.75 28.638 602.353 Flare 602.353 2.980 64 1.080 25.919 551.071 1.900 45.601 2640.119 15243.70 7 188000 0.11027 19:30:00 431.50 429.50 2801 5576 31 11.91 951 21 24 31.75 28.467 602.947 Flare 602.947 64 0.11028 20:00:00 432.00 430.00 2845 5602 32 11.91 965 21 23 31.75 28.883 603.545 Flare 603.545 2.450 65 0.850 20.398 551.921 1.600 38.402 2641.719 15242.10 7 188000 0.11029 20:30:00 432.50 430.50 2903 5607 31 11.91 993 21 23 31.75 29.108 604.149 Flare 604.149 65 0.11030 21:00:00 433.00 431.00 2860 5634 30 11.91 1007 21 22 31.75 29.186 604.756 Flare 604.756 2.650 64 0.950 22.801 552.871 1.700 40.799 2643.419 15240.40 7 188000 0.11031 21:30:00 433.50 431.50 2929 5627 30 11.91 993 20 21 31.75 28.530 605.357 Flare 605.357 64 0.11032 22:00:00 434.00 432.00 2959 5659 31 11.91 1007 20 22 31.75 28.841 605.955 Flare 605.955 2.640 64 0.940 22.562 553.811 1.700 40.798 2645.119 15238.70 7 188000 50.2 0.11033 22:00:00 434.00 432.00 API = 50.2 @ 60°F , Specific Gravity = 0.7786, H2S pull 0ppm.1034 22:30:00 434.50 432.50 2999 5667 31 11.91 986 20 22 31.75 28.382 606.551 Flare 606.551 64 0.11035 23:00:00 435.00 433.00 3011 5675 31 11.91 1000 20 22 31.75 28.745 607.146 Flare 607.146 2.800 64 1.000 23.997 554.811 1.800 43.203 2646.919 15236.90 7 188000 0.11036 23:30:00 435.50 433.50 3005 5625 31 11.91 986 21 22 31.75 28.725 607.745 Flare 607.745 64 0.11037 2015/11/14 00:00:00 436.00 434.00 2998 5672 30 11.91 993 20 22 31.75 28.650 608.342 Flare 608.342 2.660 64 0.960 23.040 555.771 1.700 40.800 2648.619 15235.20 7 188000 0.1
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Time Cum Row
Well
TubingOwing
Pres Pres
FlowChokeGabe
TempSne Pres
Dg
Pres
DnficeDryRowMelar
MIR
Temp
CumGas Gas TotalGas
To Flared
Rnid
RdVdBSWWIGanOiIRaleOICumWater
Gain
WaterWaterGum
IMM
inertLTR
dume
2
PH SalinilyAPI Smd
CM
1038
WW)amfdd
2015)IV14
hhmmss
000000 43600 43400
kPag kPag
0000Irmmsdir10
'0 mm kPart mm 1tym'id (I)m' m''Idm'pm'API
FlowingTubmgpressure=2998kPa
ShutmCasingpressure=5672kPa
Flowingtemperature=3tl'0
Chokesize= 30)64"(1191mm)
GasRate= 3032ltPm'otal
guidrate=266m'Ihr
Waterrecoveryrate=I 70m'Ihr
Condensaterate=096m'Ihr
PH=T,Salinity=188XOppmBSSW=64S
API=502@60'F,Separator=993kPagH'S=0 ppmSand=01%
Dailyhrsgowed=24hrs
Cumhrsflowed=434hrs
Dailygasproduced10flarelast24hrs=32251tPm'um
gasProducedtoflare=60834210VP
CondProducedlast24hrs= 2675m'um
CondProduced=55577m'ater
Recoveredlast24Hrs=5279m'otal
WaterRecovered=264862
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLetttoRecover= 1523520
m'ercentageRecoveredfromInmalLoad=1481 'I
Chokeswashedin24bourn=g
Totalchokeswashed=0
1039
1042
003000
010000
013000
020000
43650
43700
43750
43800
43450
43500
43550
43600
2998 5655
2866 5697
2934 5699
2802 5705
I G
1191
I G
1191
979
965
972
965
21 Jl
22 3175
22 Jl
21 3175
28339
27923
28190
27975
608936Flee 608936
609522Flare 609522 2980
610107Ftae 61010T
610692Flare 610692 2770
I 080
0970
25919
23281
556851
557821
1900
1800
45601 2650519 1523330
43199 2652319 1523150
188XO
188XO
01
504 01
020000 43800 43600Apl=504@ oficGravity=0 7780H28pull0ppm60'FSpe
023000
030000
43850
43900
43650
43T00
2656 5752
2576 5767
31 I c 972 20 21;I5 27897 611274Fhe 611274
31 II 91 965 20 21 3175 27975 611 856Flare 611 856 2660 64 0960 23040 558781 1 700 40800 2654019 1522980 7 I88XO 0I
1@7
1050
1051
1052
1053
1054
1055
1056
1057
1058
10%
IXI
1062
030000
033000
040000
040000
043000
050000
050000
053000
060000
060000
060000
063000
070000
073000
075000
080000
083000
43900
43950
44000
44000
44050
44100
44100
44150
44200
44200
44200
44250
44300
44350
44383
44400
44450
43T00
43T50
43800
43800
43850
43900
43900
43950
44000
44000
44000
44050
44100
44150
44183
44200
44250
Increasechokesneto1349mm (34(64"smglechokesetup)
2968 5749 31 1 349 1103 22 21 31'5
31 101 612471Flee 612471
2528 5570 31 1 349 1089 22 22 3175 31027 6131 18Flare 613118 3 120 64 I 1 20 26882 559901 2000 47998 2656019 1522780 7 I88XO 0I
Increasechokesueto15Sgmm(40(64"smglechokesetup)
1962 5310 32 1588 1234 24 24 31'5 34648 613802Flae613802
1982 5211 33 1 588 1255 24 26 3175 34624 614524Flare 614524 3680 65 I 280 X718 561181 2400 57602 2658419 1522540 7 IBBXO 0I
Increasechokesneto1826mm(46)64"singlechokesetup)
1880 5153 33 1 826 1262 28 26 31'5 37106 615271Flee 615271
1825 5107 33 1826 1269 28 26 3175 37535 616049Flare616049 3720 65 1294 31052 562475 2426 58228266084515222977 188XO502 01
Apl=502@60'FSpeoficGravily=07786H28pullgppm
Decreasechokesizeto1191mm(30)64"singlechokesetup)
2729 5311 33 1191 834 30 21 31'5
31980 616773Flee 616773
2692 5558 33 I 1'03 18 21 3175 25728 617374Flare617374 3520 65 1220 29281 563695 2300 55199266314515220677 188XO 01
2888 5679 33 I c 931 18 21 ;I , 26099 617914Fhe 617914
DecreasechokesizetoII 11mm (28)64"singlechokesetup)
2841 5761 32 II II 841 17 21 3175 24183 618437Flee 61843T 2820 64 I 020 24487 564715 1 800 43193 2664945 1521888 7 I88XO 00
2969 5860 32 I '93 15 20 31'5
22514 618924Flee 618924
PetroClassFlowTestVersion4.5.0.5
0:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTIMG,.IAweB24864IIWSFlowTestlibggnl)2
ProdnctiontestingASchlumbergerOempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 42
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %1038 2015/11/14 00:00:00 436.00 434.00 00:00 hrs reading
Flowing Tubing pressure = 2998 kPaShut in Casing pressure = 5672 kPaFlowing temperature = 30°CChoke size = 30/64" (11.91mm)Gas Rate = 30.32 10³m³Total fluid rate = 2.66 m³/hrWater recovery rate = 1.70 m³/hrCondensate rate = 0.96 m³/hrPH =7 , Salinity = 188000 ppm, BS&W = 64 %API = 50.2 @ 60°F, Separator = 993 kPag H²S = 0 ppm, Sand =0.1 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 434 hrsDaily gas produced t0 flare last 24 hrs = 32.25 10³m³Cum gas Produced to flare= 608.342 10³m³Cond Produced last 24 hrs = 26.75 m³Cum Cond Produced = 555.77 m³Water Recovered Last 24 Hrs = 52.79 m³Total Water Recovered = 2648.62 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15235.20 m³ Percentage Recovered from Initial Load = 14.81 %Chokes washed in 24 hours=0Total chokes washed =0
1039 00:30:00 436.50 434.50 2998 5655 31 11.91 979 20 21 31.75 28.339 608.936 Flare 608.936 64 0.11040 01:00:00 437.00 435.00 2866 5697 31 11.91 965 20 22 31.75 27.923 609.522 Flare 609.522 2.980 64 1.080 25.919 556.851 1.900 45.601 2650.519 15233.30 7 188000 0.11041 01:30:00 437.50 435.50 2934 5699 30 11.91 972 20 22 31.75 28.190 610.107 Flare 610.107 64 0.11042 02:00:00 438.00 436.00 2802 5705 31 11.91 965 20 21 31.75 27.975 610.692 Flare 610.692 2.770 65 0.970 23.281 557.821 1.800 43.199 2652.319 15231.50 7 188000 50.4 0.11043 02:00:00 438.00 436.00 API = 50.4 @ 60°F , Specific Gravity = 0.7780, H2S pull 0ppm.1044 02:30:00 438.50 436.50 2656 5752 31 11.91 972 20 21 31.75 27.897 611.274 Flare 611.274 65 0.11045 03:00:00 439.00 437.00 2576 5767 31 11.91 965 20 21 31.75 27.975 611.856 Flare 611.856 2.660 64 0.960 23.040 558.781 1.700 40.800 2654.019 15229.80 7 188000 0.11046 03:00:00 439.00 437.00 Increase choke size to 13.49mm (34/64" single choke setup)1047 03:30:00 439.50 437.50 2968 5749 31 13.49 1103 22 21 31.75 31.101 612.471 Flare 612.471 64 0.11048 04:00:00 440.00 438.00 2528 5570 31 13.49 1089 22 22 31.75 31.027 613.118 Flare 613.118 3.120 64 1.120 26.882 559.901 2.000 47.998 2656.019 15227.80 7 188000 0.11049 04:00:00 440.00 438.00 Increase choke size to 15.88mm (40/64" single choke setup)1050 04:30:00 440.50 438.50 1962 5310 32 15.88 1234 24 24 31.75 34.648 613.802 Flare 613.802 64 0.11051 05:00:00 441.00 439.00 1982 5211 33 15.88 1255 24 26 31.75 34.624 614.524 Flare 614.524 3.680 65 1.280 30.718 561.181 2.400 57.602 2658.419 15225.40 7 188000 0.11052 05:00:00 441.00 439.00 Increase choke size to 18.26 mm (46/64" single choke setup)1053 05:30:00 441.50 439.50 1880 5153 33 18.26 1262 28 26 31.75 37.106 615.271 Flare 615.271 65 0.11054 06:00:00 442.00 440.00 1825 5107 33 18.26 1269 28 26 31.75 37.535 616.049 Flare 616.049 3.720 65 1.294 31.052 562.475 2.426 58.228 2660.845 15222.97 7 188000 50.2 0.11055 06:00:00 442.00 440.00 API = 50.2 @ 60°F , Specific Gravity = 0.7786, H2S pull 0ppm.1056 06:00:00 442.00 440.00 Decrease choke size to 11.91mm (30/64" single choke setup)1057 06:30:00 442.50 440.50 2729 5311 33 11.91 834 30 21 31.75 31.980 616.773 Flare 616.773 65 0.11058 07:00:00 443.00 441.00 2692 5558 33 11.91 903 18 21 31.75 25.728 617.374 Flare 617.374 3.520 65 1.220 29.281 563.695 2.300 55.199 2663.145 15220.67 7 188000 0.11059 07:30:00 443.50 441.50 2888 5679 33 11.91 931 18 21 31.75 26.099 617.914 Flare 617.914 65 0.11060 07:50:00 443.83 441.83 Decrease choke size to 11.11mm (28/64" single choke setup)1061 08:00:00 444.00 442.00 2841 5761 32 11.11 841 17 21 31.75 24.183 618.437 Flare 618.437 2.820 64 1.020 24.487 564.715 1.800 43.193 2664.945 15218.88 7 188000 0.01062 08:30:00 444.50 442.50 2969 5860 32 11.11 793 15 20 31.75 22.514 618.924 Flare 618.924 64 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
FLOWTESTDATATestlime Well OnficeDryRowMalar
TotalGas
Flared
RdVdCumGas Gas
To
MIR Piste GasRats
TempGze
Tubing0 ming
Pres Pres
Time Cum Row FlowChokeBshe
TempSns Pres
Dg
Pres
'0 mm yPag '0 mm 1tym'idhhmmssWWlnmldd Hrs Hrs kPag kPag ii)m'0%
2015IIV14 2988 5928 20 3175 24508 6194144450044300090000 31 1111 862 619414Flare 2220
20 31'5 25327
20 3175 24964
619933Flse
620457Flare
4455044350
4460044400
4460044400
2976 5958
3030 5999
61993331 I '9631 11 11 883
oficGravily=07780H
093000
62045T 2760100000
60'FSpe891=504@ 26pull0100000 ppm
620985FlseID67 3212 6025 62098520 31'5 2578731 I '31103000 44650 44450
4470044500 3050 6030 20 3175 24508 621509 1 940110000 31 1111 862 621509Flare
622032Frse
622559Flare
3211 6044
3090 6038
62203220 31'5 25695
21 3175 24921
31 I '2431 11 11 896
113000 4475044550
4480044600IDTO 622559120000 2100
21 31'5
24921
21 3175 25738
21 31'5 25101
623079Frse
623606Flare
624136Flse
IDTI 4485044650
4490044700
4495044750
3063 6042
2878 6056
2945 6079
62307932 I '9631 11 11 931
30 I '96
123000
IDT2 623606 2840130000
IDT3 624136133000
IDT4 4500044800 3036 6105 30 11 11 883 21 3175 24738 624655140000 624655Flare 2540
60'FSpe891=502@ oficGravily=07786H
30 I '8330 11 11 896
IDT5 4500044800
4505044850
45100 44900
26pull0140000 ppm
ID76 3103 6010
3010 6115
62517022 31'5
24692
21 3175 25101
625170Frse
625689Flare
143000
ID77 625689 2380150000
31 I '83 626207FranIDTB 45150 44950 2969 6107 62620T22 31'5
24692153000
IDT9 4520045000
4525045050
4530045100
4535045150
3063 6116
3097 6127
2994 6117
3026 6125
21 3175 25101
21 31'5
24738
21 3175 25464
21 31'5 25101
626726Flare
627245Frse
627768Flare
628295Frse
626726160000 31 11 11 896
32 I '8332 11 11 910
31 I '96
2500
627245163000
1%1 627768170000 2510
628295173000
45400 45200 3062 6139 21 3175 24284 628809180000 32 11 11 862 628809Flare 2400
60'FSpeAPI=499@ oficGravily=07799H
33 I '9633 11 11 869
4540045200
4545045250
4550045300
26pull0180000 ppm
3111 6151
2962 6151
62932421 31'5 25101
20 3175 24421
629324Frse
629840Flare
183000
629840190000 2450
20 31'5
2432232 I '48 630347FlseID87 4555045350 2861 6145 6X34T193000
45600 45400
45650 45450
4570045500
2966 6183
3083 6167
3138 6177
33 11 11 855
32 I '3433 11 11 848
19 3175 24102
20 31'5 23602
21 3175 23741
630852Flare
631349Flan
631842Flare
6X852200000 2570
631349203000
631842210000 2650
20 31'5 23784
20 3175 24331
33 I '6232 11 11 876
632337Frse
632838Flare
1%1 2926 6180
3089 6185
63233T213000 4575045550
4580045600 632838220000 2670
60'FSpe891=504@ oficGravily=07780H4580045600 26pull0220000 ppm
33 I '89 633349Flse4585045650 3047 6180 63334919 31'5
24741223000
4590045700
4595045750
4600045800
3051 6195
3072 6150
3045 6173
21 3175 24285
20 31'5
24331
20 3175 24421
633860Flare
634366Flse
634874Flare
633860 2350230000 32 1111 876
32 I '7632 11 11 883
634366233000
1%72015IIV15 634874 2530000000
PetroClassFlowTestVersion4.5.D.5
0:iDOLLCOWELLDATASUSAMIDOLLCOWELLDATASERVICESIPRODUCTIOMTESTIMG,.IAweg2%864DOWDFlowTestlSQhl8
BSWOIGanOilRale OIGum
m''Id m'
820 19682 565535
0960 23045 566495
0640 15360 567135
0900 21601 568036
0840 20162 568876
0940 22561 569816
0880 21123 570696
0900 21600 571596
0910 21843 572506
0900 21600 573406
0850 20398 574256
0970 23278 575226
0937 22489 576163
0970 23280 577133
0850 20400 577983
0930 22321 578913
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
Roid dume
2
leadLTRPH SelrrrrhAPIWaterGumWstw
Gain
'API
33598 2666345 HNXO1400 1521748 00
1521568 IBBXO1800 431952668145 504 00
1300 31200 1521438 IBBXO2669445 00
1521318 IBBXO1200 28799 2670644 00
47998 IBBXO2000 2672644 1521118 00
1600 38399 IBBXO2674244 1520958 502 00
35997 IBBXO1500 2675744 1520808 00
1600 38400 1520648 HNXO2677344 00
1600 38397 IBBXO2678944 1520488 00
360002680444 1520338 IBBXO4991500 00
1600 384022682044 IBBXO1520178 00
1600 384022683644 189XO1520018 00
1713 2685357 1519846 189XO41 111 00
40800 2687057 1519676 189XO1700 504 00
36000 2688557 1519526 189XO1500 00
1600 38399 26901571519366 189XO 00
ProdnctiontestingABchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 43
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %1063 2015/11/14 09:00:00 445.00 443.00 2988 5928 31 11.11 862 17 20 31.75 24.508 619.414 Flare 619.414 2.220 63 0.820 19.682 565.535 1.400 33.598 2666.345 15217.48 7 188000 0.01064 09:30:00 445.50 443.50 2976 5958 31 11.11 896 17 20 31.75 25.327 619.933 Flare 619.933 63 0.01065 10:00:00 446.00 444.00 3030 5999 31 11.11 883 17 20 31.75 24.964 620.457 Flare 620.457 2.760 65 0.960 23.045 566.495 1.800 43.195 2668.145 15215.68 7 188000 50.4 0.01066 10:00:00 446.00 444.00 API = 50.4 @ 60°F , Specific Gravity = 0.7780, H2S pull 0ppm.1067 10:30:00 446.50 444.50 3212 6025 31 11.11 931 17 20 31.75 25.787 620.985 Flare 620.985 65 0.01068 11:00:00 447.00 445.00 3050 6030 31 11.11 862 17 20 31.75 24.508 621.509 Flare 621.509 1.940 67 0.640 15.360 567.135 1.300 31.200 2669.445 15214.38 7 188000 0.01069 11:30:00 447.50 445.50 3211 6044 31 11.11 924 17 20 31.75 25.695 622.032 Flare 622.032 67 0.01070 12:00:00 448.00 446.00 3090 6038 31 11.11 896 17 21 31.75 24.921 622.559 Flare 622.559 2.100 57 0.900 21.601 568.036 1.200 28.799 2670.644 15213.18 7 188000 0.01071 12:30:00 448.50 446.50 3063 6042 32 11.11 896 17 21 31.75 24.921 623.079 Flare 623.079 57 0.01072 13:00:00 449.00 447.00 2878 6056 31 11.11 931 17 21 31.75 25.738 623.606 Flare 623.606 2.840 70 0.840 20.162 568.876 2.000 47.998 2672.644 15211.18 7 188000 0.01073 13:30:00 449.50 447.50 2945 6079 30 11.11 896 17 21 31.75 25.101 624.136 Flare 624.136 70 0.01074 14:00:00 450.00 448.00 3036 6105 30 11.11 883 17 21 31.75 24.738 624.655 Flare 624.655 2.540 63 0.940 22.561 569.816 1.600 38.399 2674.244 15209.58 7 188000 50.2 0.01075 14:00:00 450.00 448.00 API = 50.2 @ 60°F , Specific Gravity = 0.7786, H2S pull 0ppm.1076 14:30:00 450.50 448.50 3103 6010 30 11.11 883 17 22 31.75 24.692 625.170 Flare 625.170 63 0.01077 15:00:00 451.00 449.00 3010 6115 30 11.11 896 17 21 31.75 25.101 625.689 Flare 625.689 2.380 63 0.880 21.123 570.696 1.500 35.997 2675.744 15208.08 7 188000 0.01078 15:30:00 451.50 449.50 2969 6107 31 11.11 883 17 22 31.75 24.692 626.207 Flare 626.207 63 0.01079 16:00:00 452.00 450.00 3063 6116 31 11.11 896 17 21 31.75 25.101 626.726 Flare 626.726 2.500 64 0.900 21.600 571.596 1.600 38.400 2677.344 15206.48 7 188000 0.01080 16:30:00 452.50 450.50 3097 6127 32 11.11 883 17 21 31.75 24.738 627.245 Flare 627.245 64 0.01081 17:00:00 453.00 451.00 2994 6117 32 11.11 910 17 21 31.75 25.464 627.768 Flare 627.768 2.510 64 0.910 21.843 572.506 1.600 38.397 2678.944 15204.88 7 188000 0.01082 17:30:00 453.50 451.50 3026 6125 31 11.11 896 17 21 31.75 25.101 628.295 Flare 628.295 64 0.01083 18:00:00 454.00 452.00 3062 6139 32 11.11 862 17 21 31.75 24.284 628.809 Flare 628.809 2.400 63 0.900 21.600 573.406 1.500 36.000 2680.444 15203.38 7 188000 49.9 0.01084 18:00:00 454.00 452.00 API = 49.9 @ 60°F , Specific Gravity = 0.7799, H2S pull 0ppm.1085 18:30:00 454.50 452.50 3111 6151 33 11.11 896 17 21 31.75 25.101 629.324 Flare 629.324 63 0.01086 19:00:00 455.00 453.00 2962 6151 33 11.11 869 17 20 31.75 24.421 629.840 Flare 629.840 2.450 65 0.850 20.398 574.256 1.600 38.402 2682.044 15201.78 7 188000 0.01087 19:30:00 455.50 453.50 2861 6145 32 11.11 848 17 20 31.75 24.322 630.347 Flare 630.347 65 0.01088 20:00:00 456.00 454.00 2966 6183 33 11.11 855 16 19 31.75 24.102 630.852 Flare 630.852 2.570 62 0.970 23.278 575.226 1.600 38.402 2683.644 15200.18 7 189000 0.01089 20:30:00 456.50 454.50 3083 6167 32 11.11 834 16 20 31.75 23.602 631.349 Flare 631.349 62 0.01090 21:00:00 457.00 455.00 3138 6177 33 11.11 848 16 21 31.75 23.741 631.842 Flare 631.842 2.650 65 0.937 22.489 576.163 1.713 41.111 2685.357 15198.46 7 189000 0.01091 21:30:00 457.50 455.50 2926 6180 33 11.11 862 16 20 31.75 23.784 632.337 Flare 632.337 65 0.01092 22:00:00 458.00 456.00 3089 6185 32 11.11 876 16 20 31.75 24.331 632.838 Flare 632.838 2.670 64 0.970 23.280 577.133 1.700 40.800 2687.057 15196.76 7 189000 50.4 0.01093 22:00:00 458.00 456.00 API = 50.4 @ 60°F , Specific Gravity = 0.7780, H2S pull 0ppm.1094 22:30:00 458.50 456.50 3047 6180 33 11.11 889 17 19 31.75 24.741 633.349 Flare 633.349 64 0.01095 23:00:00 459.00 457.00 3051 6195 32 11.11 876 16 21 31.75 24.285 633.860 Flare 633.860 2.350 64 0.850 20.400 577.983 1.500 36.000 2688.557 15195.26 7 189000 0.01096 23:30:00 459.50 457.50 3072 6150 32 11.11 876 16 20 31.75 24.331 634.366 Flare 634.366 64 0.01097 2015/11/15 00:00:00 460.00 458.00 3045 6173 32 11.11 883 16 20 31.75 24.421 634.874 Flare 634.874 2.530 63 0.930 22.321 578.913 1.600 38.399 2690.157 15193.66 7 189000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime
Dale Time Cum Row Tubing
Pres
Well
OwingFlow
Pres Temp
Chrdm
Size
Dg
Pres
GnficeDryRowMelar
MIR Plate GasRate
TempGze
CumGas Gas
To
TotalGas RdVd
Flared
BSWWIGanOilRale OICum
Rnid
Watw
Gain
WabuWaterGum
IMH
inertLTRPH SalinilyAPI
dume
2
WW)amfddhhmmasHrs Hrs kPag kPag '0 mm '0 mm 1tym'id ftyap (I)m''Idm'API2015)IV1500000046000458000000hrsreadmg
FlowingTubmgpressure=3045kPa
ShutmCasingpressure=6173kPa
Flowingtemperature=32'0
Chokesize= 28)64"(1111mm)
GasRate= 2586
ltPm'otalguidrate=253m'Ihr
Waterrecoveryrate=1 60m'Ihr
Condensaterate=093m'Ihr
PH=T,Salinity=189XOppmBSSW=63S
API=504@60'F,Separator=883kPagH'S=0 ppmSand=00%
Dailyhrsgowed=24hrs
Cumhrsflowed=458hrs
Dailygasproduced10flarelast24hrs=26531tPm'um
gasProducedtoflare=63487410hip
CondProducedlast24hrs= 2314m'um
CondProduced=57891
m'ater
Recoveredlast24Hrs=4154m'otal
WaterRecovered=269016
m'nmalLoadFluidtoRecover=1788382m'oad
FluidLetttoRecover= 1519366
m'ercentageRecoveredfromInmalLoad=1504 '4
Chokeswashedin24bourn=g
Totalchokeswashed=0
IIX
1101
0030004605045850 2975 6192 33 I '76 17 20
01000046100 45900 2871 6195 33 1111 883 17 20 3175
01300046150 45950 3072 6195 33 I '76 17 19
24692 635386
24604 635899
24558 636411
Ftae
Flare
Ftae
635386
635899
636411
2620 65 0920 22077 579833 1700 40803269185715191967 189XO 00
1102
1103
11(4
020000 46200 46000 3101 6196 32 II II 883 16 19 3175
020000 46200 46000API=504@60'FSpeoficGravity=0 7780H26pullgppm
023000 46250 46050 3078 6206 32 I '83 16 19
24283 636920
24098 637424
Flare
Ftae
636920
637424
2620 65 0920 22077 580753 1 700 40803 2693557 1 519026 7 189XO504 00
1105
1106
1107
1108
1109
030000 46300 46100 3121 6212 33 II II 869 16 20 3175
033000 46350 46150 3048 6224 32 I '55 16 20
040000 46400 46200 3041 6214 32 11 11 862 16 20 3175
043000 46450 46250 3041 6214 32 I '69 16 19
050000 46500 46300 3071 6226 32 II II 855 16 19 3175
24058 637926
23694 638423
23967 638920
24103 639420
23555 639917
Flare
Ftae
Flare
Ftae
Flare
637926
638423
638920
639420
639917
2470 65
2790 65
2660 64
0870 20878 581622
0990 23757 582612
0960 23040 583572
1 600 38402 2695158 1 518866 7
1 800 43203 2696958 1 518686 7
1 700 40800 2698658 1 518516 7
189XO
189XO
189XO
00
00
00
1110
1112
050000 46500 46300CollecttwohighpressuregassamplesCorelabCylindernumbers(V0001244V0008227)
050000 46500 46300CollecttwohighpressurecondensatesamplesCoreLabCylindernumbers(V0005939V0007664)
050000 46500 46300CollecttwostockllrwatersamplesandtwoHtrcondensatesamples
1113 0530004655046350 2910 6225 32 I '62 16 20 31'5 23784 640410Flee 640410
1114
1115
0600004660046400 2915 6232 32 1111 855 16 20 3175 23877 640906Flare640906 2650 64 0950 22801 584522 1700 40799270035815183467 189XO504 00
oficGravity=0 7780H26pull0ppm0600004660046400FPI=504@60'FSpe
1116
1117
1118
1119
0630004665046450
0700004670046500
0730004675046550
0800004680046600
3040 6240
3216 6235
3080 6238
2998 6239
855
862
862
827
23739
3175 24012
24012
3175 23193
641402F la e 641402
641900Flare 641900 2440
642400Flee 642400
642892Flare 642892 2630
66 0840
66 0891
20162
21391
585362 1 600
586254 1739
38398
41729
27019581518186
2703696 1518012
7 189XO
7 189XO
00
00
PetroClassFlowTestVersion4.5.0.5
0:iDDLLCDWELLDATASUSAHIDDLLCDWELLDATASERVICESIPRDDUCTIDHTESTIHG,.IAweg24864IIWBFlowTestlbegaa()4
ProdnctiontestingASchlumbergerCempany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 44
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %1098 2015/11/15 00:00:00 460.00 458.00 00:00 hrs reading
Flowing Tubing pressure = 3045 kPaShut in Casing pressure = 6173 kPaFlowing temperature = 32°CChoke size = 28/64" (11.11mm)Gas Rate = 25.86 10³m³Total fluid rate = 2.53 m³/hrWater recovery rate = 1.60 m³/hrCondensate rate = 0.93 m³/hrPH =7 , Salinity = 189000 ppm, BS&W = 63 %API = 50.4 @ 60°F, Separator = 883 kPag H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 24 hrs Cum hrs flowed = 458 hrsDaily gas produced t0 flare last 24 hrs = 26.53 10³m³Cum gas Produced to flare= 634.874 10³m³Cond Produced last 24 hrs = 23.14 m³Cum Cond Produced = 578.91 m³Water Recovered Last 24 Hrs = 41.54 m³Total Water Recovered = 2690.16 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15193.66 m³ Percentage Recovered from Initial Load = 15.04 %Chokes washed in 24 hours=0Total chokes washed =0
1099 00:30:00 460.50 458.50 2975 6192 33 11.11 876 17 20 31.75 24.692 635.386 Flare 635.386 63 0.01100 01:00:00 461.00 459.00 2871 6195 33 11.11 883 17 20 31.75 24.604 635.899 Flare 635.899 2.620 65 0.920 22.077 579.833 1.700 40.803 2691.857 15191.96 7 189000 0.01101 01:30:00 461.50 459.50 3072 6195 33 11.11 876 17 19 31.75 24.558 636.411 Flare 636.411 65 0.01102 02:00:00 462.00 460.00 3101 6196 32 11.11 883 16 19 31.75 24.283 636.920 Flare 636.920 2.620 65 0.920 22.077 580.753 1.700 40.803 2693.557 15190.26 7 189000 50.4 0.01103 02:00:00 462.00 460.00 API = 50.4 @ 60°F , Specific Gravity = 0.7780, H2S pull 0ppm.1104 02:30:00 462.50 460.50 3078 6206 32 11.11 883 16 19 31.75 24.098 637.424 Flare 637.424 65 0.01105 03:00:00 463.00 461.00 3121 6212 33 11.11 869 16 20 31.75 24.058 637.926 Flare 637.926 2.470 65 0.870 20.878 581.622 1.600 38.402 2695.158 15188.66 7 189000 0.01106 03:30:00 463.50 461.50 3048 6224 32 11.11 855 16 20 31.75 23.694 638.423 Flare 638.423 65 0.01107 04:00:00 464.00 462.00 3041 6214 32 11.11 862 16 20 31.75 23.967 638.920 Flare 638.920 2.790 65 0.990 23.757 582.612 1.800 43.203 2696.958 15186.86 7 189000 0.01108 04:30:00 464.50 462.50 3041 6214 32 11.11 869 16 19 31.75 24.103 639.420 Flare 639.420 65 0.01109 05:00:00 465.00 463.00 3071 6226 32 11.11 855 16 19 31.75 23.555 639.917 Flare 639.917 2.660 64 0.960 23.040 583.572 1.700 40.800 2698.658 15185.16 7 189000 0.01110 05:00:00 465.00 463.00 Collect two high pressure gas samples Core Lab Cylinder numbers (V0001244, V0008227)1111 05:00:00 465.00 463.00 Collect two high pressure condensate samples Core Lab Cylinder numbers (V0005939, V0007664)1112 05:00:00 465.00 463.00 Collect two stock 1ltr water samples and two 1ltr condensate samples.1113 05:30:00 465.50 463.50 2910 6225 32 11.11 862 16 20 31.75 23.784 640.410 Flare 640.410 64 0.01114 06:00:00 466.00 464.00 2915 6232 32 11.11 855 16 20 31.75 23.877 640.906 Flare 640.906 2.650 64 0.950 22.801 584.522 1.700 40.799 2700.358 15183.46 7 189000 50.4 0.01115 06:00:00 466.00 464.00 API = 50.4 @ 60°F , Specific Gravity = 0.7780, H2S pull 0ppm.1116 06:30:00 466.50 464.50 3040 6240 32 11.11 855 16 19 31.75 23.739 641.402 Flare 641.402 64 0.01117 07:00:00 467.00 465.00 3216 6235 32 11.11 862 16 19 31.75 24.012 641.900 Flare 641.900 2.440 66 0.840 20.162 585.362 1.600 38.398 2701.958 15181.86 7 189000 0.01118 07:30:00 467.50 465.50 3080 6238 33 11.11 862 16 19 31.75 24.012 642.400 Flare 642.400 66 0.01119 08:00:00 468.00 466.00 2998 6239 34 11.11 827 16 19 31.75 23.193 642.892 Flare 642.892 2.630 66 0.891 21.391 586.254 1.739 41.729 2703.696 15180.12 7 189000 0.0
ARCRESOURCESLTD.
100/01-34-085-22W6/2
2015/10/2620:00:00yyyy/mm/ddhh:mm:ss
2015/11/1509:00:00yyyy/mm/ddhh:mm:ss
ARCRESHZNREDA2-4-86-22
MONTNEYMA2/MB
NORTHRED
D4MC-00150
FLOWTESTDATATestlime Well OnficeDryRowMalar Rnid dume
2
Time Cum Row TubingCmingFlow
Pres Pres Temp
QmksShdm
Sns Pms
Dg MIR
Pres Temp
GasRats CumGas Gas TolalGasRdVd
To Flared
BSWOIGanOilRale OIGum Water WaterWaterGumleadLTR
Gain Rate
PH SalinilyAPI Smd
Dd
II20
WWfamfdd
2015HV15
hhmmasHrs Hrs kPag kPag '0
00000046000466000800hrsreadmg
mm kPag kPa '0 mm IIFm'ld Ifpm'tyap(ljm'''Id 'API
FlowingTubmgpressure=2998kPa
ShutmCasingpressure=6239kPa
Flowingtemperature=32'0
Chokesize= 28I64"(1111mmi
GasRate= 2456ltPm'otal
guidrate=263m'Ihr
Waterrecoveryrate=I 74m'Ihr
Condensaterate=089m'Ihr
PH=T,Salinity=tgggggppmBSSW=66S
API=504@60'F,Separator=827kPagH'S=0 ppmSand=00%
Dailyhrsgowed=00hrs
Cumhrsflowed=466hrs
Dailygasproduced10flarelast8hrs=80210'm'um
gasProducedtoflare=64289210VF
CondProducedlast8hrs= 734m'um
CondProduced=58625m'ater
Recoveredlast8Hrs= 1354m'otal
WaterRecovered=270370
m'nnalLoadFluidtoRecover=1708382m'oad
FluidLefttoRecover= 1510012
m'ercentageRecoveredfromInnalLoad=1511'I
Chokeswashedin8 hours=g
Totalchokeswashed=0
1121
1122
1123
1124
1125
1126
1127
II20
0005004600846600Shutmwell
0005004600846600 5150
0010004601746600 4427
001500 46025 46600 4606
0030004605046600 5107
0045004607546600 5549
090000 46900 46600 5951
0900004690046600EndotTest
6379
6503
6691
6969
7090
7155 0
0 0
0 0
000 tl tlgg
tl tlgg
642092Flee 642092
Flze 642092
Flze 642092
Flee 642092
Flee 642092
642092Flee 642092
0000 0
0000
00tlg
00tlg
0ggtl
0ggtl
506254 0ggtl
506254 0ggtl
0tlgg
0tlgg
27036961518012
27036961518012
PetroClassFlowTestVersion4.5.0.5
0:iDOLLCOWELLDATASUSAHIDOLLCOWELLDATASERVICESIPRODUCTIOHTESTIHG,.IAweD2A864DIWSFlowTestlDQgs(5
ProdnctiontestingASchlumbergerCompany
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA SERVICES\PRODUCTION TESTING...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 45
FLOW TEST DATATest Time Well Orifice Dry Flow Meter Data Summary Fluid Volume
2Date Time Cum Flow Note Tubing
PresCasingPres
FlowTemp
ChokeSize
StaticPres
DiffPres
M/RTemp
PlateSize
Gas Rate Cum Gas GasTo
Total GasFlared
Fld Vol BSW Oil Gain Oil Rate Oil Cum WaterGain
WaterRate
Water Cum Load LTR PH Salinity API SandCut
yyyy/mm/dd hh:mm:ss Hrs. Hrs. kPag kPag °C mm kPag kPa °C mm 10³m³/d 10³m³ 10³m³ (I) m³ % m³ m³/d m³ m³ m³/d m³ m³ ppm °API %1120 2015/11/15 08:00:00 468.00 466.00 08:00 hrs reading
Flowing Tubing pressure = 2998 kPaShut in Casing pressure = 6239 kPaFlowing temperature = 32°CChoke size = 28/64" (11.11mm)Gas Rate = 24.56 10³m³Total fluid rate = 2.63 m³/hrWater recovery rate = 1.74 m³/hrCondensate rate = 0.89 m³/hrPH =7 , Salinity = 189000 ppm, BS&W = 66 %API = 50.4 @ 60°F, Separator = 827 kPag H²S = 0 ppm, Sand =0.0 %
Daily hrs flowed = 08 hrs Cum hrs flowed = 466 hrsDaily gas produced t0 flare last 8 hrs = 8.02 10³m³Cum gas Produced to flare= 642.892 10³m³Cond Produced last 8 hrs = 7.34 m³Cum Cond Produced = 586.25 m³Water Recovered Last 8 Hrs = 13.54 m³Total Water Recovered = 2703.70 m³Initial Load Fluid to Recover = 17883.82 m³Load Fluid Left to Recover = 15180.12 m³ Percentage Recovered from Initial Load = 15.11 %Chokes washed in 8 hours=0Total chokes washed =0
1121 08:05:00 468.08 466.00 Shut in well.1122 08:05:00 468.08 466.00 5150 6379 11.11 0 0 0 0.00 0.000 642.892 Flare 642.892 0.000 0 0.000 0.000 586.254 0.000 0.000 2703.696 15180.12 0.01123 08:10:00 468.17 466.00 4427 6503 11.11 0.00 Flare 642.892 0 0.01124 08:15:00 468.25 466.00 4606 6691 11.11 0.00 Flare 642.892 0 0.01125 08:30:00 468.50 466.00 5107 6969 11.11 0.00 Flare 642.892 0 0.01126 08:45:00 468.75 466.00 5549 7098 11.11 0.00 Flare 642.892 0 0.01127 09:00:00 469.00 466.00 5951 7155 11.11 0 0 0 0.00 0.000 642.892 Flare 642.892 0.000 0 0.000 0.000 586.254 0.000 0.000 2703.696 15180.12 0.01128 09:00:00 469.00 466.00 End of Test.
ARC RESOURCES LTD.100/01-34-085-22W6/22015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss
ARCRES HZ N RED A2-4-86-22MONTNEY MA2/MB
NORTH REDD4MC-00150
Meter Report
Gas MeterSpecificationMeter Size
TapsMeter PositionMaterial:TubePlate
Orifice Dry I
Orifice Metering (ANSI/API 2530-92) (AGA3 1992)97.23 mm
FlangeUpstream
Carbon Steel304/316 Stainless
Gas Properties:CorrelationComponents:
AGAReport 8 (1992) Detailed
C1
C2H28
02IC5
NC7NC10
Gas Gravity (Gr)
77.9800 %10.9200 %
0.0000 %0.0000 %0.3200 %0.2200 %0.0000 %0.7336
N2C3H2
IC4NC5NC8
He
1.5300 %5.6200 %0.0000 %0.6900 %0.3900 %0.0000 %0.0100 %
CO2H20
CONC4NC6NC9
Ar
0.4700 %0.0000 %0.0000 %1.6300 %0.2200 %0.0000 %0.0000 %
Liquid MeterFluids
Fluid
Reservoir(Water) + Load(Water) Oil
SpecificationGain
Volume MeterIncremental
Liquid MeterFluidsSand Bulk DensitySand Porosity
Volume 2
Water Sand1602
kg/m'/
SpecificationGain
Volume MeterIncremental
PetroCless FlowTest Version 4 5 6.5C IDOL LCD WELL DATA- SOSAPtlOOLLCO WELL DATAS ..lAwe5 2.4-66ne@WS Flow Test.sosege 2
Production TestingA Soal moama Company
ARC RESOURCES LTD. ARCRES HZ N RED A2-4-86-22100/01-34-085-22W6/2 MONTNEY MA2/MB2015/10/26 20:00:00 yyyy/mm/dd hh:mm:ss NORTH RED2015/11/15 09:00:00 yyyy/mm/dd hh:mm:ss D4MC-00150
PetroClass FlowTest Version 4.5.0.5C:\DOLLCO WELL DATA - SUSAN\DOLLCO WELL DATA S...\Awell 2-4-86-@@W6 Flow Test.flowtestPage 2
Meter ReportGas Meter Orifice Dry Flow MeterSpecification Orifice Metering (ANSI/API 2530-92) (AGA 3 1992)Meter Size 97.23 mmTaps FlangeMeter Position UpstreamMaterial:Tube Carbon SteelPlate 304/316 Stainless
Gas Properties:Correlation AGA Report 8 (1992) DetailedComponents:
C1 77.9800 % N2 1.5300 % CO2 0.4700 %C2 10.9200 % C3 5.6200 % H2O 0.0000 %
H2S 0.0000 % H2 0.0000 % CO 0.0000 %O2 0.0000 % IC4 0.6900 % NC4 1.6300 %IC5 0.3200 % NC5 0.3900 % NC6 0.2200 %
NC7 0.2200 % NC8 0.0000 % NC9 0.0000 %NC10 0.0000 % He 0.0100 % Ar 0.0000 %
Gas Gravity (Gr) 0.7336
Liquid Meter FluidFluids Reservoir(Water) + Load(Water) Oil
Specification Volume MeterGain Incremental
Liquid Meter Volume 2Fluids Water Sand Sand Bulk Density 1602 kg/m³Sand Porosity %
Specification Volume MeterGain Incremental
EXTENDED GAS ANALYSIS
V0008227- 1
CON1AINER IDENTITY
1 00/01-34-085-22W6/02
METER ID
ARC Resources Ltd.OPERATOR
ARCRes Hz N Red A2-4-86-22
29042WELL LICENSE NUMBER
521 34-201 5-3673LABORATORY FILE NUMBER
FAGE
LOCATION(UWI) WELL NAME
Red Montney MA2/MB
KB ELEV (m) GR ELEV (m)
Production TestingFIELD OR AREA POOL OR ZONE SAMPLER
TESTTYPE AND No
Separator Meter RunPOINT OF SAMPLE
TEST RECOVERY
SAMPLE POINT ID
PUMPING FLOWING GAS LIFT SWAB
I/I ATE R rrr/d OIL m'/d GAS rrr/d
TEST INTERVALor PERFS (meters)
SEFARATOR RESERVOIR OTHER
Pressures, kPa (gauge)
2015 11 15 2015 11 19 2015 11 25 MK
L20.0SEFARATOR OTHER
Temperatures, C
DATE SAMPLED (Y/M/D) CATE RECEIVED (Y/M/D) DATE ANALYZED (Y/M/D) ANALYST AMT AND TYPE CUSHION MUD RESISTIVITY
COMPONENTMOLE FRACTION
AIR FREE ASRECEIVED
MOLE FRACTIONAIR FREE
ACID GAS FREE
mumAIR FREE AS
RECEIVED
CALCULATEDGROSS HEATING LALUEMJ/m' 15 C & 101 325 kPa (aas )
46.76 46.96
CALCULATEDLAPOR PRESSURE
kPa(aas)@40 C
92.5
MOISTURE FREE MOISTURE Ik ACID GAS FREE PEN1ANES PLUS
Hz
He
Nz
COZ
HZS
Trace
0.0001
0.0153
0.0047
0.0000
Trace
0.0001
0.0153
0.0000
0.0000
CALCULATEDTO1ALSAMPLE PROPERTIES (AIR=I)@15 C & 101 325 kPa
MOISTURE FREE AS AMPLED
0.731 21.2
DENSIRY RELATIVE DENSITY RELATIVE MOLECULAR NABS
CT PROPERTIES @15 C & 101 325 kPa MOLE FRACTION LOCATION METHOD
CALCULATEDPSEUDOCRITICAL PROPERTIESAS SAMPLED ACID GAS FREE
Pc Tc Pc Tc
Cl
Cz
0.7798
0.1 092
0.7836
0.1 097 388.1
745.6 IN/m 97.1
DENSITY MOLECULARWEIGHT
0.0000000 Laboratory Chmmatograph
HYDROGEN SULPHIDE
CS 0.0562 0.0565 206.5
iC4
C4
iCB
Cs
c,
C74
Total
0.0069
0.0163
0.0032
0. 0039
0.0022
0.0022
1.0000
0.0070
0.0164
0.0032
0.0039
0.0022
0.0021
1.0000
30.1
68.6
15.6
18.9
11.6
12.2
751.6
REMARKS:
Sample was air contaminated.
Results may be affected by air contamination.
Opening pressure does not ref lect field conditions
Duplicate cylinder was under vacuum upon arrival.
NOTE: THE GROSS HEATINGVALUEHAS BEEN CALCULATEDIN ACCORDANCETOAGAREPORT s5 ANDALLPROPERTIES HAVEBEEN CALCULATEDUTILIZING
PHYSICAL CONS1ANTS AND BOILING POINT GROUPING.
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RESERVOIR PRESSURESURVEY TEST REPORT
COMMISSION Mailmg AddressWell Data Management300-395 Harbour RoadVictoria BC V9A087
Phone (250)4)9-4400Fax (250) 419-4402
Date Received
Farm must be submitted under the suthanty of the Oil snd Gas Activities Act SBC. 2008, c 36, Dnlling snd Production Regulstian, s 73(3) ta the Oilsnd Gss Commission, at the address noted above, accompanied by the test data snd analysis. /nformatian collected on this farm will be used forpublic record in accordance with s 38 of the Oil snd Gss Activities Act General Regulatian.
WELL INFORMATION
Well Name: ARCRES HZ N RED A02-04-086-22 W6
BH Location: 100/01-34-085-22 W6/02
Well Permit Nod 29042
K.B. 690.00 m
Field: Attachie Pool: Montney C.F. 684.90 m
Completion Interval: 1727.89 —1715.89 mKB TVD Mid-point of Completion (MPP): 1721.89 mKB TVD
Well Type: vertical directional horizontal >< Fluid Type: gas >< oil water x
TEST DATA
Test Date (yyyyimmidd): 2015/12/12
Shut-in days (to the nearest smgie deamai): 27.1
Liquid Level in We))bore: 1012.09 mCF (TVD)
Test Type: SG DFFO PGFO OTHER
PG X CS AWS
PGBU CSBU AWSBU
Temperature @ Run Depth
58 'C
We))bore Gradient @ Run Depth(tc three deomal places)
10.718 kPa/m
Formation Gradient(to three deomai places)
1.198 kPa/m
Reservoir Pressure
Static Pressure: kPa g a X
@ a Run Depth of: mCF (TVD)
Extrapolated Reservoir Pressure, P* or
Calculated Reservoir Pressure, Pr
Last Measured Pressure**
Last Measured Pressure: 17094.35 kPa g a X
@ a Run Depth of: 1617.56 mCF (TVD)
Pressure Building @ 3 kPa/hr
(** reported for build-up and fat)-off pressure tests only)
COMPANY INFORMATION
Completed by: PDQ Services Ltd. [email protected] Company: ARC Resources Ltd.
Date: 2015/12/15 Phone: Email:
Reservoir Pressure Survey Test Report FormUpdated: 15 December 2015
Effective: 1-May-2013
RESERVOIR PRESSURESURVEY TEST REPORT
Date Received
Mailing Address:Well Data Management 300-398 Harbour Road Victoria BC V9A 0B7
Phone: (250) 419-4400Fax: (250) 419-4402
Form must be submitted under the authority of the Oil and Gas Activities Act S.B.C. 2008, c. 36, Drilling and Production Regulation, s.73(3) to the Oil and Gas Commission, at the address noted above, accompanied by the test data and analysis. Information collected on this form will be used for public record in accordance with s. 38 of the Oil and Gas Activities Act General Regulation.
WELL INFORMATION
Well Name: ARCRES HZ N RED A02-04-086-22 W6 Well Permit No.: 29042
BH Location: 100/01-34-085-22 W6/02 K.B. 690.00 m
Field: Attachie Pool: Montney C.F. 684.90 m
Completion Interval: 1727.89 – 1715.89 mKB TVD Mid-point of Completion (MPP): 1721.89 mKB TVD
Well Type: vertical directional horizontal Fluid Type: gas oil water
TEST DATA
Test Date (yyyy/mm/dd): 2015/12/12 Test Type: SG DFFO PGFO OTHER
Shut-in days (to the nearest single decimal): 27.1 PG CS AWS
Liquid Level in Wellbore: 1012.09 mCF (TVD) PGBU CSBU AWSBU
Temperature @ Run Depth
58 C
Wellbore Gradient @ Run Depth(to three decimal places)
10.718 kPa/m
Formation Gradient(to three decimal places)
1.198 kPa/m
Reservoir Pressure Last Measured Pressure**
Static Pressure: kPa g a Last Measured Pressure: 17094.35 kPa g a
@ a Run Depth of: mCF (TVD) @ a Run Depth of: 1617.56 mCF (TVD)
Extrapolated Reservoir Pressure, P* or Pressure Building @ 3 kPa/hr
Calculated Reservoir Pressure, Pr (** reported for build-up and fall-off pressure tests only)
Comments:
COMPANY INFORMATION
Completed by: PDQ Services Ltd. [email protected] Company: ARC Resources Ltd.
Date: 2015/12/15 Phone: Email:
Reservoir Pressure Survey Test Report FormUpdated: 15 December 2015
Effective: 1-May-2013
Company: ARC RESOURCES LTD.Well Name: ARCRES HZ N RED A02-04-086-22 W6Bottom Hole Location: 100/07-34-085-22 W6/02WA¹ 29042Formation: MontneyType of Test: Flow E BuildupDate of Test: 2015/1 1/11 to 2015/12/12
Test by RAPID WIRELINE SERVICES LTD.Report by PDQ SERVICES LTD.
Company: ARC RESOURCES LTD. Well Name: ARCRES HZ N RED A02-04-086-22 W6 Bottom Hole Location: 100/01-34-085-22 W6/02 WA# 29042 Formation: Montney Type of Test: Flow & Buildup Date of Test: 2015/11/11 to 2015/12/12
Test by RAPID WIRELINE SERVICES LTD. Report by PDQ SERVICES LTD.
Company Name ARC RESOURCES LTD.ContactWell NameUnique Well IDSurface LocationWell License NumberFieldWell Type
ARCRES HZ N RED A02-04100/01-34-085-22W6/02
A02-04-086-22 W629042
AttachieHorizontal
Test Information
General Information - FLOW & BUILDUP
KB Elevation (SL)CF Elevation (SL)GL Elevation (SL)KB-CF OffsetKB-GL Offset
690.00 m684.90 m684.10 m
5.10 m5.90 m
Test TypeFormationWell Fluid TypeTest Purpose (AEUB)H25
Test/Production Interval
Flow & BuildupMontney06 Water
Initial Test0.0 ppm
Job NumberRepresentativeWe II 0 peratorReport DatePrepared By
2015/12/15PDQ Services Ltd.
Top(Log KB)Bottom(Log KB)MPP(Log KB)
Start Test DateFinal Test DateDate Well Shut-InFlow Duration
2866.00 m Top(TVD KB)4211.00 m Bottom(TVD KB)3538.50 m MPP(TVD KB)
2015/11/11 Start Test Time2015/12/12 Final Test Time2015/11/15 Time Well Shut-In89.0361 hrs Shut-In Duration
1727.89 m1715.89 m1721.89 m
14:21:0009:29:0008:00:00649.4833 hrs
Tubing Pressure: InitialTubing Pressure: Final
Wellbore Information
5290.00 kPa(a) Casing Pressure: Initial9400.00 kPa(a) Casing Pressure: Final
5330.00 kPa(a)9400.00 kPa(a)
Flow PathTubing IDTubing ODTubing Depth(Log KB)Casing Depth(Log KB)Packer Depth(Log KB)PBTD(Log KB)
Test Results
Gauge NameGauge Serial NumberRun Depth (TVD KB)Pressure at Run DepthPressure at MPPTemperature at Run DepthLiquid Level(TVD KB)
Tubing62.0 mm73.0 mm
1653.57000 m4255.00000 m
mm
Bot Rec.1866
1622.66 m17094.35 kPa(a)18157.90 kPa(a)
57.5 'C1017.19 m
Completion TypeCasing IDCasing ODTubing Depth(TVD KB)Casing Depth(TVD KB)Packer Depth(TVD KB)PBTD(TVD KB)
Gauge NameGauge Serial NumberRun Depth (TVD KB)Pressure at Run DepthPressure at MPPTemperature at Run DepthLiquid Level(TVD KB)
Perforated99.6 mm
114.3 mm1641.17939 m1715.84000 m
mm
Top Rec.1865
1622.22 m17091.86 kPa(a)18156.78 kPa(a)
57.5 'C1016.87 m
REMARKS:
heal™Vakdala™Ver 7 1 2 6
0 1PCO WerklA02-04 F&BFKT 15-Cee-15
General Information - FLOW & BUILDUP
Contact Well Name ARCRES HZ N RED A02-04 Unique Well ID 100/01-34-085-22W6/02 Surface Location A02-04-086-22 W6 Well License Number 29042 Field Attachie Well Type Horizontal
Test Type Flow & Buildup Formation Montney Well Fluid Type 06 Water Test Purpose (AEUB) Initial Test H2S 0.0 ppm
Top(Log KB) 2866.00 m Bottom(Log KB) 4211.00 m MPP(Log KB) 3538.50 m
Start Test Date 2015/11/11 Final Test Date 2015/12/12 Date Well Shut-In 2015/11/15 Flow Duration 89.0361 hrs
Tubing Pressure: Initial 5290.00 kPa(a) Tubing Pressure: Final 9400.00 kPa(a)
Flow Path Tubing Tubing ID 62.0 mm Tubing OD 73.0 mm Tubing Depth(Log KB) 1653.57000 m Casing Depth(Log KB) 4255.00000 m Packer Depth(Log KB) m PBTD(Log KB) m
Gauge Name Bot Rec. Gauge Serial Number 1866 Run Depth (TVD KB) 1622.66 m Pressure at Run Depth 17094.35 kPa(a) Pressure at MPP 18157.90 kPa(a) Temperature at Run Depth 57.5 °C Liquid Level(TVD KB) 1017.19 m
KB Elevation (SL) 690.00 m CF Elevation (SL) 684.90 m GL Elevation (SL) 684.10 m KB-CF Offset 5.10 m KB-GL Offset 5.90 m
Job Number Representative Well Operator Report Date 2015/12/15 Prepared By PDQ Services Ltd.
Top(TVD KB) 1727.89 m Bottom(TVD KB) 1715.89 m MPP(TVD KB) 1721.89 m
Start Test Time 14:21:00 Final Test Time 09:29:00 Time Well Shut-In 08:00:00 Shut-In Duration 649.4833 hrs
Casing Pressure: Initial 5330.00 kPa(a) Casing Pressure: Final 9400.00 kPa(a)
Completion Type Perforated Casing ID 99.6 mm Casing OD 114.3 mm Tubing Depth(TVD KB) 1641.17939 m Casing Depth(TVD KB) 1715.84000 m Packer Depth(TVD KB) m PBTD(TVD KB) m
Gauge Name Top Rec. Gauge Serial Number 1865 Run Depth (TVD KB) 1622.22 m Pressure at Run Depth 17091.86 kPa(a) Pressure at MPP 18156.78 kPa(a) Temperature at Run Depth 57.5 °C Liquid Level(TVD KB) 1016.87 m
Test Information
REMARKS:
Test Results
Company Name ARC RESOURCES LTD.
Test/Production Interval
Wellbore Information
Validata Ver 7.1.2.6TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15Validata Ver 7.1.2.6TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15
Gauge NameGauge Serial NumberRun Depth (TVD KB)Date of Last CalibrationGauge Start DateGauge Stop DateDate Gauge On BottomDate Gauge Off Bottom
Bot Rec.1866
1622.66 m201 5/09/232015/11/112015/12/122015/11/112015/12/12
Gauge TypeGauge ManufacturerGauge ModelMaximum Recorder RangeGauge Start TimeGauge Stop TimeTime Gauge On BottomTime Gauge Off Bottom
StrainRoc kdata
Panther41470.00 kPa(a)
12:51:3010:33:0014:21:0009:29:00
Gauge NameGauge Serial NumberRun Depth (TVD KB)Date of Last CalibrationGauge Start DateGauge Stop DateDate Gauge On BottomDate Gauge Off Bottom
Top Rec.1865
1622.22 m2015/09/232015/11/112015/12/122015/11/112015/12/12
Gauge TypeGauge ManufacturerGauge ModelMaximum Recorder RangeGauge Start TimeGauge Stop TimeTime Gauge On BottomTime Gauge Off Bottom
StrainRockdata
Panther41470.00 kPa(a)
12:51:3010:33:0014:21:0009:29:00
Company Name ARC RESOURCES LTD. Unique Well ID 100/01-34-085-22W6/02 Start Test Date 2015/11/11 Final Test Date 2015/12/12
Well Name ARCRES HZ N RED A02-04 Formation Montney
Recorders
Gauge Name Bot Rec. Gauge Serial Number 1866 Run Depth (TVD KB) 1622.66 m Date of Last Calibration 2015/09/23 Gauge Start Date 2015/11/11 Gauge Stop Date 2015/12/12 Date Gauge On Bottom 2015/11/11 Date Gauge Off Bottom 2015/12/12
Gauge Type Strain Gauge Manufacturer Rockdata Gauge Model Panther Maximum Recorder Range 41470.00 kPa(a) Gauge Start Time 12:51:30 Gauge Stop Time 10:33:00 Time Gauge On Bottom 14:21:00 Time Gauge Off Bottom 09:29:00
Gauge Name Top Rec. Gauge Serial Number 1865 Run Depth (TVD KB) 1622.22 m Date of Last Calibration 2015/09/23 Gauge Start Date 2015/11/11 Gauge Stop Date 2015/12/12 Date Gauge On Bottom 2015/11/11 Date Gauge Off Bottom 2015/12/12
Gauge Type Strain Gauge Manufacturer Rockdata Gauge Model Panther Maximum Recorder Range 41470.00 kPa(a) Gauge Start Time 12:51:30 Gauge Stop Time 10:33:00 Time Gauge On Bottom 14:21:00 Time Gauge Off Bottom 09:29:00
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec. Top Rec. Top Rec.
Temp. Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
1 2015/11/11
2 2015/11/11
3 2015/11/11
4 2015/11/11
5 2015/11/11
6 2015/11/11
7 2015/11/11
8 2015/11/11
9 2015/11/11
10 2015/11/11
11 2015/11/11
12 2015/11/11
13 2015/11/12
14 2015/11/12
15 2015/11/12
16 2015/11/12
17 2015/11/12
18 2015/11/12
19 2015/11/12
20 2015/11/12
21 2015/11/12
22 2015/11/12
23 2015/11/12
24 2015/11/12
25 2015/11/13
26 2015/11/13
27 2015/11/13
28 2015/11/13
29 2015/11/13
30 2015/11/13
31 2015/11/13
32 2015/11/13
33 2015/11/13
34 2015/11/13
35 2015/11/13
36 2015/11/13
37 2015/11/14
38 2015/11/14
39 2015/11/14
40 2015/11/14
41 2015/11/14
42 2015/11/14
43 2015/11/14
12:51:30
14:20:55
14:21:00
14:21:05
14:51:30
14:57:45
14:57:50
14:57:55
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
0. 0000
1.4903
1.4917
1.4931
2. 0000
2.1042
2.1056
2.1069
4. 0000
6. 0000
8. 0000
10.0000
12. 0000
14.0000
16. 0000
18.0000
20. 0000
22. 0000
24. 0000
26. 0000
28. 0000
30. 0000
32. 0000
34. 0000
36. 0000
38. 0000
40. 0000
42. 0000
44. 0000
46. 0000
48. 0000
50. 0000
52. 0000
54. 0000
56. 0000
58. 0000
60. 0000
62. 0000
64. 0000
66. 0000
68. 0000
70. 0000
72. 0000
83. 74
7506.49
7506.63
7508. 98
7899.14
7991.97
7993. 41
7934. 79
5730.61
5726. 70
5701.46
5682. 03
5665.20
5681.18
5632. 56
5646.25
5605. 02
5601.47
5584. 87
5646. 03
5574.29
5625. 96
5654. 93
5659.12
5648. 79
5644. 91
5786. 93
5785.24
5731. 73
5914.12
6015.36
5971. 84
5974. 77
6488. 67
6601.38
6642. 73
6662.91
6735. 64
6169. 54
6479. 83
6946. 88
7057. 97
7089.61
16.83
56.29
56. 33
56. 36
57.48
57.39
57. 39
57.38
57. 75
57.95
57. 96
57.96
57. 96
57.96
57. 96
57.98
57. 98
57.99
57. 99
58. 00
58. 00
58. 02
58. 03
58. 04
58. 04
58. 06
58. 09
58.10
58. 09
58.13
58.16
58.16
58.15
58.24
58.25
58.26
58.26
58.29
58.22
58. 30
58. 33
58. 33
58. 35
86.68
7505. 56
7504. 01
7508. 03
7898. 33
7938. 99
7898. 74
7852. 55
5727. 73
5730. 00
5699. 01
5676. 96
5666.49
5680. 52
5636. 71
5643. 76
5607. 33
5599. 64
5586. 06
5643.11
5574. 96
5619.28
5657. 09
5656. 85
5650. 87
5645. 66
5782. 32
5785.48
5733. 06
5913.29
6012.61
5971.69
5965. 73
6490.28
6596. 93
6646. 92
6660. 55
6731.72
6162. 36
6485.23
6949. 74
7055. 61
7087. 52
16.33
48. 88
48.97 Recorders On Bottom
49. 06
57.47
57.38
57.38 0 en Well To Flow
57.38
57. 74
57. 94
57. 95
57.95
57. 96
57.96
57. 96
57.97
57. 97
57.98
57. 98
58. 00
58. 00
58. 01
58. 02
58. 03
58. 04
58. 05
58.08
58. 09
58. 09
58.11
58.16
58.15
58.14
58.24
58.24
58.25
58.25
58.27
58.21
58.29
58. 33
58. 32
58. 34
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
0 1PDQ INarkla02-04 F&BFKT 15-Dee-15 Page 1
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
Recorders On Bottom
Open Well To Flow
16.3348.8848.9749.0657.4757.3857.3857.3857.7457.9457.9557.9557.9657.9657.9657.9757.9757.9857.9858.0058.0058.0158.0258.0358.0458.0558.0858.0958.0958.1158.1658.1558.1458.2458.2458.2558.2558.2758.2158.2958.3358.3258.34
86.687505.567504.017508.037898.337938.997898.747852.555727.735730.005699.015676.965666.495680.525636.715643.765607.335599.645586.065643.115574.965619.285657.095656.855650.875645.665782.325785.485733.065913.296012.615971.695965.736490.286596.936646.926660.556731.726162.366485.236949.747055.617087.52
16.8356.2956.3356.3657.4857.3957.3957.3857.7557.9557.9657.9657.9657.9657.9657.9857.9857.9957.9958.0058.0058.0258.0358.0458.0458.0658.0958.1058.0958.1358.1658.1658.1558.2458.2558.2658.2658.2958.2258.3058.3358.3358.35
83.747506.497506.637508.987899.147991.977993.417934.795730.615726.705701.465682.035665.205681.185632.565646.255605.025601.475584.875646.035574.295625.965654.935659.125648.795644.915786.935785.245731.735914.126015.365971.845974.776488.676601.386642.736662.916735.646169.546479.836946.887057.977089.61
0.00001.49031.49171.49312.00002.10422.10562.10694.00006.00008.0000
10.000012.000014.000016.000018.000020.000022.000024.000026.000028.000030.000032.000034.000036.000038.000040.000042.000044.000046.000048.000050.000052.000054.000056.000058.000060.000062.000064.000066.000068.000070.000072.0000
12:51:3014:20:5514:21:0014:21:0514:51:3014:57:4514:57:5014:57:5516:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:30
2015/11/112015/11/112015/11/112015/11/112015/11/112015/11/112015/11/112015/11/112015/11/112015/11/112015/11/112015/11/112015/11/122015/11/122015/11/122015/11/122015/11/122015/11/122015/11/122015/11/122015/11/122015/11/122015/11/122015/11/122015/11/132015/11/132015/11/132015/11/132015/11/132015/11/132015/11/132015/11/132015/11/132015/11/132015/11/132015/11/132015/11/142015/11/142015/11/142015/11/142015/11/142015/11/142015/11/14
123456789
10111213141516171819202122232425262728293031323334353637383940414243
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 1
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
2015/11/14
2015/11/14
2015/11/14
2015/11/14
2015/11/14
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/15
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/16
2015/11/17
2015/11/17
2015/11/17
2015/11/17
2015/11/17
2015/11/17
2015/11/17
2015/11/17
2015/11/17
2015/11/17
2015/11/17
14:51:30 74.0000 7163.38
16:51:30 76.0000 7189.99
18:51:30 78.0000 7216.89
20:51:30 80.0000 7241.55
22:51:30 82.0000 7275.77
00:51:30 84.0000 7256.88
02:51:30 86.0000 7301.56
04:51:30 88.0000 7311.52
06:51:30 90.0000 7328.95
07:59:30 91.1333 7316.98
08:00:00 91.1417 7314.44
08:00:30 91.1500 7329.87
08:51:30 92.0000 8436.38
10:51:30 94.0000 9282.68
12:51:30 96.0000 9767.18
14:51:30 98.0000 10088.31
16:51:30 100.0000 10326.72
18:51:30 102.0000 10513.58
20:51:30 104.0000 10654.85
22:51:30 106.0000 10787.71
00:51:30 108.0000 10938.22
02:51:30 110.0000 11074.24
04:51:30 112.0000 11200.36
06:51:30 114.0000 11318.00
08:51:30 116.0000 11427.58
10:51:30 118.0000 11528.49
12:51:30 120.0000 11623.87
14:51:30 122.0000 11712.83
16:51:30 124.0000 11796.42
18:51:30 126.0000 11876.95
20:51:30 128.0000 11953.57
22:51:30 130.0000 12026.90
00:51:30 132.0000 12098.42
02:51:30 134.0000 12165.89
04:51:30 136.0000 12231.14
06:51:30 138.0000 12294.73
08:51:30 140.0000 12355.59
10:51:30 142.0000 12415.20
12:51:30 144.0000 12474.38
14:51:30 146.0000 12530.89
16:51:30 148.0000 12587.59
18:51:30 150.0000 12642.33
20:51:30 152.0000 12695.87
58. 37
58. 38
58. 38
58.40
58.41
58.41
58.43
58.44
58.43
58.43
58.43
58.43
57. 96
57.68
57.60
57.56
57. 52
57.49
57.46
57.49
57.48
57.46
57.45
57.43
57.43
57.41
57. 39
57.38
57. 37
57.36
57. 36
57. 34
57. 34
57.33
57. 33
57.31
57. 32
57.31
57. 30
57.31
57. 30
57.30
57. 30
7161.81
7190.74
7212.80
7241. 04
7275.62
7257. 78
7300. 34
7308.44
7326. 51
7315.50
7312.74
7322. 61
8434.18
9280. 57
9765. 59
10087.11
10325.54
10512.67
10653.66
10786.19
10936.24
11072.81
11198.74
11316.00
11426.11
11526.88
11622.38
11711.36
11795.26
11875.37
11951.71
12024. 76
12096.82
12164.27
12230.21
12293.00
12353.94
12413.24
12472.13
12529.24
12585.94
12640.49
12694.46
58. 36
58. 37
58. 37
58. 39
58.40
58.40
58.42
58.43
58.42
58.42
58.42 Shut Well In For Buildu
58.42
57. 95
57.67
57. 59
57. 54
57.49
57.46
57.44
57.47
57.47
57.45
57.44
57.42
57.42
57.40
57. 38
57.38
57. 36
57.36
57. 35
57. 34
57. 33
57.32
57. 32
57.31
57. 31
57.30
57.29
57.29
57.29
57.29
57.29
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
D lPDQ INerkvk02-04 F&BFKT 15-Dee-15 Page 2
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
Shut Well In For Buildup
58.3658.3758.3758.3958.4058.4058.4258.4358.4258.4258.4258.4257.9557.6757.5957.5457.4957.4657.4457.4757.4757.4557.4457.4257.4257.4057.3857.3857.3657.3657.3557.3457.3357.3257.3257.3157.3157.3057.2957.2957.2957.2957.29
7161.817190.747212.807241.047275.627257.787300.347308.447326.517315.507312.747322.618434.189280.579765.59
10087.1110325.5410512.6710653.6610786.1910936.2411072.8111198.7411316.0011426.1111526.8811622.3811711.3611795.2611875.3711951.7112024.7612096.8212164.2712230.2112293.0012353.9412413.2412472.1312529.2412585.9412640.4912694.46
58.3758.3858.3858.4058.4158.4158.4358.4458.4358.4358.4358.4357.9657.6857.6057.5657.5257.4957.4657.4957.4857.4657.4557.4357.4357.4157.3957.3857.3757.3657.3657.3457.3457.3357.3357.3157.3257.3157.3057.3157.3057.3057.30
7163.387189.997216.897241.557275.777256.887301.567311.527328.957316.987314.447329.878436.389282.689767.18
10088.3110326.7210513.5810654.8510787.7110938.2211074.2411200.3611318.0011427.5811528.4911623.8711712.8311796.4211876.9511953.5712026.9012098.4212165.8912231.1412294.7312355.5912415.2012474.3812530.8912587.5912642.3312695.87
74.000076.000078.000080.000082.000084.000086.000088.000090.000091.133391.141791.150092.000094.000096.000098.0000
100.0000102.0000104.0000106.0000108.0000110.0000112.0000114.0000116.0000118.0000120.0000122.0000124.0000126.0000128.0000130.0000132.0000134.0000136.0000138.0000140.0000142.0000144.0000146.0000148.0000150.0000152.0000
14:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3007:59:3008:00:0008:00:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:30
2015/11/142015/11/142015/11/142015/11/142015/11/142015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/152015/11/162015/11/162015/11/162015/11/162015/11/162015/11/162015/11/162015/11/162015/11/162015/11/162015/11/162015/11/162015/11/172015/11/172015/11/172015/11/172015/11/172015/11/172015/11/172015/11/172015/11/172015/11/172015/11/17
44454647484950515253545556575859606162636465666768697071727374757677787980818283848586
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 2
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
87 2015/11/17
88 2015/11/18
89 2015/11/18
90 2015/11/18
91 2015/11/18
92 2015/11/18
93 2015/11/18
94 2015/11/18
95 2015/11/18
96 2015/11/18
97 2015/11/18
98 2015/11/18
99 2015/11/18
100 2015/11/19
101 2015/11/19
102 2015/11/19
103 2015/11/19
104 2015/11/19
105 2015/11/19
106 2015/11/19
107 2015/11/19
108 2015/11/19
109 2015/11/19
110 2015/11/19
111 2015/11/19
112 2015/11/20
113 2015/11/20
114 2015/11/20
115 2015/11/20
116 2015/11/20
117 2015/11/20
118 2015/11/20
119 2015/11/20
120 2015/11/20
121 2015/11/20
122 2015/11/20
123 2015/11/20
124 2015/11/21
125 2015/11/21
126 2015/11/21
127 2015/11/21
128 2015/11/21
129 2015/11/21
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
154.0000
156.0000
158.0000
160.0000
162. 0000
164.0000
166. 0000
168.0000
170.0000
172.0000
174.0000
176.0000
178.0000
180.0000
182.0000
184.0000
186.0000
188.0000
190.0000
192.0000
194.0000
196.0000
198.0000
200. 0000
202. 0000
204. 0000
206. 0000
208. 0000
210.0000
212.0000
214. 0000
216.0000
218.0000
220. 0000
222. 0000
224. 0000
226. 0000
228. 0000
230. 0000
232. 0000
234. 0000
236. 0000
238. 0000
12748.98
12799.67
12849.70
12897.62
12944.20
12990.09
13035.14
13082.01
13127.09
13169.84
13211.77
13252.23
13292.28
13331.42
13370.13
13408.07
13445.29
13481.74
13517.84
13552.88
13587.56
13622.07
13655.83
13688.96
13721.86
13753.60
13784.96
13816.00
13846.58
13877.38
13907.42
13937.33
13965.27
13994.06
14022.22
14049.88
14077.13
14104.49
14131.24
14156.67
14183.24
14208.60
14233.95
57. 30
57.29
57.29
57.29
57.28
57.28
57.29
57.29
57.28
57.28
57.28
57.28
57.28
57.27
57.28
57.28
57.28
57.28
57.28
57.27
57.28
57.28
57.28
57.28
57.28
57.28
57.28
57.28
57.28
57.28
57.28
57.29
57.28
57.28
57.29
57.29
57.29
57.28
57.29
57.29
57.29
57.30
57. 30
12747.29
12798.62
12847.58
12895.65
12942.32
12988.61
13033.13
13080.60
13125.24
13168.29
13209.58
13250.45
13290.02
13329.82
13368.18
13406.35
13443.66
13480.07
13515.80
13550.88
13585.53
13620.17
13653.89
13687.07
13719.79
13752.11
13783.59
13814.50
13844.92
13875.18
13905.23
13935.00
13963.59
13991.97
14020.63
14048.11
14075.67
14102.22
14129.20
14155.10
14181.00
14206. 39
14231.92
57.29
57.28
57.27
57.28
57.27
57.27
57.27
57.27
57.26
57.26
57.26
57.27
57.26
57.26
57.27
57.27
57.27
57.26
57.26
57.26
57.26
57.26
57.26
57.26
57.26
57.26
57.26
57.26
57.27
57.26
57.26
57.27
57.26
57.27
57.28
57.28
57.27
57.27
57.28
57.28
57.28
57.28
57.28
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
0 1PDQ INerkvk02-04 F&BFKT 15-Dee-15 Page 3
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
57.2957.2857.2757.2857.2757.2757.2757.2757.2657.2657.2657.2757.2657.2657.2757.2757.2757.2657.2657.2657.2657.2657.2657.2657.2657.2657.2657.2657.2757.2657.2657.2757.2657.2757.2857.2857.2757.2757.2857.2857.2857.2857.28
12747.2912798.6212847.5812895.6512942.3212988.6113033.1313080.6013125.2413168.2913209.5813250.4513290.0213329.8213368.1813406.3513443.6613480.0713515.8013550.8813585.5313620.1713653.8913687.0713719.7913752.1113783.5913814.5013844.9213875.1813905.2313935.0013963.5913991.9714020.6314048.1114075.6714102.2214129.2014155.1014181.0014206.3914231.92
57.3057.2957.2957.2957.2857.2857.2957.2957.2857.2857.2857.2857.2857.2757.2857.2857.2857.2857.2857.2757.2857.2857.2857.2857.2857.2857.2857.2857.2857.2857.2857.2957.2857.2857.2957.2957.2957.2857.2957.2957.2957.3057.30
12748.9812799.6712849.7012897.6212944.2012990.0913035.1413082.0113127.0913169.8413211.7713252.2313292.2813331.4213370.1313408.0713445.2913481.7413517.8413552.8813587.5613622.0713655.8313688.9613721.8613753.6013784.9613816.0013846.5813877.3813907.4213937.3313965.2713994.0614022.2214049.8814077.1314104.4914131.2414156.6714183.2414208.6014233.95
154.0000156.0000158.0000160.0000162.0000164.0000166.0000168.0000170.0000172.0000174.0000176.0000178.0000180.0000182.0000184.0000186.0000188.0000190.0000192.0000194.0000196.0000198.0000200.0000202.0000204.0000206.0000208.0000210.0000212.0000214.0000216.0000218.0000220.0000222.0000224.0000226.0000228.0000230.0000232.0000234.0000236.0000238.0000
22:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:30
2015/11/172015/11/182015/11/182015/11/182015/11/182015/11/182015/11/182015/11/182015/11/182015/11/182015/11/182015/11/182015/11/182015/11/192015/11/192015/11/192015/11/192015/11/192015/11/192015/11/192015/11/192015/11/192015/11/192015/11/192015/11/192015/11/202015/11/202015/11/202015/11/202015/11/202015/11/202015/11/202015/11/202015/11/202015/11/202015/11/202015/11/202015/11/212015/11/212015/11/212015/11/212015/11/212015/11/21
87888990919293949596979899
100101102103104105106107108109110111112113114115116117118119120121122123124125126127128129
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 3
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
130
131
132
133
134
135
136
137
138
139
140
141
142
143
144
145
146
147
148
149
150
151
152
153
154
155
156
157
158
159
160
161
162
201 5/1 1/21
2015/11/21
201 5/1 1/21
2015/11/21
201 5/1 1/21
2015/11/21
201 5/1 1/22
2015/11/22
201 5/1 1/22
2015/11/22
201 5/1 1/22
2015/11/22
201 5/1 1/22
2015/11/22
201 5/1 1/22
2015/11/22
201 5/1 1/22
2015/11/22
201 5/1 1/23
2015/11/23
201 5/1 1/23
2015/11/23
201 5/1 1/23
2015/11/23
201 5/1 1/23
2015/11/23
201 5/1 1/23
2015/11/23
201 5/1 1/23
2015/11/23
201 5/1 1/24
2015/11/24
201 5/1 1/24
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
240. 0000
242. 0000
244. 0000
246. 0000
248. 0000
250. 0000
252. 0000
254. 0000
256. 0000
258. 0000
260. 0000
262. 0000
264. 0000
266. 0000
268. 0000
270. 0000
272. 0000
274. 0000
276. 0000
278. 0000
280. 0000
282. 0000
284. 0000
286. 0000
288. 0000
290. 0000
292. 0000
294. 0000
296. 0000
298. 0000
300. 0000
302. 0000
304. 0000
14258.89
14283. 56
14308.07
14332. 35
14355.93
14379.20
14402.29
14425.48
14448.41
14470. 74
14492.31
14514.91
14536.43
14558.07
14579.31
14600. 34
14620.95
14641.61
14662.43
14682. 31
14702.20
14721. 30
14740.99
14760.26
14779.78
14798.44
14816.78
14835. 72
14853.61
14872.07
14890.29
14908.08
14925.89
57.29
57.30
57.29
57.29
57. 30
57.30
57.29
57.30
57. 30
57.31
57. 30
57.31
57. 31
57.30
57. 31
57.31
57. 31
57.31
57. 31
57.31
57. 31
57.32
57. 32
57.32
57. 32
57.32
57. 32
57.32
57. 32
57.32
57. 32
57.32
57. 33
14257.02
14281.61
14306.28
14329. 79
14353.88
14377.62
14400.74
14423.45
14445.72
14468. 72
14490.78
14512.82
14534. 83
14555.89
14577.27
14598.13
14618.84
14639.43
14659.71
14680. 36
14700.17
14719.95
14739.22
14758. 31
14777.34
14796. 30
14815.13
14833.61
14851.77
14870.29
14888.26
14906.13
14924.00
57.28
57.28
57.28
57.27
57.28
57.28
57.29
57.28
57.29
57.29
57. 29
57.29
57. 29
57.29
57. 30
57.29
57.29
57.29
57.29
57.31
57. 30
57.30
57. 30
57.30
57. 30
57.31
57. 30
57.30
57. 30
57.30
57. 30
57.30
57.31
163 201 5/1 1/24 06:51:30 306. 0000 14943.24 57.33 14941.69 57.31
164
165
166
167
168
169
170
171
172
201 5/1 1/24
2015/11/24
201 5/1 1/24
2015/11/24
201 5/1 1/24
2015/11/24
201 5/1 1/24
2015/11/24
201 5/1 1/25
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
308. 0000
310.0000
312.0000
314.0000
316.0000
318.0000
320. 0000
322. 0000
324. 0000
14961.02
14978. 52
14995.63
15012.42
15029.49
15046.30
15063.02
15079.71
15096.15
57. 33
57.33
57. 33
57.33
57. 34
57.33
57. 34
57. 34
57. 34
14959.16
14976.26
14993.54
15010.76
15027.56
15044.64
15060.84
15077.78
15094.07
57. 32
57.32
57. 31
57.31
57. 32
57.32
57. 32
57.32
57. 32
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
0 1PDQ INerkvk02-04 F&BFKT 15-Dee-15 Page 4
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
57.2857.2857.2857.2757.2857.2857.2957.2857.2957.2957.2957.2957.2957.2957.3057.2957.2957.2957.2957.3157.3057.3057.3057.3057.3057.3157.3057.3057.3057.3057.3057.3057.3157.3157.3257.3257.3157.3157.3257.3257.3257.3257.32
14257.0214281.6114306.2814329.7914353.8814377.6214400.7414423.4514445.7214468.7214490.7814512.8214534.8314555.8914577.2714598.1314618.8414639.4314659.7114680.3614700.1714719.9514739.2214758.3114777.3414796.3014815.1314833.6114851.7714870.2914888.2614906.1314924.0014941.6914959.1614976.2614993.5415010.7615027.5615044.6415060.8415077.7815094.07
57.2957.3057.2957.2957.3057.3057.2957.3057.3057.3157.3057.3157.3157.3057.3157.3157.3157.3157.3157.3157.3157.3257.3257.3257.3257.3257.3257.3257.3257.3257.3257.3257.3357.3357.3357.3357.3357.3357.3457.3357.3457.3457.34
14258.8914283.5614308.0714332.3514355.9314379.2014402.2914425.4814448.4114470.7414492.3114514.9114536.4314558.0714579.3114600.3414620.9514641.6114662.4314682.3114702.2014721.3014740.9914760.2614779.7814798.4414816.7814835.7214853.6114872.0714890.2914908.0814925.8914943.2414961.0214978.5214995.6315012.4215029.4915046.3015063.0215079.7115096.15
240.0000242.0000244.0000246.0000248.0000250.0000252.0000254.0000256.0000258.0000260.0000262.0000264.0000266.0000268.0000270.0000272.0000274.0000276.0000278.0000280.0000282.0000284.0000286.0000288.0000290.0000292.0000294.0000296.0000298.0000300.0000302.0000304.0000306.0000308.0000310.0000312.0000314.0000316.0000318.0000320.0000322.0000324.0000
12:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:30
2015/11/212015/11/212015/11/212015/11/212015/11/212015/11/212015/11/222015/11/222015/11/222015/11/222015/11/222015/11/222015/11/222015/11/222015/11/222015/11/222015/11/222015/11/222015/11/232015/11/232015/11/232015/11/232015/11/232015/11/232015/11/232015/11/232015/11/232015/11/232015/11/232015/11/232015/11/242015/11/242015/11/242015/11/242015/11/242015/11/242015/11/242015/11/242015/11/242015/11/242015/11/242015/11/242015/11/25
130131132133134135136137138139140141142143144145146147148149150151152153154155156157158159160161162163164165166167168169170171172
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 4
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
173 2015/11/25
174 2015/11/25
175 2015/11/25
176 2015/11/25
177 2015/11/25
178 2015/11/25
179 2015/11/25
180 2015/11/25
181 2015/11/25
182 2015/11/25
183 2015/11/25
184 2015/11/26
185 2015/11/26
186 2015/11/26
187 2015/11/26
188 2015/11/26
189 2015/11/26
190 2015/11/26
191 2015/11/26
192 2015/11/26
193 2015/11/26
194 2015/11/26
195 2015/11/26
196 2015/11/27
197 2015/11/27
198 2015/11/27
199 2015/11/27
200 2015/11/27
201 2015/11/27
202 2015/11/27
203 2015/11/27
204 2015/11/27
205 2015/11/27
206 2015/11/27
207 2015/11/27
208 2015/11/28
209 2015/11/28
210 2015/11/28
211 2015/11/28
212 2015/11/28
213 2015/11/28
214 2015/11/28
215 2015/11/28
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
326. 0000
328. 0000
330. 0000
332. 0000
334. 0000
336. 0000
338. 0000
340. 0000
342. 0000
344. 0000
346. 0000
348. 0000
350. 0000
352. 0000
354. 0000
356. 0000
358. 0000
360. 0000
362. 0000
364. 0000
366. 0000
368. 0000
370. 0000
372. 0000
374. 0000
376. 0000
378. 0000
380. 0000
382. 0000
384. 0000
386. 0000
388. 0000
390. 0000
392. 0000
394. 0000
396. 0000
398. 0000
400. 0000
402. 0000
404. 0000
406. 0000
408. 0000
410.0000
15112.46
15127.84
15144.37
15160.65
15176.27
15191.74
15208.14
15223.06
15238.15
15253.40
15268.76
15283.92
15299.48
15313.95
15328.79
15343.48
15357.58
15371.81
15386.80
15400.86
15415.07
15429.11
15443.16
15457.51
15470.90
15484.74
15498.87
15512.20
15525.66
15539.23
15552.21
15565.50
15578.63
15591.44
15604.67
15617.47
15630.60
15643.28
15656.08
15668.98
15681.40
15693.34
15705.92
57. 34
57. 34
57. 34
57.35
57. 35
57. 34
57. 35
57.35
57. 35
57.35
57. 35
57.36
57. 35
57.35
57. 35
57.36
57. 36
57.36
57. 36
57.36
57. 36
57.36
57. 37
57.37
57. 37
57.38
57. 37
57.36
57. 35
57.35
57. 34
57. 34
57. 34
57. 34
57. 34
57. 34
57. 33
57.36
57.40
57.39
57.40
57.39
57. 39
15110.17
15126.55
15142.26
15158.24
15174.35
15189.95
15205.73
15220.93
15236.48
15251.37
15266.23
15281.84
15297.15
15312.30
15326.78
15341.32
15355.71
15370.04
15384.58
15398.49
15412.77
15426.84
15441.28
15454.83
15469.08
15482.40
15496.21
15509.72
15523.80
15536.82
15549.87
15562.75
15576.28
15589.15
15602.32
15615.50
15628.12
15640.42
15653.35
15665.98
15678.71
15691.37
15703.54
57. 33
57.33
57. 32
57.33
57. 32
57.33
57. 33
57.33
57. 34
57.33
57. 34
57. 34
57. 33
57.33
57. 33
57.33
57. 34
57. 34
57. 34
57. 34
57. 34
57.35
57. 35
57.35
57. 36
57.36
57. 35
57.35
57. 34
57. 34
57. 33
57.33
57. 33
57.33
57. 32
57.32
57. 32
57.31
57. 38
57.39
57. 39
57.39
57. 38
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
0 1PDQ INerkvk02-04 F&BFKT 15-Dee-15 Page 5
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
57.3357.3357.3257.3357.3257.3357.3357.3357.3457.3357.3457.3457.3357.3357.3357.3357.3457.3457.3457.3457.3457.3557.3557.3557.3657.3657.3557.3557.3457.3457.3357.3357.3357.3357.3257.3257.3257.3157.3857.3957.3957.3957.38
15110.1715126.5515142.2615158.2415174.3515189.9515205.7315220.9315236.4815251.3715266.2315281.8415297.1515312.3015326.7815341.3215355.7115370.0415384.5815398.4915412.7715426.8415441.2815454.8315469.0815482.4015496.2115509.7215523.8015536.8215549.8715562.7515576.2815589.1515602.3215615.5015628.1215640.4215653.3515665.9815678.7115691.3715703.54
57.3457.3457.3457.3557.3557.3457.3557.3557.3557.3557.3557.3657.3557.3557.3557.3657.3657.3657.3657.3657.3657.3657.3757.3757.3757.3857.3757.3657.3557.3557.3457.3457.3457.3457.3457.3457.3357.3657.4057.3957.4057.3957.39
15112.4615127.8415144.3715160.6515176.2715191.7415208.1415223.0615238.1515253.4015268.7615283.9215299.4815313.9515328.7915343.4815357.5815371.8115386.8015400.8615415.0715429.1115443.1615457.5115470.9015484.7415498.8715512.2015525.6615539.2315552.2115565.5015578.6315591.4415604.6715617.4715630.6015643.2815656.0815668.9815681.4015693.3415705.92
326.0000328.0000330.0000332.0000334.0000336.0000338.0000340.0000342.0000344.0000346.0000348.0000350.0000352.0000354.0000356.0000358.0000360.0000362.0000364.0000366.0000368.0000370.0000372.0000374.0000376.0000378.0000380.0000382.0000384.0000386.0000388.0000390.0000392.0000394.0000396.0000398.0000400.0000402.0000404.0000406.0000408.0000410.0000
02:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:30
2015/11/252015/11/252015/11/252015/11/252015/11/252015/11/252015/11/252015/11/252015/11/252015/11/252015/11/252015/11/262015/11/262015/11/262015/11/262015/11/262015/11/262015/11/262015/11/262015/11/262015/11/262015/11/262015/11/262015/11/272015/11/272015/11/272015/11/272015/11/272015/11/272015/11/272015/11/272015/11/272015/11/272015/11/272015/11/272015/11/282015/11/282015/11/282015/11/282015/11/282015/11/282015/11/282015/11/28
173174175176177178179180181182183184185186187188189190191192193194195196197198199200201202203204205206207208209210211212213214215
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 5
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
216 2015/11/28
217 2015/11/28
218 2015/11/28
219 2015/11/28
220 2015/11/29
221 2015/11/29
222 2015/11/29
223 2015/11/29
224 2015/11/29
225 2015/11/29
226 2015/11/29
227 2015/11/29
228 2015/11/29
229 2015/11/29
230 2015/11/29
231 2015/11/29
232 2015/11/30
233 2015/11/30
234 2015/11/30
235 2015/11/30
236 2015/11/30
237 2015/11/30
238 2015/11/30
239 2015/11/30
240 2015/11/30
241 2015/11/30
242 2015/11/30
243 2015/11/30
244 2015/12/01
245 2015/12/01
246 2015/12/01
247 2015/12/01
248 2015/12/01
249 2015/12/01
250 2015/12/01
251 2015/12/01
252 2015/12/01
253 2015/12/01
254 2015/12/01
255 2015/12/01
256 2015/12/02
257 2015/12/02
258 2015/12/02
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
412.0000
414.0000
416.0000
418.0000
420. 0000
422. 0000
424.0000
426. 0000
428. 0000
430. 0000
432. 0000
434. 0000
436. 0000
438. 0000
440. 0000
442. 0000
444. 0000
446. 0000
448. 0000
450. 0000
452. 0000
454. 0000
456. 0000
458. 0000
460. 0000
462. 0000
464.0000
466. 0000
468. 0000
470. 0000
472. 0000
474. 0000
476. 0000
478. 0000
480. 0000
482. 0000
484. 0000
486. 0000
488. 0000
490. 0000
492. 0000
494. 0000
496. 0000
15718.13
15730.44
15742.55
15754.39
15766.60
15778.60
15789.95
15801.71
15813.77
15825.18
15836.91
15848.73
15859.97
15870.72
15882.52
15893.30
15904.42
15915.73
15926.75
15937.94
15948.42
15959.78
15971.07
15981.04
15992.29
16002.50
16013.44
16023.55
16034.41
16044.37
16055.12
16065.42
16075.94
16086.19
16095.92
16106.11
16116.15
16126.63
16136.17
16146.40
16156.13
16165.84
16175.61
57.40
57.40
57.40
57.41
57.41
57.41
57.41
57.40
57.41
57.41
57.41
57.41
57.42
57.41
57.42
57.42
57.41
57.41
57.41
57.42
57.42
57.42
57.42
57.42
57.42
57.42
57.42
57.43
57.43
57.42
57.43
57.43
57.43
57.43
57.43
57.43
57.43
57.43
57.43
57.42
57.42
57.41
57.41
15715.88
15728.02
15740.23
15751.92
15764.27
15775.94
15787.43
15799.53
15811.18
15822.66
15834.35
15845.66
15856.98
15868.80
15879.73
15890.75
15902.15
15913.46
15924.02
15935.37
15946.44
15957.16
15968.17
15978.83
15989.29
16000.15
16010.57
16020.69
16031.76
16041.82
16052.45
16062.91
16073.24
16082.93
16093.66
16103.48
16113.57
16123.48
16134.05
16143.56
16153.76
16163.18
16173.12
57. 39
57.39
57. 39
57.39
57. 39
57.40
57. 39
57.39
57.40
57.39
57. 39
57.39
57.40
57.40
57. 39
57.40
57.40
57.40
57.40
57.40
57.41
57.40
57. 39
57.40
57.41
57.41
57.40
57.41
57.40
57.41
57.41
57.41
57.41
57.41
57.40
57.41
57.41
57.41
57.42
57.41
57.40
57.40
57. 39
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
0 1PDQ INerkvk02-04 F&BFKT 15-Dee-15 Page 6
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
57.3957.3957.3957.3957.3957.4057.3957.3957.4057.3957.3957.3957.4057.4057.3957.4057.4057.4057.4057.4057.4157.4057.3957.4057.4157.4157.4057.4157.4057.4157.4157.4157.4157.4157.4057.4157.4157.4157.4257.4157.4057.4057.39
15715.8815728.0215740.2315751.9215764.2715775.9415787.4315799.5315811.1815822.6615834.3515845.6615856.9815868.8015879.7315890.7515902.1515913.4615924.0215935.3715946.4415957.1615968.1715978.8315989.2916000.1516010.5716020.6916031.7616041.8216052.4516062.9116073.2416082.9316093.6616103.4816113.5716123.4816134.0516143.5616153.7616163.1816173.12
57.4057.4057.4057.4157.4157.4157.4157.4057.4157.4157.4157.4157.4257.4157.4257.4257.4157.4157.4157.4257.4257.4257.4257.4257.4257.4257.4257.4357.4357.4257.4357.4357.4357.4357.4357.4357.4357.4357.4357.4257.4257.4157.41
15718.1315730.4415742.5515754.3915766.6015778.6015789.9515801.7115813.7715825.1815836.9115848.7315859.9715870.7215882.5215893.3015904.4215915.7315926.7515937.9415948.4215959.7815971.0715981.0415992.2916002.5016013.4416023.5516034.4116044.3716055.1216065.4216075.9416086.1916095.9216106.1116116.1516126.6316136.1716146.4016156.1316165.8416175.61
412.0000414.0000416.0000418.0000420.0000422.0000424.0000426.0000428.0000430.0000432.0000434.0000436.0000438.0000440.0000442.0000444.0000446.0000448.0000450.0000452.0000454.0000456.0000458.0000460.0000462.0000464.0000466.0000468.0000470.0000472.0000474.0000476.0000478.0000480.0000482.0000484.0000486.0000488.0000490.0000492.0000494.0000496.0000
16:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:30
2015/11/282015/11/282015/11/282015/11/282015/11/292015/11/292015/11/292015/11/292015/11/292015/11/292015/11/292015/11/292015/11/292015/11/292015/11/292015/11/292015/11/302015/11/302015/11/302015/11/302015/11/302015/11/302015/11/302015/11/302015/11/302015/11/302015/11/302015/11/302015/12/012015/12/012015/12/012015/12/012015/12/012015/12/012015/12/012015/12/012015/12/012015/12/012015/12/012015/12/012015/12/022015/12/022015/12/02
216217218219220221222223224225226227228229230231232233234235236237238239240241242243244245246247248249250251252253254255256257258
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 6
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
259 2015/12/02 06:51:30 498.0000
260 2015/12/02 08:51:30 500.0000
261 2015/12/02 10:51:30 502.0000
262 2015/12/02 12:51:30 504.0000
263 2015/12/02 14:51:30 506.0000
264 2015/12/02 16:51:30 508.0000
265 2015/12/02 18:51:30 510.0000
266 2015/12/02 20:51:30 512.0000
267 2015/12/02 22:51:30 514.0000
268 2015/12/03 00:51:30 516.0000
269 2015/12/03 02:51:30 518.0000
270 2015/12/03 04:51:30 520.0000
271 2015/12/03 06:51:30 522.0000
272 2015/12/03 08:51:30 524.0000
273 2015/12/03 10:51:30 526.0000
274 2015/12/03 12:51:30 528.0000
275 2015/12/03 14:51:30 530.0000
276 2015/12/03 16:51:30 532.0000
277 2015/12/03 18:51:30 534.0000
278 2015/12/03 20:51:30 536.0000
279 2015/12/03 22:51:30 538.0000
280 2015/12/04 00:51:30 540.0000
281 2015/12/04 02:51:30 542.0000
282 2015/12/04 04:51:30 544.0000
283 2015/12/04 06:51:30 546.0000
284 2015/12/04 08:51:30 548.0000
285 2015/12/04 10:51:30 550.0000
286 2015/12/04 12:51:30 552.0000
287 2015/12/04 14:51:30 554.0000
288 2015/12/04 16:51:30 556.0000
289 2015/12/04 18:51:30 558.0000
290 2015/12/04 20:51:30 560.0000
291 2015/12/04 22:51:30 562.0000
292 2015/12/05 00:51:30 564.0000
293 2015/12/05 02:51:30 566.0000
294 2015/12/05 04:51:30 568.0000
295 2015/12/05 06:51:30 570.0000
296 2015/12/05 08:51:30 572.0000
297 2015/12/05 10:51:30 574.0000
298 2015/12/05 12:51:30 576.0000
299 2015/12/05 14:51:30 578.0000
300 2015/12/05 16:51:30 580.0000
301 2015/12/05 18:51:30 582.0000
16185.73
16196.02
16205.91
16215.92
16226.44
16235.76
16245.61
16254.95
16264.95
16273.92
16283.78
16292.84
16302.40
16311.68
16321.27
16329.91
16339.09
16348.21
16357.22
16366.46
16374.74
16383.35
16392.21
16400.97
16410.07
16417.98
16426.44
16435.33
16443.59
16452.28
16460.71
16469.35
16477.60
16485.66
16494.12
16502.26
16510.60
16518.48
16526.61
16534.96
16542.43
16551.20
16558.72
57.40 16183.17
57.40 16193.11
57.41 16203.29
57.40 16213.84
57.39 16223.66
57.40 16233.31
57.40 16242.75
57.40 16252.55
57.45 16261.69
57.45 16271.79
57.45 16281.15
57.44 16290.52
57.44 16299.50
57.44 16308.75
57.44 16318.02
57.44 16327.48
57.45 16336.07
57.45 16345.31
57.45 16354.28
57.45 16363.54
57.46 16371.83
57.46 16380.70
57.46 16389.69
57.46 16398.29
57.46 16407.07
57.46 16415.40
57.46 16424.25
57.46 16432.67
57.46 16440.87
57.46 16449.46
57.46 16458.21
57.45 16466.56
57.45 16474.51
57.45 16483.12
57.44 16491.25
57.44 16499.70
57.44 16507.97
57.43 16516.21
57.43 16524.33
57.43 16532.64
57.43 16540.35
57.43 16548.25
57.42 16556.60
57. 39
57.39
57.40
57.39
57. 38
57.38
57. 38
57.37
57. 38
57.44
57.44
57.44
57.43
57.43
57.43
57.44
57.44
57.44
57.44
57.44
57.44
57.45
57.44
57.45
57.44
57.45
57.45
57.44
57.44
57.44
57.45
57.44
57.44
57.44
57.43
57.43
57.43
57.43
57.42
57.42
57.41
57.41
57.41
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
0 1PDQ INerkvk02-04 F&BFKT 15-Dee-15 Page 7
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
57.3957.3957.4057.3957.3857.3857.3857.3757.3857.4457.4457.4457.4357.4357.4357.4457.4457.4457.4457.4457.4457.4557.4457.4557.4457.4557.4557.4457.4457.4457.4557.4457.4457.4457.4357.4357.4357.4357.4257.4257.4157.4157.41
16183.1716193.1116203.2916213.8416223.6616233.3116242.7516252.5516261.6916271.7916281.1516290.5216299.5016308.7516318.0216327.4816336.0716345.3116354.2816363.5416371.8316380.7016389.6916398.2916407.0716415.4016424.2516432.6716440.8716449.4616458.2116466.5616474.5116483.1216491.2516499.7016507.9716516.2116524.3316532.6416540.3516548.2516556.60
57.4057.4057.4157.4057.3957.4057.4057.4057.4557.4557.4557.4457.4457.4457.4457.4457.4557.4557.4557.4557.4657.4657.4657.4657.4657.4657.4657.4657.4657.4657.4657.4557.4557.4557.4457.4457.4457.4357.4357.4357.4357.4357.42
16185.7316196.0216205.9116215.9216226.4416235.7616245.6116254.9516264.9516273.9216283.7816292.8416302.4016311.6816321.2716329.9116339.0916348.2116357.2216366.4616374.7416383.3516392.2116400.9716410.0716417.9816426.4416435.3316443.5916452.2816460.7116469.3516477.6016485.6616494.1216502.2616510.6016518.4816526.6116534.9616542.4316551.2016558.72
498.0000500.0000502.0000504.0000506.0000508.0000510.0000512.0000514.0000516.0000518.0000520.0000522.0000524.0000526.0000528.0000530.0000532.0000534.0000536.0000538.0000540.0000542.0000544.0000546.0000548.0000550.0000552.0000554.0000556.0000558.0000560.0000562.0000564.0000566.0000568.0000570.0000572.0000574.0000576.0000578.0000580.0000582.0000
06:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:30
2015/12/022015/12/022015/12/022015/12/022015/12/022015/12/022015/12/022015/12/022015/12/022015/12/032015/12/032015/12/032015/12/032015/12/032015/12/032015/12/032015/12/032015/12/032015/12/032015/12/032015/12/032015/12/042015/12/042015/12/042015/12/042015/12/042015/12/042015/12/042015/12/042015/12/042015/12/042015/12/042015/12/042015/12/052015/12/052015/12/052015/12/052015/12/052015/12/052015/12/052015/12/052015/12/052015/12/05
259260261262263264265266267268269270271272273274275276277278279280281282283284285286287288289290291292293294295296297298299300301
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 7
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
302 2015/12/05 20:51:30
303 2015/12/05 22:51:30
304 2015/12/06 00:51:30
305 2015/12/06 02:51:30
306 2015/12/06 04:51:30
307 2015/12/06 06:51:30
308 2015/12/06 08:51:30
309 2015/12/06 10:51:30
310 2015/12/06 12:51:30
311 2015/12/06 14:51:30
312 2015/12/06 16:51:30
313 2015/12/06 18:51:30
314 2015/12/06 20:51:30
315 2015/12/06 22:51:30
316 2015/12/07 00:51:30
317 2015/12/07 02:51:30
318 2015/12/07 04:51:30
319 2015/12/07 06:51:30
320 2015/12/07 08:51:30
321 2015/12/07 10:51:30
322 2015/12/07 12:51:30
323 2015/12/07 14:51:30
324 2015/12/07 16:51:30
325 2015/12/07 18:51:30
326 2015/12/07 20:51:30
327 2015/12/07 22:51:30
328 2015/12/08 00:51:30
329 2015/12/08 02:51:30
330 2015/12/08 04:51:30
331 2015/12/08 06:51:30
332 2015/12/08 08:51:30
333 2015/12/08 10:51:30
334 2015/12/08 12:51:30
335 2015/12/08 14:51:30
336 2015/12/08 16:51:30
337 2015/12/08 18:51:30
338 2015/12/08 20:51:30
339 2015/12/08 22:51:30
340 2015/12/09 00:51:30
341 2015/12/09 02:51:30
342 2015/12/09 04:51:30
343 2015/12/09 06:51:30
344 2015/12/09 08:51:30
584. 0000
586. 0000
588. 0000
590. 0000
592. 0000
594. 0000
596. 0000
598. 0000
600. 0000
602. 0000
604. 0000
606. 0000
608. 0000
610.0000
612.0000
614.0000
616.0000
618.0000
620. 0000
622. 0000
624. 0000
626. 0000
628. 0000
630. 0000
632. 0000
634. 0000
636. 0000
638. 0000
640. 0000
642. 0000
644. 0000
646.0000
648. 0000
650. 0000
652. 0000
654. 0000
656. 0000
658. 0000
660. 0000
662. 0000
664. 0000
666. 0000
668. 0000
16566.78
16575.29
16583.24
16590.75
16598.10
16606.13
16613.75
16621.51
16629.04
16636.81
16644.04
16651.29
16658.84
16666.24
16674.42
16681.47
16689.15
16696.59
16703.89
16711.52
16718.70
16725.55
16733.04
16739.90
16746.92
16754.22
16761.34
16768.63
16775.04
16782.38
16789.40
16796.44
16803.48
16809.96
16816.92
16823.75
16830.42
16837.43
16844.07
16850.80
16857.39
16864.11
16870.61
57.42 16564.48
57.42 16572.14
57.42 16580.12
57.42 16587.75
57.42 16595.57
57.42 16603.29
57.43 16611.34
57.48 16618.64
57.50 16626.52
57.51 16633.68
57.50 16641.72
57.50 16648.46
57.49 16656.54
57.50 16664.10
57.50 16671.55
57.50 16679.00
57.50 16686.19
57.50 16694.05
57.50 16700.95
57.51 16708.76
57.50 16715.76
57.51 16723.15
57.50 16730.38
57.50 16737.29
57.51 16744.57
57.51 16751.63
57.51 16758.62
57.51 16765.81
57.51 16773.06
57.51 16779.73
57.51 16786.36
57.51 16793.23
57.51 16800.70
57.51 16807.16
57.51 16814.28
57.51 16820.27
57.51 16827.77
57.52 16834.38
57.51 16841.55
57.51 16848.19
57.52 16854.78
57.52 16861.57
57.52 16867.92
57.41
57.41
57.41
57.41
57.41
57.41
57.41
57.41
57.46
57.50
57.49
57.49
57.49
57.49
57.49
57.49
57.48
57.49
57.48
57.49
57.48
57.50
57.49
57.49
57.49
57.50
57.49
57.49
57.49
57.49
57.48
57.49
57.49
57.49
57.49
57.50
57.49
57.50
57. 50
57.50
57.49
57.50
57.49
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Ver
0 1PDQ INerkvk02-04 F&BFKT 15-Dee-15 Page 8
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
57.4157.4157.4157.4157.4157.4157.4157.4157.4657.5057.4957.4957.4957.4957.4957.4957.4857.4957.4857.4957.4857.5057.4957.4957.4957.5057.4957.4957.4957.4957.4857.4957.4957.4957.4957.5057.4957.5057.5057.5057.4957.5057.49
16564.4816572.1416580.1216587.7516595.5716603.2916611.3416618.6416626.5216633.6816641.7216648.4616656.5416664.1016671.5516679.0016686.1916694.0516700.9516708.7616715.7616723.1516730.3816737.2916744.5716751.6316758.6216765.8116773.0616779.7316786.3616793.2316800.7016807.1616814.2816820.2716827.7716834.3816841.5516848.1916854.7816861.5716867.92
57.4257.4257.4257.4257.4257.4257.4357.4857.5057.5157.5057.5057.4957.5057.5057.5057.5057.5057.5057.5157.5057.5157.5057.5057.5157.5157.5157.5157.5157.5157.5157.5157.5157.5157.5157.5157.5157.5257.5157.5157.5257.5257.52
16566.7816575.2916583.2416590.7516598.1016606.1316613.7516621.5116629.0416636.8116644.0416651.2916658.8416666.2416674.4216681.4716689.1516696.5916703.8916711.5216718.7016725.5516733.0416739.9016746.9216754.2216761.3416768.6316775.0416782.3816789.4016796.4416803.4816809.9616816.9216823.7516830.4216837.4316844.0716850.8016857.3916864.1116870.61
584.0000586.0000588.0000590.0000592.0000594.0000596.0000598.0000600.0000602.0000604.0000606.0000608.0000610.0000612.0000614.0000616.0000618.0000620.0000622.0000624.0000626.0000628.0000630.0000632.0000634.0000636.0000638.0000640.0000642.0000644.0000646.0000648.0000650.0000652.0000654.0000656.0000658.0000660.0000662.0000664.0000666.0000668.0000
20:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:30
2015/12/052015/12/052015/12/062015/12/062015/12/062015/12/062015/12/062015/12/062015/12/062015/12/062015/12/062015/12/062015/12/062015/12/062015/12/072015/12/072015/12/072015/12/072015/12/072015/12/072015/12/072015/12/072015/12/072015/12/072015/12/072015/12/072015/12/082015/12/082015/12/082015/12/082015/12/082015/12/082015/12/082015/12/082015/12/082015/12/082015/12/082015/12/082015/12/092015/12/092015/12/092015/12/092015/12/09
302303304305306307308309310311312313314315316317318319320321322323324325326327328329330331332333334335336337338339340341342343344
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 8
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
SUBSURFACE PRESSURE MEASUREMENTS
Run depths quoted below are mKB MD
ARCRES HZ N RED A02-04Formation: Montney
Date Clk Time
Accum. Bot Rec.
Time Pres.
Bot Rec.
Temp.
Top Rec. Top Rec.
Pres. Temp. Comment
yyyy/mm/dd hh:mm:ss hr kPa(a) C kPa(a) C
345 2015/12/09
346 2015/12/09
347 2015/12/09
348 2015/12/09
349 2015/12/09
350 2015/12/09
351 2015/12/09
352 2015/12/10
353 2015/12/10
354 2015/12/10
355 2015/12/10
356 2015/12/10
357 2015/12/10
358 2015/12/10
359 2015/12/10
360 2015/12/10
361 2015/12/10
362 2015/12/10
363 2015/12/10
364 2015/12/11
365 2015/12/11
366 2015/12/11
367 2015/12/11
368 2015/12/11
369 2015/12/11
370 2015/12/11
371 2015/12/11
372 2015/12/11
373 2015/12/11
374 2015/12/11
375 2015/12/11
376 2015/12/12
377 2015/12/12
378 2015/12/12
379 2015/12/12
380 2015/12/12
381 2015/12/12
382 2015/12/12
383 2015/12/12
384 2015/12/12
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
10:51:30
12:51:30
14:51:30
16:51:30
18:51:30
20:51:30
22:51:30
00:51:30
02:51:30
04:51:30
06:51:30
08:51:30
09:28:30
09:29:00
09:29:30
10:32:59
670.0000 16877.32
672.0000 16883.84
674.0000 16890.46
676.0000 16897.41
678.0000 16903.69
680.0000 16910.00
682.0000 16916.39
684.0000 16922.60
686.0000 16929.54
688.0000 16936.06
690.0000 16942.10
692.0000 16948.51
694.0000 16954.50
696.0000 16961.09
698.0000 16967.43
700.0000 16973.30
702.0000 16979.59
704.0000 16985.84
706.0000 16991.68
708.0000 16998.01
710.0000 17004.07
712.0000 17010.35
714.0000 17016.38
716.0000 17022.24
718.0000 17028.52
720.0000 17034.33
722.0000 17040.87
724.0000 17046.24
726.0000 17052.29
728.0000 17058.35
730.0000 17064.23
732.0000 17070.08
734.0000 17075.94
736.0000 17081.48
738.0000 17087.86
740.0000 17093.44
740.6166 17094.30
740.6250 17094.35
740.6334 17004.54
97.90741. 6914
57. 52
57.52
57. 52
57.52
57. 52
57.53
57. 52
57.52
57. 53
57.53
57. 53
57.53
57. 53
57.53
57. 53
57.53
57. 52
57.53
57. 53
57.53
57. 54
57.53
57. 53
57.53
57. 54
57.53
57. 54
57.53
57. 54
57. 54
57. 54
57. 54
57. 55
57.53
57. 54
57. 54
57. 51
57.51
57. 50
-3. 96
16874.64
16881.00
16887.82
16894.61
16901.06
16907.39
16913.98
16919.98
16926.62
16933.57
16939.42
16945.79
16952.22
16958.31
16964.73
16970.64
16976.72
16983.10
16989.71
16995.11
17001.39
17007.50
17013.78
17019.64
17025.90
17031.91
17038.06
17043.74
17049.58
17055.95
17061.31
17067.23
17073.20
17079.23
17084.98
17090.63
17091.53
17091.86
17019.87
103.21
57.49
57.49
57.49
57.51
57. 50
57.50
57. 51
57.51
57. 51
57.50
57. 51
57.51
57. 52
57.51
57. 51
57.51
57. 51
57.50
57. 51
57.51
57. 52
57.51
57. 52
57.51
57. 51
57.51
57. 52
57.51
57. 52
57.52
57. 51
57.52
57. 52
57.52
57. 52
57.52
57. 50
57.49 Recorders Off Bottom
57.49
-3. 58
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10
Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
heal™Vakdata™Var
0 1PDQ Vrarkvk02-04 F&BFKT 15-Daa-15 Page 9
SUBSURFACE PRESSURE MEASUREMENTSRun depths quoted below are mKB MD
ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/11/11Final Test Date: 2015/12/12
Bot Rec. Serial Number: 1866 Start Date: 2015/11/11 12:51:30 Run Depth: 1632.10Top Rec. Serial Number: 1865 Start Date: 2015/11/11 12:51:30 Run Depth: 1631.60Print Filter: Print every 2 hour
CommentTop Rec.
Temp.
°C
Top Rec.Pres.
kPa(a)
Bot Rec.Temp.
°C
Bot Rec.Pres.
kPa(a)
Accum.Time
hr
Clk Time
hh:mm:ss
Date
yyyy/mm/dd
Recorders Off Bottom
57.4957.4957.4957.5157.5057.5057.5157.5157.5157.5057.5157.5157.5257.5157.5157.5157.5157.5057.5157.5157.5257.5157.5257.5157.5157.5157.5257.5157.5257.5257.5157.5257.5257.5257.5257.5257.5057.4957.49-3.58
16874.6416881.0016887.8216894.6116901.0616907.3916913.9816919.9816926.6216933.5716939.4216945.7916952.2216958.3116964.7316970.6416976.7216983.1016989.7116995.1117001.3917007.5017013.7817019.6417025.9017031.9117038.0617043.7417049.5817055.9517061.3117067.2317073.2017079.2317084.9817090.6317091.5317091.8617019.87
103.21
57.5257.5257.5257.5257.5257.5357.5257.5257.5357.5357.5357.5357.5357.5357.5357.5357.5257.5357.5357.5357.5457.5357.5357.5357.5457.5357.5457.5357.5457.5457.5457.5457.5557.5357.5457.5457.5157.5157.50-3.96
16877.3216883.8416890.4616897.4116903.6916910.0016916.3916922.6016929.5416936.0616942.1016948.5116954.5016961.0916967.4316973.3016979.5916985.8416991.6816998.0117004.0717010.3517016.3817022.2417028.5217034.3317040.8717046.2417052.2917058.3517064.2317070.0817075.9417081.4817087.8617093.4417094.3017094.3517004.54
97.90
670.0000672.0000674.0000676.0000678.0000680.0000682.0000684.0000686.0000688.0000690.0000692.0000694.0000696.0000698.0000700.0000702.0000704.0000706.0000708.0000710.0000712.0000714.0000716.0000718.0000720.0000722.0000724.0000726.0000728.0000730.0000732.0000734.0000736.0000738.0000740.0000740.6166740.6250740.6334741.6914
10:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3010:51:3012:51:3014:51:3016:51:3018:51:3020:51:3022:51:3000:51:3002:51:3004:51:3006:51:3008:51:3009:28:3009:29:0009:29:3010:32:59
2015/12/092015/12/092015/12/092015/12/092015/12/092015/12/092015/12/092015/12/102015/12/102015/12/102015/12/102015/12/102015/12/102015/12/102015/12/102015/12/102015/12/102015/12/102015/12/102015/12/112015/12/112015/12/112015/12/112015/12/112015/12/112015/12/112015/12/112015/12/112015/12/112015/12/112015/12/112015/12/122015/12/122015/12/122015/12/122015/12/122015/12/122015/12/122015/12/122015/12/12
345346347348349350351352353354355356357358359360361362363364365366367368369370371372373374375376377378379380381382383384
Validata Ver TM
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Page 9
ARC RESOURCES LTD.
1 00/01-34-085-22W6/02
Start Test Date: 2015/1 1/11
Final Test Date: 2015/12/12
18000
FLOW II BUILDUP
ARCRES HZ N RED A02-04
Formation: Montney
16200
14400
12600
mm 10800
m m
0 Ik
e'
mm
re re9000
0 Ik
n n
mm
IDIn 7200
62~01
menn
me
618 8
me
mm
EE
me
600 Fk
5400
3600
1800
0:00 3:16:22
2015/11I10 11I13
6:32:44 9:49:05 13:05:27 16:21:49 19:38:11
11/16 11/19 11/22 11I25 11I28
TIME
22:54:33 2:10:55 5:27:16 8:43:38 12:00
12I1 12/5 12/8 12I11 12I14
C IPDQ Werkr002 04 F&0 FKF 15 Der15 Ver
FLOW & BUILDUP
TIME
Top
Rec
. Pre
ssur
e , k
Pa(a
)Bo
t Rec
. Pre
ssur
e , k
Pa(a
) Top Rec. Tem
perature , °CBot R
ec. Temperature , °C
0:002015/11/10
3:16:2211/13
6:32:4411/16
9:49:0511/19
13:05:2711/22
16:21:4911/25
19:38:1111/28
22:54:3312/1
2:10:5512/5
5:27:1612/8
8:43:3812/11
12:0012/14
0
1800
3600
5400
7200
9000
10800
12600
14400
16200
18000
56
57
58
59
60
61
62
63
64
65
66
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/11/11Final Test Date: 2015/12/12
ARCRES HZ N RED A02-04Formation: Montney
C:\PDQ Work\A02-04 F&B.FKT 15-Dec-15 Ver
RESERVOIR PRESSURESURVEY TEST REPORT
COMMISSION Mailmg AddressWell Data Management300-395 Harbour RoadVictoria BC V9A087
Phone (250)4)9-4400Fax (250) 419-4402
Date Received
Farm must be submitted under the suthanty of the Oil snd Gas Activities Act SBC. 2008, c 36, Dnlling snd Production Regulstian, s 73(3) ta the Oilsnd Gss Commission, at the address noted above, accompanied by the test data snd analysis. /nformatian collected on this farm will be used forpublic record in accordance with s 38 of the Oil snd Gss Activities Act General Regulatian.
WELL INFORMATION
Well Name: ARCRES HZ N RED A02-04-086-22 W6
BH Location: 100/01-34-085-22 W6/02
Well Permit Nod 29042
K.B. 690.00 m
Field: Attachie Pool: Montney C.F. 684.90 m
Completion Interval: 1727.89 —1715.89 mKB TVD Mid-point of Completion (MPP): 1721.89 mKB TVD
Well Type: vertical directional horizontal >< Fluid Type: gas >< oil water ><
Test Date (yyyyimmidd): 2015/12/12
Shut-in days (to the nearest smgie deamai): 27.1
Liquid Level in We))bore: 1012.09 mCF (TVD)
TEST DATA
Test Type: SG X DFFO PGFO OTHER
PG CS AWS
PGBU CSBU AWSBU
Temperature @ Run Depth
58 'C
We))bore Gradient @ Run Depth(tc three deomal places)
10.718 kPa/m
Formation Gradient(to three deomai places)
1.198 kPa/m
Reservoir Pressure
Static Pressure: 17094.35 kPa g a ><
@ a Run Depth of: 1917.56 mCF (TVD)
Extrapolated Reservoir Pressure, P* or
Calculated Reservoir Pressure, Pr
Last Measured Pressure**
Last Measured Pressure: kPa g a ><
@ a Run Depth of: mCF (TVD)
Pressure Building @ kPa/hr
(** reported for build-up and fat)-off pressure tests only)
COMPANY INFORMATION
Date: 2015/12/15 Phone:
Completed by: PDQ Services Ltd. [email protected] Company: ARC Resources Ltd.
Email:
Reservoir Pressure Survey Test Report FormUpdated: 15 December 2015
Effective: 1-May-2013
RESERVOIR PRESSURESURVEY TEST REPORT
Date Received
Mailing Address:Well Data Management 300-398 Harbour Road Victoria BC V9A 0B7
Phone: (250) 419-4400Fax: (250) 419-4402
Form must be submitted under the authority of the Oil and Gas Activities Act S.B.C. 2008, c. 36, Drilling and Production Regulation, s.73(3) to the Oil and Gas Commission, at the address noted above, accompanied by the test data and analysis. Information collected on this form will be used for public record in accordance with s. 38 of the Oil and Gas Activities Act General Regulation.
WELL INFORMATION
Well Name: ARCRES HZ N RED A02-04-086-22 W6 Well Permit No.: 29042
BH Location: 100/01-34-085-22 W6/02 K.B. 690.00 m
Field: Attachie Pool: Montney C.F. 684.90 m
Completion Interval: 1727.89 – 1715.89 mKB TVD Mid-point of Completion (MPP): 1721.89 mKB TVD
Well Type: vertical directional horizontal Fluid Type: gas oil water
TEST DATA
Test Date (yyyy/mm/dd): 2015/12/12 Test Type: SG DFFO PGFO OTHER
Shut-in days (to the nearest single decimal): 27.1 PG CS AWS
Liquid Level in Wellbore: 1012.09 mCF (TVD) PGBU CSBU AWSBU
Temperature @ Run Depth
58 C
Wellbore Gradient @ Run Depth(to three decimal places)
10.718 kPa/m
Formation Gradient(to three decimal places)
1.198 kPa/m
Reservoir Pressure Last Measured Pressure**
Static Pressure: 17094.35 kPa g a Last Measured Pressure: kPa g a
@ a Run Depth of: 1917.56 mCF (TVD) @ a Run Depth of: mCF (TVD)
Extrapolated Reservoir Pressure, P* or Pressure Building @ kPa/hr
Calculated Reservoir Pressure, Pr (** reported for build-up and fall-off pressure tests only)
Comments: Pressure builds approx. 2 kPa on bottom stop. (1 hour)
COMPANY INFORMATION
Completed by: PDQ Services Ltd. [email protected] Company: ARC Resources Ltd.
Date: 2015/12/15 Phone: Email:
Reservoir Pressure Survey Test Report FormUpdated: 15 December 2015
Effective: 1-May-2013
Company: ARC RESOURCES LTD.Well Name: ARCRES HZ N RED A02-04-086-22 W6Bottom Hole Location: 100/07-34-085-22 W6/02WA¹ 29042Formation: MontneyType of Test: Static GradientDate of Test: 2015/12/12
Test by RAPID WIRELINE SERVICES LTD.Report by PDQ SERVICES LTD.
Company: ARC RESOURCES LTD. Well Name: ARCRES HZ N RED A02-04-086-22 W6 Bottom Hole Location: 100/01-34-085-22 W6/02 WA# 29042 Formation: Montney Type of Test: Static Gradient Date of Test: 2015/12/12
Test by RAPID WIRELINE SERVICES LTD. Report by PDQ SERVICES LTD.
General Information - STATIC GRADIENT
ARCRES HZ N RED A02-04100/01-34-085-22W6/02
A02-04-086-22 W629042
AttachieHorizontal
Test Information
Company Name ARC RESOURCES LTD.ContactWell NameUnique Well IDSurface LocationWell License NumberFieldWell Type
KB Elevation (SL)CF Elevation (SL)GL Elevation (SL)KB-CF OffsetKB-GL Offset
690.00 m684.90 m684.10 m
5.10 m5.90 m
Test TypeFormationWell Fluid TypeTest Purpose (AEUB)H25
Test/Production Interval
Static GradientMontney06 Water
Initial Test0.0 ppm
Job NumberRepresentativeWe II 0 peratorReport DatePrepared By
2015/12/15PDQ Services Ltd.
Top(Log KB)Bottom(Log KB)MPP(Log KB)
Start Test DateFinal Test DateDate Well Shut-InFlow Duration
2866.00 m Top(TVD KB)4211.00 m Bottom(TVD KB)3538.50 m MPP(TVD KB)
2015/12/12 Start Test Time2015/12/12 Final Test Time2015/11/15 Time Well Shut-In89.0361 hrs Shut-In Duration
1727.89 m1715.89 m1721.89 m
08:29:0010:19:0008:00:00649.4833 hrs
Tubing Pressure: InitialTubing Pressure: Final
Wellbore Information
9400.00 kPa(a) Casing Pressure: Initial9400.00 kPa(a) Casing Pressure: Final
9400.00 kPa(a)9400.00 kPa(a)
Flow PathTubing IDTubing ODTubing Depth(Log KB)Casing Depth(Log KB)Packer Depth(Log KB)PBTD(Log KB)
Test Results
Gauge NameGauge Serial NumberRun Depth (TVD KB)Pressure at Run DepthPressure at MPPTemperature at Run DepthLiquid Level(TVD KB)
Tubing62.0 mm73.0 mm
1653.57000 m4255.00000 m
mm
Bot Rec.1866
1622.66 m17094.35 kPa(a)18157.90 kPa(a)
57.5 'C1017.19 m
Completion TypeCasing IDCasing ODTubing Depth(TVD KB)Casing Depth(TVD KB)Packer Depth(TVD KB)PBTD(TVD KB)
Gauge NameGauge Serial NumberRun Depth (TVD KB)Pressure at Run DepthPressure at MPPTemperature at Run DepthLiquid Level(TVD KB)
Perforated99.6 mm
114.3 mm1641.17939 m1715.84000 m
mm
Top Rec.1865
1622.22 m17091.86 kPa(a)18156.78 kPa(a)
57.5 'C1016.87 m
REMARKS: Pressure builds approx. 2 kPa on bottom stop. (1 hour)
heal™Vakdala™Ver 7 1 2 6
0 WCO WerklA02-04 5G PKT 15-Cee-15
General Information - STATIC GRADIENT
Contact Well Name ARCRES HZ N RED A02-04 Unique Well ID 100/01-34-085-22W6/02 Surface Location A02-04-086-22 W6 Well License Number 29042 Field Attachie Well Type Horizontal
Test Type Static Gradient Formation Montney Well Fluid Type 06 Water Test Purpose (AEUB) Initial Test H2S 0.0 ppm
Top(Log KB) 2866.00 m Bottom(Log KB) 4211.00 m MPP(Log KB) 3538.50 m
Start Test Date 2015/12/12 Final Test Date 2015/12/12 Date Well Shut-In 2015/11/15 Flow Duration 89.0361 hrs
Tubing Pressure: Initial 9400.00 kPa(a) Tubing Pressure: Final 9400.00 kPa(a)
Flow Path Tubing Tubing ID 62.0 mm Tubing OD 73.0 mm Tubing Depth(Log KB) 1653.57000 m Casing Depth(Log KB) 4255.00000 m Packer Depth(Log KB) m PBTD(Log KB) m
Gauge Name Bot Rec. Gauge Serial Number 1866 Run Depth (TVD KB) 1622.66 m Pressure at Run Depth 17094.35 kPa(a) Pressure at MPP 18157.90 kPa(a) Temperature at Run Depth 57.5 °C Liquid Level(TVD KB) 1017.19 m
KB Elevation (SL) 690.00 m CF Elevation (SL) 684.90 m GL Elevation (SL) 684.10 m KB-CF Offset 5.10 m KB-GL Offset 5.90 m
Job Number Representative Well Operator Report Date 2015/12/15 Prepared By PDQ Services Ltd.
Top(TVD KB) 1727.89 m Bottom(TVD KB) 1715.89 m MPP(TVD KB) 1721.89 m
Start Test Time 08:29:00 Final Test Time 10:19:00 Time Well Shut-In 08:00:00 Shut-In Duration 649.4833 hrs
Casing Pressure: Initial 9400.00 kPa(a) Casing Pressure: Final 9400.00 kPa(a)
Completion Type Perforated Casing ID 99.6 mm Casing OD 114.3 mm Tubing Depth(TVD KB) 1641.17939 m Casing Depth(TVD KB) 1715.84000 m Packer Depth(TVD KB) m PBTD(TVD KB) m
Gauge Name Top Rec. Gauge Serial Number 1865 Run Depth (TVD KB) 1622.22 m Pressure at Run Depth 17091.86 kPa(a) Pressure at MPP 18156.78 kPa(a) Temperature at Run Depth 57.5 °C Liquid Level(TVD KB) 1016.87 m
Test Information
REMARKS: Pressure builds approx. 2 kPa on bottom stop. (1 hour)
Test Results
Company Name ARC RESOURCES LTD.
Test/Production Interval
Wellbore Information
Validata Ver 7.1.2.6TM
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15Validata Ver 7.1.2.6TM
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15
Top Rec.
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/12/12Final Test Date: 2015/12/12
ARCRES HZ N RED A02-04Formation: Montney
~To Rec.
Gauge Serial NumberGauge ManufacturerRun Depth (Log KB)Gauge Start Date
Date Gauge On Bottom
1865
Rockdata
1631.60 m
2015/11/11 12:51:30
2015/12/12 08:29:00
Gauge TypeMaximum Recorder RangeDate of Last Calibration
Gauge Stop Date
Date Gauge Off Bottom
Strain
41470.00 kPa(a)2015/09/23
2015/12/12 10:33:00
2015/12/12 09:29:00
Test Data
Top(TVD KB)Pool Datum Depth (SS)Tubing Pressure: Initial
Casing Pressure: Initial
Start Test Date
1727.89 m Bottom(TVD KB)m Well Datum Depth
9400.00 kPa(a) Tubing Pressure: Final
9400.00 kPa(a) Casing Pressure: Final
2015/12/12 08:29:00 Date Well Shut-In
1715.89 m
1721.89 m
9400.00 kPa(a)9400.00 kPa(a)
2015/11/15 08:00:00
Depth Log tn Depthm m
Timehh:mm:ss
Durationmin
PressurekPa(a)
GradientkPa/m
Temp. Gradient'C C/m
1622.22 1631.60 08:39:00
1622.22 1631.60 08:49:00
1622.22 1631.60 08:59:00
1622.22 1631.60 09:09:00
1622.22 1631.60 09:19:00
1622.22 1631.60 09:29:00
1598.32 1604.60 09:34:00
1504.30 1504.60 09:41:00
1204.56 1204.60 09:48:00
10.00
10.00
10.00
10.00
10.00
10.00
5.00
7.00
7.00
904. 57
604. 57
304. 57
4. 60
904.60 09:56:00
604.60 10:03:00
304.60 10:10:00
4.60 10:18:59
8.00
7.00
7.00
8.99
1622.22 1631.60 08:29:00 44288.00 17089.71
17090.17
17090.90
17090.97
17091.88
17087.18
17091.86
1 6846. 59
15814.29
12621.70
10600.81
10112.38
9761.19
9410.69
10.260
10.980
10.651
6.737
1.628
1.171
1.168
57.52
57.52
57.52
57.52
57.52
57.52
57.49
57.24
56.07
51.95
42.46
33.84
23.19
4. 31
0.011
0.012
0.014
0.032
0.029
0.036
0.063
Results
Gas
Water1.253 kPa/m Gas - Water Interface
10.685 kPa/mWell Datum Depth
1016.87 m 10656.03 kPa(a)
1721.89 m 18156.78 kPa(a)
heal™Vakdata™
0 rPDQ INarkrrk02-04 GG PKT 15-Dee-15
Top Rec.ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/12/12Final Test Date: 2015/12/12
ValidataTM
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15
Top Rec.
Gauge Serial Number 1865 Gauge Type StrainGauge Manufacturer Rockdata Maximum Recorder Range 41470.00 kPa(a)Run Depth (Log KB) 1631.60 m Date of Last Calibration 2015/09/23Gauge Start Date 2015/11/11 12:51:30 Gauge Stop Date 2015/12/12 10:33:00Date Gauge On Bottom 2015/12/12 08:29:00 Date Gauge Off Bottom 2015/12/12 09:29:00
Test Data
Top(TVD KB) 1727.89 m Bottom(TVD KB) 1715.89 mPool Datum Depth (SS) m Well Datum Depth 1721.89 mTubing Pressure: Initial 9400.00 kPa(a) Tubing Pressure: Final 9400.00 kPa(a)Casing Pressure: Initial 9400.00 kPa(a) Casing Pressure: Final 9400.00 kPa(a)Start Test Date 2015/12/12 08:29:00 Date Well Shut-In 2015/11/15 08:00:00
Depth Log \n Depth Time Duration Pressure Gradient Temp. Gradientm m hh:mm:ss min kPa(a) kPa/m °C °C/m
1622.22 1631.60 08:29:00 44288.00 17089.71 57.52
1622.22 1631.60 08:39:00 10.00 17090.17 57.52
1622.22 1631.60 08:49:00 10.00 17090.90 57.52
1622.22 1631.60 08:59:00 10.00 17090.97 57.52
1622.22 1631.60 09:09:00 10.00 17091.88 57.52
1622.22 1631.60 09:19:00 10.00 17087.18 57.52
1622.22 1631.60 09:29:00 10.00 17091.86 57.49
1598.32 1604.60 09:34:00 5.00 16846.5910.260
57.240.011
1504.30 1504.60 09:41:00 7.00 15814.2910.980
56.070.012
1204.56 1204.60 09:48:00 7.00 12621.7010.651
51.950.014
904.57 904.60 09:56:00 8.00 10600.816.737
42.460.032
604.57 604.60 10:03:00 7.00 10112.381.628
33.840.029
304.57 304.60 10:10:00 7.00 9761.191.171
23.190.036
4.60 4.60 10:18:59 8.99 9410.691.168
4.310.063
Results
Gas 1.253 kPa/mWater 10.685 kPa/m
Gas - Water Interface 1016.87 m 10656.03 kPa(a)
Well Datum Depth 1721.89 m 18156.78 kPa(a)
ValidataTM
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15
Bot Rec.
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/12/12Final Test Date: 2015/12/12
ARCRES HZ N RED A02-04Formation: Montney
Bot Rec.
Gauge Serial NumberGauge ManufacturerRun Depth (Log KB)Gauge Start Date
Date Gauge On Bottom
1866
Rockdata
1632.10 m
2015/11/11 12:51:30
2015/12/12 08:29:00
Gauge TypeMaximum Recorder RangeDate of Last Calibration
Gauge Stop Date
Date Gauge Off Bottom
Strain
41470.00 kPa(a)2015/09/23
2015/12/12 10:33:00
2015/12/12 09:29:00
Test Data
Top(TVD KB)Pool Datum Depth (SS)Tubing Pressure: Initial
Casing Pressure: Initial
Start Test Date
1727.89 m Bottom(TVD KB)m Well Datum Depth
9400.00 kPa(a) Tubing Pressure: Final
9400.00 kPa(a) Casing Pressure: Final
2015/12/12 08:29:00 Date Well Shut-In
1715.89 m
1721.89 m
9400.00 kPa(a)9400.00 kPa(a)
2015/11/15 08:00:00
Depth Log tn Depthm m
Timehh:mm:ss
Durationmin
PressurekPa(a)
GradientkPa/m
Temp. Gradient'C C/m
905. 07
605. 07
305. 07
5.10
905.10
605.10
305.10
5.10
1622.66 1632.10
1622.66 1632.10
1622.66 1632.10
1622.66 1632.10
1622.66 1632.10
1622.66 1632.10
1622.66 1632.10
1598.77 1605.10
1504.79 1505.10
1205.06 1205.10
08:29:00
08:39:00
08:49:00
08:59:00
09:09:00
09:19:00
09:29:00
09:34:00
09:41:00
09:48:00
09:56:00
10:03:00
10:10:00
10:18:59
0.00 17092.22
10.00 17092.41
10.00 17093.12
10.00 17093.90
10.00 17094.23
10.00 17091.09
10.00 17094.35
5.00 16849.14
7.00 15818.12
7.00 12624.80
8.00 10603.56
7.00 10115.36
7.00 9764.52
8.99 9414.52
10.262
10.971
10.654
6.738
1.627
1.169
1.167
57.54
57.54
57.54
57.54
57.54
57.54
57.51
57.25
56. 08
52.07
42.57
33.94
23.11
4. 32
0.011
0.012
0.013
0.032
0.029
0.036
0.063
Results
Gas
Water1.198 kPa/m Gas - Water Interface
10.718 kPa/mWell Datum Depth
1017.19 m 10641.97 kPa(a)
1721.89 m 18157.90 kPa(a)
heal™Vakdata™
0 rPDQ INarkrrk02-04 GG PKT 15-Dee-15
Bot Rec.ARC RESOURCES LTD. ARCRES HZ N RED A02-04100/01-34-085-22W6/02 Formation: MontneyStart Test Date: 2015/12/12Final Test Date: 2015/12/12
ValidataTM
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15
Bot Rec.
Gauge Serial Number 1866 Gauge Type StrainGauge Manufacturer Rockdata Maximum Recorder Range 41470.00 kPa(a)Run Depth (Log KB) 1632.10 m Date of Last Calibration 2015/09/23Gauge Start Date 2015/11/11 12:51:30 Gauge Stop Date 2015/12/12 10:33:00Date Gauge On Bottom 2015/12/12 08:29:00 Date Gauge Off Bottom 2015/12/12 09:29:00
Test Data
Top(TVD KB) 1727.89 m Bottom(TVD KB) 1715.89 mPool Datum Depth (SS) m Well Datum Depth 1721.89 mTubing Pressure: Initial 9400.00 kPa(a) Tubing Pressure: Final 9400.00 kPa(a)Casing Pressure: Initial 9400.00 kPa(a) Casing Pressure: Final 9400.00 kPa(a)Start Test Date 2015/12/12 08:29:00 Date Well Shut-In 2015/11/15 08:00:00
Depth Log \n Depth Time Duration Pressure Gradient Temp. Gradientm m hh:mm:ss min kPa(a) kPa/m °C °C/m
1622.66 1632.10 08:29:00 0.00 17092.22 57.54
1622.66 1632.10 08:39:00 10.00 17092.41 57.54
1622.66 1632.10 08:49:00 10.00 17093.12 57.54
1622.66 1632.10 08:59:00 10.00 17093.90 57.54
1622.66 1632.10 09:09:00 10.00 17094.23 57.54
1622.66 1632.10 09:19:00 10.00 17091.09 57.54
1622.66 1632.10 09:29:00 10.00 17094.35 57.51
1598.77 1605.10 09:34:00 5.00 16849.1410.262
57.250.011
1504.79 1505.10 09:41:00 7.00 15818.1210.971
56.080.012
1205.06 1205.10 09:48:00 7.00 12624.8010.654
52.070.013
905.07 905.10 09:56:00 8.00 10603.566.738
42.570.032
605.07 605.10 10:03:00 7.00 10115.361.627
33.940.029
305.07 305.10 10:10:00 7.00 9764.521.169
23.110.036
5.10 5.10 10:18:59 8.99 9414.521.167
4.320.063
Results
Gas 1.198 kPa/mWater 10.718 kPa/m
Gas - Water Interface 1017.19 m 10641.97 kPa(a)
Well Datum Depth 1721.89 m 18157.90 kPa(a)
ValidataTM
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15
ARC RESOURCES LTD.t 00/01-34-085-22W6/02Start Test Date: 2015/12/12Final Test Date: 2015/12/12 Bot Rec. Pressure Gradient
ARCRES HZ N RED A02-04Formation: Montney
200
Gas Grad = 1.198 kPa/m
400
600
800
o.~1
/D
1000
LLP = 10641.97 kPa(a)LL = 1017.19 m
1200
Wats r Grad = 10.718 kPa/m
1400
1600
1800
Datum = 1721.89 m
PMpp = 18157.90 kPa(a)PMpp is extrapolated
9000 10000 11000 12000 13000 14000 15000 16000Pressure, kPa(a)
17000 18000 19000
0 1PDQ TrealA0604 SG PKT 15-Dee-15 Ver
Bot Rec. Pressure Gradient
Pressure , kPa(a)
Dep
th ,
m
9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000
0
200
400
600
800
1000
1200
1400
1600
1800
Datum = 1721.89 mPMPP = 18157.90 kPa(a)PMPP is extrapolated
Gas Grad = 1.198 kPa/m
Water Grad = 10.718 kPa/m
LLP = 10641.97 kPa(a)LL = 1017.19 m
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/12/12Final Test Date: 2015/12/12
ARCRES HZ N RED A02-04Formation: Montney
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15 Ver
ARC RESOURCES LTD.
1 00/01-34-085-22W6/02
Start Test Date: 2015/12/12
Final Test Date: 2015/12/12
18000
STATIC GRADIENT
ARCRES HZ N RED A02-04
Formation: Montney
100
16200
14400
12600
mm 10800
m m
0 IL
e'
me
re re9000
0 IL
n n
me
IDIn 7200
80~m
menn
me
me
mm
EE
me
40 nPk
5400
3600
1800
8:25 8:35 8:45 8:55 9:05 9:15 9:25 9:35 9:45 9:55 10:05 10:15 10:25
2015/12/12
TIME
0 IPDQ Werkr402 04 GG PKT 15.Dec.15 Ver
STATIC GRADIENT
TIME
Top
Rec
. Pre
ssur
e , k
Pa(a
)Bo
t Rec
. Pre
ssur
e , k
Pa(a
) Top Rec. Tem
perature , °CBot R
ec. Temperature , °C
8:252015/12/12
8:35 8:45 8:55 9:05 9:15 9:25 9:35 9:45 9:55 10:05 10:15 10:250
1800
3600
5400
7200
9000
10800
12600
14400
16200
18000
0
10
20
30
40
50
60
70
80
90
100
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/12/12Final Test Date: 2015/12/12
ARCRES HZ N RED A02-04Formation: Montney
C:\PDQ Work\A02-04 SG.FKT 15-Dec-15 Ver
ARC RESOURCES LTD.
1 00/01-34-085-22W6/02
Start Test Date: 2015/12/12
Final Test Date: 2015/12/12
17110
PRESSURE ON BOTTOM
ARCRES HZ N RED A02-04
Formation: Montney
17100
17090
17080
mm 17070
m m
D IL
n'
me
rn m17060
onme
Dttn17050
81~m
menn
me
809 9
me
mm
EE
me
59nn
17040
17030
17020
17010
8:25 8:30 8:35 8:40 8:45 8:50 8:55 9:00 9:05 9:10 9:15 9:20 9:25 9:30 9:35
2015/12/12
TIME
C IPDII Workt93 on not tkt 15 Dec 15 Ver
PRESSURE ON BOTTOM
TIME
Top
Rec
. Pre
ssur
e , k
Pa(a
)Bo
t Rec
. Pre
ssur
e , k
Pa(a
) Top Rec. Tem
perature , °CBot R
ec. Temperature , °C
8:252015/12/12
8:30 8:35 8:40 8:45 8:50 8:55 9:00 9:05 9:10 9:15 9:20 9:25 9:30 9:3517010
17020
17030
17040
17050
17060
17070
17080
17090
17100
17110
55
56
57
58
59
60
61
62
63
64
65
ARC RESOURCES LTD.100/01-34-085-22W6/02Start Test Date: 2015/12/12Final Test Date: 2015/12/12
ARCRES HZ N RED A02-04Formation: Montney
C:\PDQ Work\93 on bot.fkt 15-Dec-15 Ver
WATER ANALYSIS
019- 4CONTAINER IDENTITY
1 00/01-34-085-22W6/02LOCATION(UWI)
RedFIELD OR AREA
METER ID
ARC Resources Ltd.OPERATOR
ARCRes Hz N Red A2-4-86-22WELL NAME
Montney MA2/MBPOOL OR ZONE
29042WELL LICENSE NUMBER
521 34-201 5-3673LABORATORY FILE NUMBER
FAGE
KB ELEV (m) GR ELEV (m)
Production TestingSAMPLER
TESTTYPE AND NO
Water Leg SeparatorPOINT OF SAMPLE
TEST RECOVERY
SAMPLE POINT ID
PUMPING FLOWING GAS LIFT SWAB
I/I ATE R rrn/d OIL m'/d GAS rrn/d
TEST INTERLALor PERFS (meters)
SEFARATOR RESERVOIR OTHER
Pressures, kPa (gauge)05:00 Hrs
2015 11 15 2015 11 19 2015 11 25 SR/YW
LSEFARATOR OTHER
Temperatures, C
DATE SAMPLED (Y/M/D) CATE RECEIVED (Y/M/D) DATE ANALYZED (Y/M/D) ANALYST AMT AND TYPE CUSHION MUD RESISTIVITY
CATIONS ANIONS Total Dissolved Solids
(mg/L)
Not RequestedBy Evaporation (g 110 'C
Not RequestedBy Evaporabon (g I 00 'C
195238Calculated
1.1344 @ 15.5 c 1.3656 @ 24 cSpeafic Gravity Refractive Index ( n 0 )
6.3 @ 25.0 cpH
0.050 @ 25 'cResisbvity (Ohm-Meters)
Na
LOGARITHMICPATTERNS OF DISSOLVED IONSmeq/L
CI
Ca HCO3
Sos
Fe10,000 1,000 100 10
003I 01 I 10 100 1,000 10,000
REMARKs: N.D.—Not Detected.
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ARC Resources Ltd.
Reservoir Fluid Study
Field: Red Creek
Formation: Montney
Well: A02-4-86-22W6
CL-79574
June 2016
The items, advice, recommendation or opinions delivered hereunder are delivered for informational purposes only and client acknowledges it
is accepting all "as is". Client further agrees to not disclose except as expressly permitted by Weatherford. Weatherford makes no
representation or warranty, express or implied, of any kind or description in respect thereto, including, but not limited to the warranties of
merchantability and/or fitness for a particular purpose, and such is delivered hereunder with the explicit understanding and agreement that
any action client may take based thereon shall be at its own risk and responsibility. Client shall have no claim against Weatherford as a
consequence thereof. The foregoing disclaimer of warranties and representations shall apply to any entity receiving by, under or through
client and client shall indemnify Weatherford for any claims arising from any entity so receiving from client.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 1 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE OF CONTENTS
Page TABLE OF CONTENTS i
List of Tables ii List of Figures iii List of Appendices iv
SUMMARY 1
Study Objective 1 Technical Approach 1 Analyses Summary 1
RESULTS AND DISCUSSION 4 PROCEDURES AND EQUIPMENT 10
Fluids Preparation and Analysis Procedure 10 Sample Validation 10 Sample Recombination 11 Compositional Analysis 13 Differential Liberation 14 Multi-Stage Separator Test 15 Description of Experimental Equipment 16
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 2 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
List of Tables Page TABLE 1: COMPOSITIONAL ANALYSIS OF RESERVOIR FLUID 19 TABLE 2: FLUID COMPRESSIBILITY @ 143.6 oF (62.0 oC) 20 TABLE 3: CONSTANT COMPOSITION EXPANSION @ 143.6 oF (62.0 oC) 21 TABLE 4: DIFFERENTIAL LIBERATION OIL PROPERTIES
@ 143.6 oF (62.0 oC) 22 TABLE 5: DIFFERENTIAL LIBERATION GAS PROPERTIES
@ 143.6 oF (62.0 oC) 23 TABLE 6: DIFFERENTIAL LIBERATION FLUID VISCOSITY
@ 143.6 oF (62.0 oC) 24 TABLE 7: COMPOSITIONAL ANALYSIS OF LIBERATED GAS
@ 143.6 oF (62 oC) 25 TABLE 8: COMPOSITIONAL ANALYSIS OF RESIDUAL OIL @ 143.6 oF (62 oC) 26
TABLE 9: MULTI-STAGE SEPARATOR TEST OIL PROPERTIES 38 TABLE 10: MULTI-STAGE SEPARATOR TEST OIL PROPERTIES 39 TABLE 11: COMPOSITIONAL ANALYSIS OF TANK OIL 40 TABLE 12: ADJUSTED DIFFERENTIAL LIBERATION DATA TO
SEPARATOR CONDITION 41
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 3 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
List of Figures Page FIGURE 1: CONSTANT COMPOSITION EXPANSION @ 143.6 oF (62.0 oC) 27
FIGURE 2: DIFFERENTIAL LIBERATION OIL DENSITY @ 143.6 oF (62.0 oC) 28 FIGURE 3: DIFFERENTIAL LIBERATION OIL FORMATION VOLUME FACTOR
@ 143.6 oF (62.0 oC) 29
FIGURE 4: DIFFERENTIAL LIBERATION GAS-OIL RATIOS @ 143.6 oF (62.0oC) 30 FIGURE 5: DIFFERENTIAL LIBERATION OIL VISCOSITY @ 143.6 oF (62.0 oC) 31 FIGURE 6: DIFFERENTIAL LIBERATION GAS DEVIATION FACTOR @ 143.6 oF (62.0 oC) 32 FIGURE 7: DIFFERENTIAL LIBERATION GAS VOLUME FACTORS @ 143.6 oF (62.0 oC) 33 FIGURE 8: DIFFERENTIAL LIBERATION GAS GRAVITY @ 143.6 oF (62.0 oC) 34
FIGURE 9: DIFFERENTIAL LIBERATION GAS VISCOSITY @ 143.6 oF (62.0 oC) 35 FIGURE 10: LIBERATED GAS COMPOSITION PROFILE @ 143.6 oF (62.0 oC) 29 36 FIGURE 11: ADJUSTED DIFFERENTIAL LIBERATION OIL FORMATION VOLUME
FACTOR @ 143.6 oF (62.0 oC) 42 FIGURE 12: ADJUSTED DIFFERENTIAL LIBERATION GAS-OIL RATIOS
@ 143.6 oF (62.0 oC) 43
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 4 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
List of Appendices APPENDIX A: RECOMBINED FLUID COMPOSITION
APPENDIX B: DIFFERENTIAL LIBERATION - MATERIAL BALANCE APPENDIX C: DIFFERENTIAL LIBERATION - LIBERATED GAS COMPOSITIONS APPENDIX D: MULTI-STAGE SEPARATOR TEST- MATERIAL BALANCE APPENDIX E: MULTI-STAGE SEPARATOR TEST - LIBERATED GAS COMPOSITION APPENDIX F: SELECTED SEPARATOR SAMPLES VALIDATION APPENDIX G: WFT OIL SYSTEM CHARACTERIZATION PROTOCOL APPENDIX H: HIGH GOR RECOMBINED FLUID APPENDIX I: LOW GOR RECOMBINED FLUID APPENDIX J: EXCESS GAS CORRECTION
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 5 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
SUMMARY
Study Objective
ARC Resources Ltd. commissioned Weatherford Laboratories - Calgary to perform a
PVT study using multi-rate separator samples collected from well A02-4-86-22W6 of the Red
Creek field, Montney formation. The study aims to provide characterization of the fluid in situ
and to measure the current physical and compositional properties associated with the fluid.
Technical Approach
The reservoir fluid study was conducted on a representative reservoir fluid in situ
obtained following the WFT-Liquid Rich System Characterization Protocol. Constant
Composition Expansion, Differential Liberation and Two-stage separator tests were performed
on the fluid simulating the reservoir depletion and production processes.
Analyses Summary
The following analyses summary is provided to enhance understanding of the laboratory
data and to offer additional insight relative to Weatherford's experience with laboratory and field
processes. They represent our interpretation as to possible mechanisms and physical
phenomena that may be occurring within the laboratory models that have been studied. These
laboratory experiments are microscale representations of the field scenario; however
macroscale phenomena may override behaviour exhibited in the laboratory. A more thorough
development of the conclusions is presented in the Discussion section of the report.
Multirate sampling was conducted to assess the changes in fluid properties as the
flowing bottomhole pressure varies with flowrates. Five sampling rates were collected and
delivered to the laboratory. The details of the samples are summarized below.
Rate # Gas Rate, e3m3/day Production GOR, m3/m3 Meter Temperature, °C Static Pressure, kPa
0 15 249 44 2034
1 37 1171 25 331
2 33 1191 27 276
3 31 1083 25 1034
4 25 1154 22 1138
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 6 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
Upon review of the production gas-oil ratios, Rate 3 samples were selected to be the
most representative separator gas and liquid samples for physical recombination. Two physical
recombination were conducted, a high GOR (1083 m3/m3) corresponding to the separator GOR
at the time the Rate 3 samples were collected and a low GOR (249 m3/m3) corresponding the
separator GOR at the time the Rate 0 samples were collected.
The recombined fluid at high GOR exhibited an apparent dew point pressure of 43.92
MPa at a reservoir temperature of 62°C, which is found above the reservoir pressure (21.75
MPa). The recombined fluid at low GOR exhibited an apparent bubble point pressure of 25.44
MPa at 62°C, which is also above the reservoir pressure. Based on these results, the WFT-
Liquid Rich Characterization Protocol was applied to determine the type of reservoir fluid system
in situ.
The fluid system in situ was determined to be an oil system with excess gas in solution.
A correction was done to eliminate the presence of the excess gas in solution thereby obtaining
the representative sample for PVT study. Subsequently a constant composition expansion,
differential liberation and two-stage separator tests were conducted on the corrected fluid
sample.
The salient conclusions and recommendations of the study are:
1. On the basis of detailed compositional analysis, constant composition expansion,
differential liberation and separator-tests, sufficient data were provided to effectively
characterize the vapor-liquid phase behavior of A02-4-86-22W6 reservoir fluid from a
primary depletion perspective.
2. The Weatherford Oil System Characterization protocol determined that the reservoir fluid
is a bubble point system.
3. A constant composition expansion test measured a bubble point pressure = 21.75 MPa
at the reservoir temperature of 62°C.
4. The differential liberation test measured the following fluid properties at saturation
pressure: solution gas-oil ratio (Rs) = 226.66 m3/m3, formation volume factor (Bo) =
1.7228, reservoir oil density = 605.2 Kg/m3, and reservoir oil viscosity = 0.33 mPa.s.
5. The residual oil from differential liberation exhibited 44.45 API gravity and 1.46 mPa.s
viscosity.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 7 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
6. The two-stage separator test measured the following fluid properties at saturation
pressure: solution gas-oil ratio (Rs) = 184.65 m3/m3 and formation volume factor (Bo) =
1.5874. The stock tank oil from the two-stage separator test exhibited a 46.4 API gravity.
7. From the above tests the differential liberation data was adjusted to the separator
conditions
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 8 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
RESULTS & DISCUSSION
ARC Resources Ltd. commissioned Weatherford Laboratories - Calgary to perform a
PVT study using multi-rate separator samples collected from well A02-4-86-22W6 of the Red
Creek field, Montney formation. Multi-rate sampling was performed and separator gas and liquid
samples from five sampling rates were collected and delivered to the laboratory.
Sample validations were conducted and Rate 3 samples were selected to be the most
representative separator gas and liquid samples for physical recombination. Two physical
recombinations were conducted, a high GOR (1083 m3/m3) corresponding to the separator GOR
at the time the Rate 3 samples were collected and a low GOR (249 m3/m3) corresponding the
separator GOR at the time the Rate 0 samples were collected.
The recombined fluid at high GOR exhibited an apparent dew point pressure of 43.92
MPa at a reservoir temperature of 62°C (refer to Appendix H), which is found above the
reservoir pressure (21.75 MPa). The recombined fluid at low GOR exhibited an apparent bubble
point pressure of 25.44 MPa at 62°C (refer to Appendix I), which is also above the reservoir
pressure. Based on these results, the WFT-Liquid Rich Characterization Protocol (refer to
Appendix G) was applied to determine the type of reservoir fluid system in situ.
For the high GOR recombined fluid, the GOR* was determined to assess the fluid in situ.
The separator gas and liquid were recombined using the GOR* value (224.44 m3/m3). The
resulting fluid showed a bubble point pressure of 23.26 MPa which is closely similar to the
results of the low GOR recombination. According to the WFT-Liquid Rich Characterization
Protocol, the fluid system in situ is oil with excess gas in solution.
An algorithm was used to calculate the correct GOR and solution gas composition for
the low GOR recombined fluid (refer to Appendix J). The algorithm is designed to eliminate the
excess gas in solution thereby obtaining a corrected fluid with saturation pressure equal to the
reservoir pressure. The resulting reservoir fluid composition obtained from the algorithm was
compared with the composition of the low GOR recombined sample depleted at the reservoir
pressure. The measured and fluid composition and GOR was found to closely match the
calculated fluid composition and GOR value (Appendix J). Based on this comparison, it was
decided to proceed with the PVT study on the physically corrected reservoir oil.
Subsequently a constant composition expansion, differential liberation and two-stage
separator tests were conducted on this sample. The pertinent data are summarized below.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 9 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
SUMMARY OF INDIVIDUAL TEST RESULTS
INITIAL RESERVOIR CONDITIONS
Reservoir Pressure 3154 psia 21.75 MPa
Reservoir Temperature: 143.6 F 62.0 C
CONSTANT COMPOSITION EXPANSION @ 143.6 F (62.0 C)
Saturation Pressure 3154 psia 21.74 MPa
Compressibility @ Reservoir Pressure 1.97033E-05 psia-1
2.857721E-03 MPa-1
Compressibility @ Saturation Pressure 2.05309E-05 psia-1
2.977768E-03 MPa-1
DIFFERENTIAL LIBERATION @ 143.6 F (62.0 C)
At Saturation Pressure
Oil Formation Volume Factor 1.7228 res.bbl/STB 1.7228 res.m3/m
3
Solution Gas-Oil Ratio 1272.66 scf/STB 226.66 m3/m
3
Oil Density 0.6052 g/cm3
605.2 kg/m3
Oil Viscosity 0.331 cp 0.3 mPa.s
At Ambient Pressure
Residual Oil Density 0.7712 g/cm3
771.2 kg/m3
Residual Oil Viscosity 1.460 cp 1.5 mPa.s
At Tank Conditions
Residual Oil Density 0.8042 g/cm3
804.2 kg/m3
API Gravity 44.45 44.45
MULTI-STAGE SEPARATOR TEST
Saturation Pressure 3154 psia 21.74 MPa
At Saturation Pressure
Oil Formation Volume Factor 1.5874 res.bbl/STB 1.5874 res.m3/m
3
Solution Gas-Oil Ratio 1036.77 scf/STB 184.65 m3/m
3
Oil Density 0.6052 g/cm3
605.2 kg/m3
At Ambient Pressure
Residual Oil Density 0.7955 g/cm3
795.5 kg/m3
At Tank Conditions
Residual Oil Density 0.7955 g/cm3
795.5 kg/m3
API Gravity 46.4 46.4
SINGLE-STAGE SEPARATOR TEST
At Saturation Pressure
Oil Formation Volume Factor 1.6721 res.bbl/STB 1.6721 res.m3/m
3
Solution Gas-Oil Ratio 1158.30 scf/STB 206.29 m3/m
3
At Tank Conditions
Residual Oil Density 0.8028 g/cm3
802.8 kg/m3
API Gravity 44.8 44.8
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 10 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
Since the differential liberation test data is relative to the residual oil volume, the two-
stage separator test provided a basis for converting the differential data from residual oil to
stock-tank oil basis. The method Weatherford used for this conversion is discussed in detail in
procedures and equipment section. The following table shows the differential liberation data
adjusted to the separator conditions.
The relevant data required for specific reservoir engineering application are summarized
as input to the black oil PVT formulation in the table below.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 11 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
DETAILED SUMMARY FOR BLACK OIL TABLE FORMULATION
Recombination GOR 206.29 m3/m
3Gas Sp. Gravity 0.8081 (Air = 1)
Saturation Pressure 21.74 Mpa Stock Tank Oil Gravity 44.75
Reservoir Temperature 62.0 °C
Pressure Solution GOR Oil FVF Oil Density Oil Viscosity Compressibility GasDensity Gas Deviation Gas FVF Gas ViscosityP Rs* Bo* ρo µo** Co ρg Z Bg µg
(MPa) (m3/m
3) (m
3/m
3) (Kg/m
3) (mPa-s) (Mpa
-1) (Kg/m
3) Factor (m
3/m
3) (mPa-s)
34.56 184.65 1.5453 624.2 0.3762 -32.63 184.65 1.5506 621.8 0.3694 2.0395E-0329.80 184.65 1.5588 618.0 0.3594 2.1368E-0327.07 184.65 1.5675 614.0 0.3497 2.3458E-0324.60 184.65 1.5762 610.2 0.3410 2.5520E-0323.44 184.65 1.5806 608.2 0.3369 2.7516E-0322.27 184.65 1.5852 606.2 0.3327 2.8577E-0321.74 184.65 1.5874 605.2 0.3307 2.9778E-0319.39 161.01 1.5197 618.1 0.3570 181.8 0.8007 0.0049 0.020917.33 143.42 1.4688 631.1 0.3818 162.3 0.7954 0.0054 0.019415.26 126.28 1.4254 644.6 0.4118 141.0 0.7980 0.0062 0.017913.19 111.62 1.3861 656.7 0.4375 119.6 0.8068 0.0072 0.016611.12 97.09 1.3520 666.8 0.4698 98.5 0.8223 0.0087 0.01559.05 83.42 1.3165 678.4 0.5075 78.3 0.8434 0.0110 0.01456.98 70.03 1.2874 686.7 0.5560 59.1 0.8692 0.0146 0.01374.92 57.11 1.2541 697.9 0.6280 41.5 0.8976 0.0215 0.01302.16 38.18 1.2015 714.7 0.8420 19.5 0.9412 0.0513 0.01190.09 0.00 1.0378 771.2 1.4600 1.3 0.9933 1.3035 0.0097
* Adjusted to separator conditions** Viscosities above Psat were extrapolated from 3-point viscosity measurement (see Table 7)
Oil Properties Gas Properties
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 12 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
The compositional analysis of reservoir fluid is given in Table 1.
The PVT cell was charged with a portion of the fluid sample and a constant composition
expansion experiment (CCE) was performed on the fluid. Table 2 provides the CCE results of
the average compressibility of the reservoir fluid at pressures above the saturation pressure.
Table 3 contains the complete CCE results with the exception of the data already presented in
Table 2. Figure 1 shows the relative total volume (V/Vsat) data and Y-function.
Table 4 contains various property measurements made on the differentially liberated oil
below the bubblepoint including live oil density, oil formation volume factor, and gas-oil ratios.
These are shown in Figures 2 through 4, respectively.
Table 5 contains a summary of the properties of the differentially liberated gas including
gas gravities, deviation factors, gas formation volume factors and gas expansion factors. The
gas deviation factor (Z), gas formation volume factor and gas expansion factor, and gas gravity
are shown in Figures 6 through 8, respectively.
Table 6 provides the results of the reservoir fluid viscosity measurements. This data is
represented by Figures 5 and 9. Gas phase viscosity was calculated using the compositional
data and the Lee, Gonzalez, Eakin correlation.
Table 7 summarizes the effluent gas compositions from each pressure stage during the
differential liberation experiments. Figure 10 shows this data plotted on semi-log co-ordinates.
Table 8 presents the compositional analysis of the residual oil at completion of the experiment.
Appendix B contains the material balance check performed for this experiment. It is
displayed as formation volume factors so that the balance can be checked on a point by point
basis. Appendix C contains the detailed compositional analyses of the liberated gases from the
differential liberation test.
Table 9 contains various oil property measurements performed on the two-stage
separator test including live oil density, oil formation volume factor and gas-oil ratios.
Table 10 contains a summary of the gas properties including gas gravities, deviation
factors, gas formation volume factors and gas expansion factors from the two-stage separator
test.
Table 11 presents the compositional analysis of the residual oil at completion of the two-
stage experiment.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 13 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
Table 12 summarizes the differential liberation data adjusted to flash liberation separator
conditions. These data is graphically presented in Figures 11 and 12.
Appendix D contains the material balance check performed for the multi-stage separator
experiment. Appendix E contains the detailed compositional analyses of the liberated gases
from the multi-stage separator test.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 14 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
PROCEDURE AND EQUIPMENT
Fluids Preparation and Analysis Procedure
The following is an example of typical procedures and equipment used for fluids
preparation, analysis and testing. Additional or unique procedures are outlined in the “Results
and Discussion” section.
Sample Validation
PVT properties such as formation volume factor and gas-oil ratio are obtained taking a
small portion of each sample and mounting the sample cylinder into the separator system as
shown in the flow chart below.
The sample is then flashed slowly from test conditions to stock tank conditions. The
amount of gas released and residual oil are measured and used to calculate the formation
volume factor and gas-oil ratio.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 15 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
Subsequent to gas-oil ratio measurement, compositional analyses are conducted on the
flashed phases.
A known volume of flashed fluid is injected into the head of the column. The technique
uses heated sample ports through which the sample can be injected and vaporized
simultaneously. A carrier gas, which is chemically inert, transports the sample through the
column. It is within the column that the separation of the components takes place. After the
components of the mixture move through the GC column, they reach the detector. Ideally,
components of the mixture will reach the detector at varying time due to differences in
partitioning between mobile and stationary phases. The detector sends a signal to the chart
recorder which results in a peak. The area of the peak is then proportional to the composition of
the component generating the signal.
Separator oil properties were measured on duplicate samples to verify the quality of the
samples. Two samples had a single stage flash performed at 60oC. Both samples were then
subjected to compositional analysis to compare the samples and also to possibly detect sample
contamination by extraneous hydrocarbon fluids.
Duplicate separator gas samples were analyzed for composition at 60oC. Any
discrepancy between the two analyses may indicate that some components in the samples
have condensed to liquid and that the samples must be thoroughly heated before use to
vaporize these components.
Sample Recombination
To recombine live oil from separator oil and separator gas, the gas was first condensed
into a high-pressure cylinder for high-pressure applications. By immersing the target high-
pressure cylinder in liquid nitrogen, the low pressure gas could be readily transferred. The
amount of pressure drop (∆P) is calculated in terms of the amount of live oil (Voil) needed, the
GOR of the oil, the live oil formation volume factor (Bo), and the volume of the gas tank (Vtank).
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 16 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
∆ ⁄
Once the specified pressure drop had been achieved on the source gas in the low
pressure tank, the high pressure cylinder was then heated to system temperature. To increase
the pressure to operating pressure, mercury was injected into the bottom of the cylinder which
acted as a confining fluid. In this manner, any pressure can be obtained (up to 70 MPa) and a
constant pressure injection can be maintained.
The oil supplied was from a separator sample. The required value of the separator
sample (Vsep) was calculated and added to the target cylinder. The live separator oil was
pressured above the sampling pressure to ensure a single-phase fluid when transferring.
Once the gas and oil had been added together, the cylinder was isolated and thoroughly
agitated at reservoir temperature to ensure a homogeneous fluid system.
The recombined sample was then pressurized to above the reservoir pressure and
mixed into single phase. A single-stage flash gas-oil ratio (GOR) was measured by flashing a
sample of the fluid from some pressure greater than the saturation pressure at reservoir
temperature into an atmospheric separator and measuring the corresponding volumes of gas
and liquid. This flash also provides parameters such as formation volume factor (Bo) and live
fluid density. Although these values are measured relative to the single phase fluid pressure
from which they were flashed, the CCE provides data allowing these values to be corrected to
the saturation pressure. These fluids (gas and liquid) were then subjected to compositional
analysis using GC analysis, as mentioned in the "Equipment" section, from which a computer
generated live oil composition was determined. Compositions of these gases and oils are
determined in the following manner.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 17 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
Compositional Analysis
Mole fractions of gases are determined by injecting the gas of interest to an evacuated
sample system while maintaining a slight negative pressure (7 cm Hg vacuum). The carrier gas
(helium) transports the gas into the column, the thermal conductivity detector (TCD), flame
ionizing detector (FID), and integrator indicate an area associated with each component. These
areas are then translated into component mole fractions by the following formula:
∑
The subscript i in the expression represents the ith component in the gas and the
calibration constant is an empirical amount per area ratio which relates the area detected to the
mole fraction that should be present in the analytical standard. If the resulting mole fractions
deviate from the standard, new calibration constants are calculated knowing the mole fraction
and the area detected. Thus recalibration is easy to perform and can be checked daily by
running a standard sample. Recalibration is usually only necessary biweekly at most and often
only monthly. When recalibrated the differences are only very slight and often affect only the
non-hydrocarbons.
Mole fractions in the flashed liquid sample are determined by injecting the liquid sample
into the megabore column of the HP5890 GC. Calibration is made on a component basis.
However, there are many more components than with the gas, a total of 47 including the
unsaturated cyclics and aromatics enumerated in the "Description of the Equipment".
Calibration of this column is carried out using a quantitative standard containing C6 through
C40. The main deficiency of this analytical method is related to the fraction that does not elute
from the column.
Some components, especially the heavier end of an oil sample, leave some residual
amount behind in the column. This non-eluted portion, if uncorrected, will indicate a smaller
fraction of these components than is actually present. In order to account for any hydrocarbon
that is not eluted at the final temperature, the oil analyses are corrected by applying the WFT
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 18 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
proprietary method of plus fraction correction which quantitatively determine the higher
hydrocarbon components of the sample. This method measures component elution up to C60
and also calculates the non-eluted portion of the sample, determines the maximum carbon
number component in the sample and the molecular weight of these fractions (Patent
Publication # EP2863216 A1). Thus the fraction of the oil not eluted can be quantified and a
correction applied to the compositional analysis. This appears in the form of a C30+ correction.
Not only does this factor correct for the fraction of C30+ in the oil sample but also accounts for
the fraction not eluted amongst any of the components lighter than C30+.
Previous studies done by Hycal Energy Research Laboratories Ltd. (currently
Weatherford) found that using a common C30+ mass fraction and molecular weight correction is
adequate for the majority of compositions of the same oil. For those few compositions that have
undergone considerable mass transfer, this correction may be insufficient, but the error is
attenuated since the corresponding gas analysis is unaffected and the GOR's for these samples
are usually high.
Differential Liberation
The Differential Liberation experiment consists of two major portions: the constant
composition expansion (CCE) and the actual differential liberation test (DL).
In the CCE experiment, a sample of the reservoir fluid is transferred to the PVT cell at a
pressure of approximately 7000 kPa greater than the bubble point pressure. Starting at this
pressure, the pressure in the cell is incrementally reduced by expanding the volume of the
sample chamber, allowing time at each stage for equilibration. Gauge pressure, pump volume
and gas/liquid/Hg interfaces are recorded at each stage.
The CCE test provides several pieces of information, the most important of which is the
saturation pressure (bubble point) of the reservoir fluid. Secondly, it provides P-V relation data
for the reservoir fluid such as relative volume and compressibility above and below the bubble
point. It also allows the calculation of the Y-Function which, as indicated previously, is used as a
data quality check. Since the two phase relative volume at pressures below the bubble point is
generally a linear function of pressure, the Y-Function should also be linear. Subsequent to the
CCE, the reservoir fluid is again pressured into single phase. Then the fluid is subjected to the
following DL procedure:
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 19 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
1. The cell pressure is lowered to approximately 140 kPa greater than the bubble point.
The volume of fluid in the PVT cell at this pressure is recorded.
2. The pressure in the PVT cell is lowered to the first designated pressure stage. Liquid
and vapour phase volumes are measured using a cathetometer.
3. Keeping a constant pressure, liberated gas from the oil is displaced from the visual cell.
The composition and volume of the displaced fluid are recorded.
4. Steps 2 and 3 are repeated for each designated pressure stage.
This procedure simulates the depletion of a typical oil reservoir during production.
Multi-Stage Separator Test
Initially, the reservoir sample is brought to saturation conditions and the volume is
measured. The sample is then brought to the pressure and temperature of the first-stage
separator. All of the gas is removed and the oil volume at the separator stage is noted, together
with the volume of moles and specific gravity of the removed gas. The compositions of the gas
samples are also measured. This procedure is repeated on more time, bringing the sample to
the pressure and temperature of the second-stage separator.
The oil remaining after gas removal is brought to stock tank conditions and the final oil
volume and specific gravity are measured at standard conditions.
On the basis of the formation volume factor and gas-oil ratio given by this test,
differential data is corrected to stock tank basis. The adjusted parameters are evaluated from
the following equations:
∙
∙
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 20 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
: Solution gas-oil ratio at P < Pb obtained by the differential liberation test
: Solution –gas-oil ratio at Pb obtained from the separator test
: Solution gas-oil ratio at Pb obtained by the differential liberation test
: Oil formation volume factor at Pb from the separator test
: Oil formation volume factor at Pb obtained by the differential liberation test
: Oil formation volume factor at P<Pb obtained by the differential liberation test
: Oil formation volume factor at Patm obtained by the differential liberation test
The above method is taken from SPE 68234, June 2003 SPE Reservoir Evaluation and
Engineering.
Description of Experimental Equipment
Fluid Recombination
A cryogenic process is used to condense the sampled separator gas into a high
pressure cylinder for the recombination of oil. High-pressure cylinders are used in the
recombination procedure by condensing from the low pressure separator gas source to the high
pressure gas source.
Compositional Analysis
Analysis of the fluids and gases in this experiment is carried out on gas chromotographs
(GC). Various techniques can be used to perform compositional analysis on hydrocarbon gases
and liquids.
Analysis of light hydrocarbon fluids is conducted using an HP5890 liquid injection gas
chromatograph equipped with flame ionization detector (FID) operated to a maximum
temperature of 300°C. Separation of individual components is performed with a 30 meter, 530
micrometer diameter “Megabore” capillary column. It is a fused silica column using methyl
silicone as the stationary phase. The stationary phase is 2.6 micrometers thick and is rated for
operation in the temperature range of -60o to 300°C. Over this temperature range the
components eluted are from C1 to C36 along with cyclopentane, methylcyclopentane, benzene,
cyclohexane, methylcyclohexane, toluene, ortho-xylene, 1,2,4,-trimethylbenzene, meta- and
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 21 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
para-xylene. That is, each of these components is retarded in its flow through the column,
based on its physical properties, by the stationary phase. Thus the sample becomes segregated
as it passes through the column. With prior knowledge of the amount of “retention” of a given
compound, its relative magnitude can be determined by the length of time it remains in the
column before it finally passing through. This is known as its retention time. For some
compounds this can be lengthy so typically the temperature is gradually increased during the
analysis to shorten retention times by a predefined amount.
The gas analyses are carried out on an HP5890 gas injection GC equipped with two
separation columns. The first column is a combination of a 100 mesh packed column and a 100
mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to
achieve separation of the very light gaseous components (N2, O2, C1), while the packed column
serves to separate ethane, propane, butanes, pentanes, and hexanes plus along with CO2 and
H2S. The second column is a capillary column as described previously in liquid analysis. This
column is capable of achieving separation of components up to C12+, along with the associated
napthenese and aromatics, though these values are typically lumped into the C6+ fraction during
analysis. Components up to C4 are analyzed using a thermal conductivity detector (TCD) while
the C5+ components are analyzed using an FID. The instrument has programmable air actuated
multiport valves that let the flow of the sample mixture to be varied between the two columns
allowing for the correct separation and analysis of the injected sample gas.
DL & Sep Test Apparatus
A PVT cell is used to measure the bubble point by the breakpoint of the PV curve
resulting from the measure depletion of pressure from some pressure greater than the bubble
point (single phase) to well below (the two-phase region). It consists of a PVT cell, source
cylinders, capillary tube, collection cylinder, oven, buffers and pumps. The PVT cell is the heart
of the apparatus where the fluids of interest are injected. The PVT cell has a rating of 70 MPa
at about 200oC and has an internal volume of approximately 300 cm3. Connected to the PVT
cell are high-pressure source cylinders containing fluids of interest. Displacing mercury into the
bottom of the source cylinder with the pump transfers a corresponding volume into the visual
cell. Thus, fluids can be transferred in prescribed volumes to within 0.02 cm3. The source
cylinder is typically a 660 cm3 316 SS high-pressure cylinder rated to 70 MPa.
The oven in which this equipment is housed is capable of operation to 200°C and is
controlled to ±0.5°C. The oven has been constructed so that it is capable of 180° rotation to
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 22 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
expedite equilibration. With mercury used as the confining fluid in the visual cell, considerable
mixing and agitation are provided when the oven is inverted.
The final equipment associated with the DL apparatus are the Ruska positive
displacement pumps. They are capable of injecting at pressures up to 70 MPa. Digital
Sensotec gauges were used in conjunction with the positive displacement pumps to set
pressure levels; these gauges are accurate to ± 40 kPa.
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 23 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF RESERVOIR FLUID
Boiling Point Mole Mass (C) Fraction Fraction
-195.8 Nitrogen N2 0.0037 0.0014 Total Sample-78.5 Carbon Dioxide CO2 0.0028 0.0017-60.3 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 74.39
-161.7 Methane C1 0.4628 0.0998-88.9 Ethane C2 0.0811 0.0328-42.2 Propane C3 0.0605 0.0359 C6+ Fraction-11.7 i-Butane i-C4 0.0106 0.0083
-0.6 n-Butane n-C4 0.0316 0.0247 Molecular Weight 181.2427.8 i-Pentane i-C5 0.0129 0.0126 Mole Fraction 0.313136.1 n-Pentane n-C5 0.0208 0.0202 Density (g/cc) 0.8319
36.1 - 68.9 Hexanes C6 0.0336 0.038968.9 - 98.3 Heptanes C7 0.0289 0.0389
98.3 - 125.6 Octanes C8 0.0299 0.0460 C7+ Fraction125.6 - 150.6 Nonanes C9 0.0254 0.0438150.6 - 173.9 Decanes C10 0.0196 0.0375 Molecular Weight 193.49173.9 - 196.1 Undecanes C11 0.0179 0.0354 Mole Fraction 0.2776
196.1 - 215 Dodecanes C12 0.0142 0.0307 Density (g/cc) 0.8419215 - 235 Tridecanes C13 0.0147 0.0345
235 - 252.2 Tetradecanes C14 0.0116 0.0296252.2 - 270.6 Pentadecanes C15 0.0088 0.0245 C12+ Fraction270.6 - 287.8 Hexadecanes C16 0.0071 0.0211287.8 - 291.7 Heptadecanes C17 0.0063 0.0199 Molecular Weight 291.17291.7 - 317.2 Octadecanes C18 0.0063 0.0214 Mole Fraction 0.1216
317.2 - 330 Nonadecanes C19 0.0058 0.0204 Density (g/cc) 0.8863330 - 344.4 Eicosanes C20 0.0044 0.0164
344.4 - 357.2 Heneicosanes C21 0.0040 0.0157357.2 - 369.4 Docosanes C22 0.0036 0.0147
369.4 - 380 Tricosanes C23 0.0031 0.0133380 - 391.1 Tetracosanes C24 0.0028 0.0125
391.1 - 401.7 Pentacosanes C25 0.0027 0.0127401.7 - 412.2 Hexacosanes C26 0.0023 0.0110412.3 - 422.2 Heptacosanes C27 0.0021 0.0103422.3 - 431.7 Octacosanes C28 0.0019 0.0101431.7 - 441.1 Nonacosanes C29 0.0017 0.0092Above 441.1 Tricontanes Plus C30+ 0.0183 0.1481
48.9 Cyclopentane C5H10 0.0019 0.001872.2 Methylcyclopentane C6H12 0.0055 0.006381.1 Cyclohexane C6H12 0.0051 0.0058
101.1 Methylcyclohexane C7H14 0.0089 0.0118
80.0 Benzene C6H6 0.0015 0.0016110.6 Toluene C7H8 0.0031 0.0038
136.1 - 138.9 Ethylbenzene & p,m-Xylene C8H10 0.0034 0.0049144.4 o-Xylene C8H10 0.0024 0.0034168.9 1, 2, 4-Trimethylbenzene C9H12 0.0043 0.0069
Total 1.0000 1.0000
Calculated Properties
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 24 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
FLUID COMPRESSIBILITY @ 143.6 oF (62.0 oC)
Pressure Range Average
From To Compressibility(psia) (psia) (psi
-1)
5013 4733 1.4062E-05
4733 4322 1.4732E-05
4322 3927 1.6174E-05
3927 3568 1.7595E-05
3568 3400 1.8971E-05
3400 3230 1.9703E-05
3230 3154 Psat 2.0531E-05
Pressure Range Average
From To Compressibility
(MPa) (MPa) (MPa-1
)
34.56 32.63 2.0395E-03
32.63 29.80 2.1368E-03
29.80 27.07 2.3458E-03
27.07 24.60 2.5520E-03
24.60 23.44 2.7516E-03
23.44 22.27 2.8577E-03
22.27 21.74 Psat 2.9778E-03
Psat - Saturation Pressure
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 25 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 3 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
CONSTANT COMPOSITION EXPANSION @ 143.6 oF (62.0 oC)
Pressure RelativeVolume Y-Function Fluid Density
(psia) (MPa) [1] [2] (g/cc) 5013 34.56 0.969598 0.6242
4733 32.63 0.973431 0.6218
4322 29.80 0.979361 0.6180
3927 27.07 0.985658 0.6140
3568 24.60 0.991924 0.6102
3400 23.44 0.995095 0.6082
3230 22.27 0.998440 0.6062
3154 Psat 21.74 1.000000 0.60523101 21.38 1.004555 3.7522
3067 21.14 1.007628 3.7189
3009 20.74 1.013160 3.6620
2957 20.39 1.018451 3.6110
2858 19.70 1.029476 3.5139
2691 18.55 1.051362 3.3502
2547 17.56 1.074274 3.2090
2399 16.54 1.102729 3.0638
2274 15.68 1.131584 2.9413
2070 14.27 1.191058 2.7412
1775 12.24 1.316894 2.4519
1410 9.72 1.590772 2.0940
1182 8.15 1.892140 1.8704
1022 7.04 2.217705 1.7135
904 6.23 2.558105 1.5978
[1] Volume at indicated pressure per volume at saturation pressure
[2] Y Function = ((Psat-P)/P)/(Relative Volume - 1)
Psat - Saturation Pressure
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 26 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 4 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION OIL PROPERTIES @ 143.6 oF (62.0 oC)
Oil Oil Formation Total Formation Gas-Oil Ratio
Density Volume Factor Volume Factor Solution Liberated Solution Liberated(psia) (MPa) (g/cm
3) [1] [2] (scf/STB) (scf/STB) (m
3/m
3) (m
3/m
3)
5013 34.56 0.6242 1.6704 1.6704 1272.66 0.00 226.66 0.004733 32.63 0.6218 1.6770 1.6770 1272.66 0.00 226.66 0.004322 29.80 0.6180 1.6872 1.6872 1272.66 0.00 226.66 0.003927 27.07 0.6140 1.6981 1.6981 1272.66 0.00 226.66 0.003568 24.60 0.6102 1.7089 1.7089 1272.66 0.00 226.66 0.003400 23.44 0.6082 1.7144 1.7144 1272.66 0.00 226.66 0.003230 22.27 0.6062 1.7201 1.7201 1272.66 0.00 226.66 0.00
3154 Psat 21.74 0.6052 1.7228 1.7228 1272.66 0.00 226.66 0.002813 19.39 0.6181 1.6385 1.7788 1109.71 162.95 197.64 29.022513 17.33 0.6311 1.5751 1.8470 988.48 284.17 176.05 50.612213 15.26 0.6446 1.5209 1.9592 870.34 402.32 155.01 71.651913 13.19 0.6567 1.4720 2.1128 769.34 503.31 137.02 89.641613 11.12 0.6668 1.4294 2.3570 669.17 603.49 119.18 107.481313 9.05 0.6784 1.3852 2.7339 574.95 697.71 102.40 124.261013 6.98 0.6867 1.3489 3.3831 482.69 789.96 85.97 140.69713 4.92 0.6979 1.3075 4.6110 393.64 879.02 70.11 156.55313 2.16 0.7147 1.2418 10.1065 263.12 1009.53 46.86 179.8013 0.09 0.7712 1.0378 150.6330 0.00 1272.66 0.00 226.66
Density of Residual Oil = 0.8042 g/cm3 (804.2 kg/m3) @ 60 F (288.7K)
[1] Barrels (Cubic meters) of oil at indicated pressure and temperature per barrel (cubic meter) of residual oil @ 60 F (288.7 K).[2] Total barrels (cubic meters) of oil and liberated gas at the indicated pressure and temperature per barrel (cubic meter) of residual oil @ 60 F (288.7 K).Psat - Saturation Pressure - Tank conditions: 60 F (288.7 K) @ 13 psia (0.0896 MPa); Standard conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa).
PressureGas-Oil Ratio
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 27 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 5 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS PROPERTIES @ 143.6 oF (62.0 oC)
Gas Gravity Gas Gas Deviation Gas Formation Gas ExpansionIncremental Cumulative Density Factor Volume Factor Factor
(psia) (MPa) (Air = 1) (Air = 1) (g/cm3) (-) [1] [2]
5013 34.564733 32.634322 29.803927 27.073568 24.603400 23.443230 22.27
3154 Psat 21.742813 19.39 0.7222 0.7222 0.1818 0.8007 0.0049 205.9152513 17.33 0.7166 0.7198 0.1623 0.7954 0.0054 185.1792213 15.26 0.7093 0.7167 0.1410 0.7980 0.0062 162.5401913 13.19 0.7039 0.7141 0.1196 0.8068 0.0072 138.9571613 11.12 0.7004 0.7119 0.0985 0.8223 0.0087 114.9581313 9.05 0.7016 0.7105 0.0783 0.8434 0.0110 91.2391013 6.98 0.7076 0.7101 0.0591 0.8692 0.0146 68.296713 4.92 0.7296 0.7121 0.0415 0.8976 0.0215 46.547313 2.16 0.8174 0.7257 0.0195 0.9412 0.0513 19.47913 0.09 1.3446 0.8537 0.0013 0.9933 1.3035 0.767
[1] Cubic feet (meters) of gas at indicated pressure and temperature per cubic feet (meter) @ standard conditions
Psat - Saturation pressure - Standard conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa)
Pressure
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 28 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 6 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION FLUID VISCOSITY @ 143.6 oF (62.0 oC)
Pressure Oil Viscosity Gas Viscosity Oil - Gas(psia) (MPa) (cp=mPa.s) (cp=mPa.s) Viscosity Ratio
3763 25.94 0.3463513 24.22 0.3403263 22.50 0.3343154 Psat 21.74 0.3312813 19.39 0.357 0.02090 17.082513 17.32 0.382 0.01937 19.712213 15.26 0.412 0.01791 22.991913 13.19 0.437 0.01661 26.341613 11.12 0.470 0.01548 30.351313 9.05 0.508 0.01451 34.981013 6.98 0.556 0.01369 40.61713 4.91 0.628 0.01296 48.44313 2.16 0.842 0.01194 70.5213 0.09 1.460 0.00973 150.02
Psat - Saturation Pressure
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 29 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 7 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITONAL ANALYSIS OF LIBERATED GAS @ 143.6 oF (62.0 oC)
2813 2513 2213 1913 1613 1313 1013 713 313 13
19.39 17.33 15.26 13.19 11.12 9.05 6.98 4.92 2.16 0.09
N2 0.0085 0.0082 0.0081 0.0076 0.0068 0.0061 0.0047 0.0034 0.0015 0.0002
CO 2 0.0039 0.0039 0.0040 0.0041 0.0042 0.0045 0.0049 0.0054 0.0064 0.0044
H2S 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000
C1 0.8196 0.8236 0.8277 0.8298 0.8291 0.8238 0.8118 0.7831 0.6783 0.2572
C2 0.0848 0.0847 0.0850 0.0866 0.0899 0.0954 0.1051 0.1228 0.1775 0.2467
C3 0.0412 0.0401 0.0390 0.0384 0.0390 0.0404 0.0442 0.0525 0.0863 0.2603
i-C4 0.0057 0.0054 0.0051 0.0049 0.0047 0.0048 0.0051 0.0060 0.0096 0.0397
n-C4 0.0145 0.0137 0.0128 0.0120 0.0116 0.0115 0.0120 0.0138 0.0223 0.1013
i-C5 0.0040 0.0038 0.0034 0.0031 0.0028 0.0027 0.0027 0.0030 0.0045 0.0224
n-C5 0.0063 0.0056 0.0050 0.0045 0.0040 0.0038 0.0037 0.0040 0.0060 0.0296
C6 0.0056 0.0053 0.0047 0.0041 0.0035 0.0032 0.0028 0.0030 0.0039 0.0186
C7+ 0.0060 0.0057 0.0052 0.0049 0.0043 0.0037 0.0032 0.0031 0.0036 0.0196
Total 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000
Calculated Properties of Total Sample @ Standard Conditions
MW (g/mol) 20.92 20.76 20.54 20.39 20.29 20.32 20.49 21.13 23.68 38.94
Gravity (Air=1.0) 0.7222 0.7166 0.7093 0.7039 0.7004 0.7016 0.7076 0.7296 0.8174 1.3446
Calculated Properties of C7+ @ Standard Conditions
MW (g/mol) 99.70 101.53 102.47 102.86 102.71 104.38 103.12 104.10 103.41 110.96
Density (g/cc) 0.7291 0.7325 0.7343 0.7349 0.7345 0.7376 0.7353 0.7371 0.7358 0.7439
Component
Differential Liberation Stage Pressure (psia/MPa)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 30 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
TABLE 8 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITONAL ANALYSIS OF RESIDUAL OIL @ 143.6 oF (62.0 oC)
Boiling Point Mole Mass Calculated Properties(C) Fraction Fraction
-195.8 Nitrogen N2 0.0000 0.0000 Total Sample-78.5 Carbon Dioxide CO2 0.0000 0.0000-60.3 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 171.14
-161.7 Methane C1 0.0000 0.0000-88.9 Ethane C2 0.0000 0.0000-42.2 Propane C3 0.0101 0.0027 C6+ Fraction-11.7 i-Butane i-C4 0.0062 0.0022
-0.6 n-Butane n-C4 0.0279 0.0100 Molecular Weight 183.5327.8 i-Pentane i-C5 0.0216 0.0096 Mole Fraction 0.895636.1 n-Pentane n-C5 0.0386 0.0172 Density (g/cc) 0.8339
36.1 - 68.9 Hexanes C6 0.0818 0.043568.9 - 98.3 Heptanes C7 0.0787 0.0486
98.3 - 125.6 Octanes C8 0.0862 0.0607 C7+ Fraction125.6 - 150.6 Nonanes C9 0.0743 0.0588150.6 - 173.9 Decanes C10 0.0572 0.0501 Molecular Weight 194.07173.9 - 196.1 Undecanes C11 0.0541 0.0490 Mole Fraction 0.8089
196.1 - 215 Dodecanes C12 0.0426 0.0423 Density (g/cc) 0.8423215 - 235 Tridecanes C13 0.0442 0.0477
235 - 252.2 Tetradecanes C14 0.0361 0.0423252.2 - 270.6 Pentadecanes C15 0.0276 0.0351 C12+ Fraction270.6 - 287.8 Hexadecanes C16 0.0215 0.0295287.8 - 291.7 Heptadecanes C17 0.0195 0.0285 Molecular Weight 288.48291.7 - 317.2 Octadecanes C18 0.0195 0.0302 Mole Fraction 0.3611
317.2 - 330 Nonadecanes C19 0.0171 0.0277 Density (g/cc) 0.8854330 - 344.4 Eicosanes C20 0.0132 0.0223
344.4 - 357.2 Heneicosanes C21 0.0119 0.0214357.2 - 369.4 Docosanes C22 0.0096 0.0180
369.4 - 380 Tricosanes C23 0.0086 0.0169380 - 391.1 Tetracosanes C24 0.0075 0.0153
391.1 - 401.7 Pentacosanes C25 0.0071 0.0150401.7 - 412.2 Hexacosanes C26 0.0064 0.0142412.3 - 422.2 Heptacosanes C27 0.0055 0.0127422.3 - 431.7 Octacosanes C28 0.0049 0.0118431.7 - 441.1 Nonacosanes C29 0.0043 0.0107Above 441.1 Tricontanes Plus C30+ 0.0539 0.2007
48.9 Cyclopentane C5H10 0.0049 0.002172.2 Methylcyclopentane C6H12 0.0143 0.007481.1 Cyclohexane C6H12 0.0143 0.0074
101.1 Methylcyclohexane C7H14 0.0249 0.0151
80.0 Benzene C6H6 0.0040 0.0019110.6 Toluene C7H8 0.0087 0.0050
136.1 - 138.9 Ethylbenzene & p,m-Xylene C8H10 0.0104 0.0068144.4 o-Xylene C8H10 0.0070 0.0046168.9 1, 2, 4-Trimethylbenzene C9H12 0.0138 0.0102
Total 1.0000 1.0000
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 31 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
CONSTANT COMPOSITION EXPANSION @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 32 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION OIL DENSITY @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 33 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 3 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION OIL FORMATION VOLUME FACTOR @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 34 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 4 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS-OIL RATIOS @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 35 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 5 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION OIL VISCOSITY @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 36 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 6 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS DEVIATION FACTOR @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 37 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 7 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS VOLUME FACTORS @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 38 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 8 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS GRAVITY @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 39 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 9 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS VISCOSITY @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 40 Weatherford Labs File #: CL-79754 Location: A02-4-86-22W6
FIGURE 10 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
LIBERATED GAS COMPOSITION PROFILE @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 41 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Two-stage Separator Test
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 42 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE 9 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
TWO-STAGE SEPARATOR TEST OIL PROPERTIES
Oil Oil Formation Total Formation Gas-Oil Ratio
Density Volume Factor Volume Factor Solution Liberated Solution Liberated(psia) (MPa) (F) (C) (g/cm
3) [1] [2] (scf/STB) (scf/STB) (m
3/m
3) (m
3/m
3)
3154 Psat 21.74 144 62.0 0.6052 1.5874 1.5874 1036.77 0.00 184.65 0.00263 1.81 77 25.0 0.7563 1.0891 9.3522 149.39 887.38 26.61 158.0413 0.09 60 15.6 0.7955 1.0000 105.8852 0.00 1036.77 0.00 184.65
Density of Residual Oil = 0.7955 g/cm3 (795.5 kg/m3) @ 60 F (288.7K)API Gravity of Residual Oil = 46.4[1] Barrels (Cubic meters) of oil at indicated pressure and temperature per barrel (cubic meter) of residual oil @ 60 F (288.7 K).[2] Total barrels (cubic meters) of oil and liberated gas at the indicated pressure and temperature per barrel (cubic meter) of residual oil @ 60 F (288.7 K).Psat - Saturation Pressure - Tank conditions: 60 F (288.7 K) @ 13 psia (0.0896 MPa); Standard conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa).
Pressure Temperature Gas-Oil Ratio
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 43 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE 10 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
TWO-STAGE SEPARATOR TEST GAS PROPERTIES
Gas Gravity Gas Gas Deviation Gas Formation Gas Expansion
Incremental Cumulative Density Factor Volume Factor Factor(psia) (MPa) (F) (C) (Air = 1) (Air = 1) (g/cm
3) (-) [1] [2]
3154 Psat 21.74 144 62.0263 1.81 77 25.0 0.6850 0.6850 0.0153 0.9498 0.0523 19.12613 0.09 60 15.6 1.0597 0.7390 0.0012 0.9933 0.5680 1.760
[1] Cubic feet (meters) of gas at indicated pressure and temperature per cubic feet (meter) @ standard conditions[2] Cubic feet (meters) of gas @ standard conditions per cubic feet (meter) @ indicated pressure and temperature.Psat - Saturation pressure - Standard conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa)
Pressure Temperature
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 44 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE 11 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF TANK OIL
Boiling Point Mole Mass Calculated Properties(C) Fraction Fraction
-195.8 Nitrogen N2 0.0000 0.0000 Total Sample-78.5 Carbon Dioxide CO2 0.0000 0.0000-60.3 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 156.92
-161.7 Methane C1 0.0000 0.0000 Density (g/cc) 0.8059-88.9 Ethane C2 0.0000 0.0000-42.2 Propane C3 0.0416 0.0117 C6+ Fraction-11.7 i-Butane i-C4 0.0146 0.0054
-0.6 n-Butane n-C4 0.0542 0.0201 Molecular Weight 179.5827.8 i-Pentane i-C5 0.0302 0.0139 Mole Fraction 0.809036.1 n-Pentane n-C5 0.0503 0.0231 Density (g/cc) 0.8313
36.1 - 68.9 Hexanes C6 0.0888 0.048868.9 - 98.3 Heptanes C7 0.0762 0.0487
98.3 - 125.6 Octanes C8 0.0794 0.0578 C7+ Fraction125.6 - 150.6 Nonanes C9 0.0659 0.0539150.6 - 173.9 Decanes C10 0.0505 0.0458 Molecular Weight 192.08173.9 - 196.1 Undecanes C11 0.0467 0.0437 Mole Fraction 0.7146
196.1 - 215 Dodecanes C12 0.0365 0.0374 Density (g/cc) 0.8416215 - 235 Tridecanes C13 0.0365 0.0407
235 - 252.2 Tetradecanes C14 0.0286 0.0346252.2 - 270.6 Pentadecanes C15 0.0228 0.0299 C12+ Fraction270.6 - 287.8 Hexadecanes C16 0.0174 0.0247287.8 - 291.7 Heptadecanes C17 0.0167 0.0252 Molecular Weight 292.51291.7 - 317.2 Octadecanes C18 0.0160 0.0256 Mole Fraction 0.3053
317.2 - 330 Nonadecanes C19 0.0142 0.0238 Density (g/cc) 0.8876330 - 344.4 Eicosanes C20 0.0114 0.0200
344.4 - 357.2 Heneicosanes C21 0.0098 0.0182357.2 - 369.4 Docosanes C22 0.0086 0.0166
369.4 - 380 Tricosanes C23 0.0077 0.0157380 - 391.1 Tetracosanes C24 0.0067 0.0142
391.1 - 401.7 Pentacosanes C25 0.0062 0.0136401.7 - 412.2 Hexacosanes C26 0.0053 0.0121412.3 - 422.2 Heptacosanes C27 0.0047 0.0112422.3 - 431.7 Octacosanes C28 0.0042 0.0103431.7 - 441.1 Nonacosanes C29 0.0037 0.0095Above 441.1 Tricontanes Plus C30+ 0.0483 0.1857
48.9 Cyclopentane C5H10 0.0056 0.002572.2 Methylcyclopentane C6H12 0.0147 0.007981.1 Cyclohexane C6H12 0.0142 0.0076
101.1 Methylcyclohexane C7H14 0.0227 0.0142
80.0 Benzene C6H6 0.0040 0.0020110.6 Toluene C7H8 0.0084 0.0049
136.1 - 138.9 Ethylbenzene & p,m-Xylene C8H10 0.0097 0.0066144.4 o-Xylene C8H10 0.0059 0.0040168.9 1, 2, 4-Trimethylbenzene C9H12 0.0110 0.0084
Total 1.0000 1.0000
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 45 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE 12 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
ADJUSTED DIFFERENTIAL LIBERATION DATA TO SEPARATOR CONDITION
Solution Gas-Oil RatioPVT Flash Adjusted PVT Flash Adjusted PVT Flash Adjusted
(psia) (MPa) (scf/STB) (scf/STB) (m3/m
3) (m
3/m
3)
5013 34.56 1.6704 1.5453 1272.66 1036.72 226.66 184.654733 32.63 1.6770 1.5506 1272.66 1036.72 226.66 184.654322 29.80 1.6872 1.5588 1272.66 1036.72 226.66 184.653927 27.07 1.6981 1.5675 1272.66 1036.72 226.66 184.653568 24.60 1.7089 1.5762 1272.66 1036.72 226.66 184.653400 23.44 1.7144 1.5806 1272.66 1036.72 226.66 184.653230 22.27 1.7201 1.5852 1272.66 1036.72 226.66 184.65
3154 Psat 21.74 1.7228 1.5874 1272.66 1036.72 226.66 184.652813 19.39 1.6385 1.5197 1109.71 903.98 197.64 161.012513 17.33 1.5751 1.4688 988.48 805.23 176.05 143.422213 15.26 1.5209 1.4254 870.34 708.99 155.01 126.281913 13.19 1.4720 1.3861 769.34 626.71 137.02 111.621613 11.12 1.4294 1.3520 669.17 545.11 119.18 97.091313 9.05 1.3852 1.3165 574.95 468.36 102.40 83.421013 6.98 1.3489 1.2874 482.69 393.21 85.97 70.03713 4.92 1.3075 1.2541 393.64 320.66 70.11 57.11313 2.16 1.2418 1.2015 263.12 214.34 46.86 38.1813 0.09 1.0378 1.0378 0.00 0.00 0.00 0.00
Psat - Saturation Pressure
Pressure Oil Formation Volume Factor
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 46 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
FIGURE 11 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION OIL FORMATION VOLUME FACTOR @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 47 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
FIGURE 12 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS-OIL RATIOS @ 143.6 oF (62.0 oC)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 48 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix A
RECOMBINED FLUID COMPOSITION
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 49 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE A1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF RESERVOIR FLUID
Boiling Point Component Chemical Mole Mass (C) Name Symbol Fraction Fraction
-195.8 Nitrogen N2 0.0037 0.0014 Total Sample-78.5 Carbon Dioxide CO2 0.0028 0.0017-60.3 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 74.39
-161.7 Methane C1 0.4628 0.0998 Density (g/cc) 0.6549-88.9 Ethane C2 0.0811 0.0328-42.2 Propane C3 0.0605 0.0359 C6+ Fraction-11.7 i-Butane i-C4 0.0106 0.0083
-0.6 n-Butane n-C4 0.0316 0.0247 Molecular Weight 181.2427.8 i-Pentane i-C5 0.0129 0.0126 Mole Fraction 0.313136.1 n-Pentane n-C5 0.0208 0.0202 Density (g/cc) 0.8319
36.1 - 68.9 Hexanes C6 0.0336 0.038968.9 - 98.3 Heptanes C7 0.0289 0.0389 C7+ Fraction
98.3 - 125.6 Octanes C8 0.0299 0.0460125.6 - 150.6 Nonanes C9 0.0254 0.0438 Molecular Weight 193.49150.6 - 173.9 Decanes C10 0.0196 0.0375 Mole Fraction 0.2776173.9 - 196.1 Undecanes C11 0.0179 0.0354 Density (g/cc) 0.8419
196.1 - 215 Dodecanes C12 0.0142 0.0307215 - 235 Tridecanes C13 0.0147 0.0345 C12+ Fraction
235 - 252.2 Tetradecanes C14 0.0116 0.0296252.2 - 270.6 Pentadecanes C15 0.0088 0.0245 Molecular Weight 291.17270.6 - 287.8 Hexadecanes C16 0.0071 0.0211 Mole Fraction 0.1216287.8 - 291.7 Heptadecanes C17 0.0063 0.0199 Density (g/cc) 0.8863291.7 - 317.2 Octadecanes C18 0.0063 0.0214
317.2 - 330 Nonadecanes C19 0.0058 0.0204 C30+ Fraction330 - 344.4 Eicosanes C20 0.0044 0.0164
344.4 - 357.2 Heneicosanes C21 0.0040 0.0157 Molecular Weight 603.51357.2 - 369.4 Docosanes C22 0.0036 0.0147 Mole Fraction 0.0183
369.4 - 380 Tricosanes C23 0.0031 0.0133 Density (g/cc) 0.9864380 - 391.1 Tetracosanes C24 0.0028 0.0125
391.1 - 401.7 Pentacosanes C25 0.0027 0.0127401.7 - 412.2 Hexacosanes C26 0.0023 0.0110 Recombination Parameters412.3 - 422.2 Heptacosanes C27 0.0021 0.0103422.3 - 431.7 Octacosanes C28 0.0019 0.0101 Gas-Oil Ratio (cc/cc) 206.29431.7 - 441.1 Nonacosanes C29 0.0017 0.0092 Dead Oil Density (g/cc) 0.8028Above 441.1 Tricontanes Plus C30+ 0.0183 0.1481 Dead Oil MW (g/mol) 166.46
NAPHTHENES48.9 Cyclopentane C5H10 0.0019 0.001872.2 Methylcyclopentane C6H12 0.0055 0.006381.1 Cyclohexane C6H12 0.0051 0.0058
101.1 Methylcyclohexane C7H14 0.0089 0.0118
AROMATICS80.0 Benzene C6H6 0.0015 0.0016
110.6 Toluene C7H8 0.0031 0.0038136.1 - 138.9 Ethylbenzene & p,m-Xylen C8H10 0.0034 0.0049
144.4 o-Xylene C8H10 0.0024 0.0034168.9 1, 2, 4-Trimethylbenzene C9H12 0.0043 0.0069
Total 1.0000 1.0000Note: Physical Properties calculated based GPA 2145-00 physical constants
Calculated Properties
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 50 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE A2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED OIL
Boiling Point Component Chemical Mole Mass (C) Name Symbol Fraction Fraction
-195.8 Nitrogen N2 0.0000 0.0000 Total Sample-78.5 Carbon Dioxide CO2 0.0000 0.0000-60.3 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 166.46
-161.7 Methane C1 0.0000 0.0000 Density (g/cc) 0.8160-88.9 Ethane C2 0.0000 0.0000-42.2 Propane C3 0.0213 0.0056 C6+ Fraction-11.7 i-Butane i-C4 0.0089 0.0031
-0.6 n-Butane n-C4 0.0370 0.0129 Molecular Weight 182.7227.8 i-Pentane i-C5 0.0250 0.0108 Mole Fraction 0.864236.1 n-Pentane n-C5 0.0436 0.0189 Density (g/cc) 0.8331
36.1 - 68.9 Hexanes C6 0.0857 0.044468.9 - 98.3 Heptanes C7 0.0783 0.0471 C7+ Fraction
98.3 - 125.6 Octanes C8 0.0835 0.0573125.6 - 150.6 Nonanes C9 0.0709 0.0547 Molecular Weight 194.18150.6 - 173.9 Decanes C10 0.0550 0.0470 Mole Fraction 0.7732173.9 - 196.1 Undecanes C11 0.0503 0.0444 Density (g/cc) 0.8423
196.1 - 215 Dodecanes C12 0.0398 0.0385215 - 235 Tridecanes C13 0.0412 0.0433 C12+ Fraction
235 - 252.2 Tetradecanes C14 0.0325 0.0371252.2 - 270.6 Pentadecanes C15 0.0248 0.0307 Molecular Weight 291.17270.6 - 287.8 Hexadecanes C16 0.0199 0.0265 Mole Fraction 0.3413287.8 - 291.7 Heptadecanes C17 0.0176 0.0250 Density (g/cc) 0.8863291.7 - 317.2 Octadecanes C18 0.0178 0.0269
317.2 - 330 Nonadecanes C19 0.0162 0.0256 C30+ Fraction330 - 344.4 Eicosanes C20 0.0124 0.0205
344.4 - 357.2 Heneicosanes C21 0.0112 0.0197 Molecular Weight 603.51357.2 - 369.4 Docosanes C22 0.0101 0.0184 Mole Fraction 0.0512
369.4 - 380 Tricosanes C23 0.0087 0.0167 Density (g/cc) 0.9864380 - 391.1 Tetracosanes C24 0.0079 0.0156
391.1 - 401.7 Pentacosanes C25 0.0077 0.0159401.7 - 412.2 Hexacosanes C26 0.0064 0.0138412.3 - 422.2 Heptacosanes C27 0.0058 0.0129422.3 - 431.7 Octacosanes C28 0.0054 0.0126431.7 - 441.1 Nonacosanes C29 0.0048 0.0116Above 441.1 Tricontanes Plus C30+ 0.0512 0.1857
NAPHTHENES48.9 Cyclopentane C5H10 0.0052 0.002272.2 Methylcyclopentane C6H12 0.0145 0.007381.1 Cyclohexane C6H12 0.0143 0.0072
101.1 Methylcyclohexane C7H14 0.0243 0.0144
AROMATICS80.0 Benzene C6H6 0.0040 0.0019
110.6 Toluene C7H8 0.0086 0.0048136.1 - 138.9 Ethylbenzene & p,m-Xylen C8H10 0.0096 0.0062
144.4 o-Xylene C8H10 0.0067 0.0043168.9 1, 2, 4-Trimethylbenzene C9H12 0.0120 0.0086
Total 1.0000 1.0000Note: Physical Properties calculated based GPA 2145-00 physical constants
Calculated Properties
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 51 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE A3 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED GAS Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0058 0.0058
Carbon Dioxide CO2 0.0044 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.7190 0.7222
Ethane C2 0.1261 0.1266
Propane C3 0.0822 0.0825 53.658 301.261
i-Butane i-C4 0.0115 0.0116 8.940 50.195
n-Butane n-C4 0.0286 0.0287 21.405 120.178
i-Pentane i-C5 0.0063 0.0063 5.447 30.580
n-Pentane n-C5 0.0083 0.0083 7.104 39.887
Hexanes C6 0.0048 0.0048 4.659 26.156
Heptanes C7 0.0023 0.0023 2.483 13.940
Octanes C8 0.0007 0.0007 0.825 4.631
Nonanes C9 0.0002 0.0002 0.211 1.187
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 104.731 588.015
Propanes Plus C3+ 0.1447 0.1453 104.731 588.015
Butanes Plus C4+ 0.0625 0.0628 51.074 286.755
C5+ 0.0224 0.0225 20.729 116.382
Molecular Weight 23.41 kg/kmol 23.41 lb/lb-mol Ppc 659.9 psia 4.55 MPa
Specific Gravity 0.8081 (Air = 1) 0.8081 (Air = 1) Tpc 424.4 R 235.8 K
MW of C7+ 0.31 kg/kmol 0.31 lb/lbmol Ppc* 658.5 psia 4.54 MPa
Density of C7+ 0.7292 g/cc 729.2 kg/m3 Tpc* 423.5 R 235.3 K
Dry 1,385.2 Btu/scf 51.71 MJ/m3 Dry 1,259.8 Btu/scf 47.03 MJ/m3
Wet 1,361.1 Btu/scf 50.81 MJ/m3 Wet 1,237.9 Btu/scf 46.21 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: a160314
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 52 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix B
DIFFERENTIAL LIBERATION-MATERIAL BALANCE
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 53 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE B1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION @ 143.6 oF (62.0 oC)-MATERIAL BALANCE
Measured Calculated Absolute
Oil FVF Oil FVF Relative Error
(psia) (MPa) [1] [1] (% )
3154 Psat 21.74 1.7228 1.7197 0.1813
2813 19.39 1.6385 1.6425 0.2463
2513 17.33 1.5751 1.5786 0.2233
2213 15.26 1.5209 1.5173 0.2399
1913 13.19 1.4720 1.4658 0.4245
1613 11.12 1.4294 1.4205 0.6221
1313 9.05 1.3852 1.3752 0.7306
1013 6.98 1.3489 1.3377 0.8416
713 4.92 1.3075 1.2961 0.8799
313 2.16 1.2418 1.2330 0.7195
13 0.09 1.0378 1.0428 0.4832
[1] (res bbl/STB) (res m3/m3)
Psat - Saturation Pressure
- Tank conditions: 60 F (288.7 K) @ 13 psia (0.09 MPa)
Pressure
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 54 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
FIGURE B1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION @ 143.6 oF (62.0 oC)-MATERIAL BALANCE
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 55 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix C
DIFFERENTIAL LIBERATION -LIBERATED GAS COMPOSITIONS
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 56 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 2813 PSIA (19.39 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0085 0.0085
Carbon Dioxide CO2 0.0039 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8196 0.8228
Ethane C2 0.0848 0.0851
Propane C3 0.0412 0.0414 26.910 151.084
i-Butane i-C4 0.0057 0.0057 4.436 24.906
n-Butane n-C4 0.0145 0.0145 10.835 60.832
i-Pentane i-C5 0.0040 0.0040 3.498 19.639
n-Pentane n-C5 0.0063 0.0063 5.418 30.419
Hexanes C6 0.0056 0.0056 5.450 30.596
Heptanes C7 0.0044 0.0044 4.834 27.143
Octanes C8 0.0012 0.0012 1.424 7.996
Nonanes C9 0.0004 0.0004 0.489 2.746
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 63.293 355.362
Propanes Plus C3+ 0.0833 0.0836 63.293 355.362
Butanes Plus C4+ 0.0421 0.0422 36.384 204.278
C5+ 0.0219 0.0219 21.113 118.540
Molecular Weight 20.92 kg/kmol 20.92 lb/lb-mol Ppc 661.9 psia 4.56 MPa
Specific Gravity 0.7222 (Air = 1) 0.7222 (Air = 1) Tpc 394.2 R 219.0 K
MW of C7+ 99.70 kg/kmol 99.70 lb/lbmol Ppc* 660.5 psia 4.55 MPa
Density of C7+ 0.7291 g/cc 729.1 kg/m3 Tpc* 393.4 R 218.6 K
Dry 1,248.6 Btu/scf 46.61 MJ/m3 Dry 1,132.5 Btu/scf 42.27 MJ/m3
Wet 1,226.9 Btu/scf 45.80 MJ/m3 Wet 1,112.8 Btu/scf 41.54 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160342
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 57 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 2513 PSIA (17.33 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0082 0.0082
Carbon Dioxide CO2 0.0039 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8236 0.8268
Ethane C2 0.0847 0.0850
Propane C3 0.0401 0.0403 26.184 147.010
i-Butane i-C4 0.0054 0.0055 4.214 23.662
n-Butane n-C4 0.0137 0.0138 10.283 57.734
i-Pentane i-C5 0.0038 0.0038 3.302 18.538
n-Pentane n-C5 0.0056 0.0056 4.826 27.093
Hexanes C6 0.0053 0.0053 5.170 29.028
Heptanes C7 0.0036 0.0036 3.931 22.069
Octanes C8 0.0015 0.0015 1.862 10.455
Nonanes C9 0.0006 0.0006 0.738 4.143
Decanes C10 0.0000 0.0000 0.031 0.172
Undecane C11 0.0000 0.0000 0.000 0.003
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 60.541 339.906
Propanes Plus C3+ 0.0797 0.0800 60.541 339.906
Butanes Plus C4+ 0.0396 0.0397 34.357 192.895
C5+ 0.0204 0.0205 19.859 111.499
Molecular Weight 20.76 kg/kmol 20.76 lb/lb-mol Ppc 662.4 psia 4.57 MPa
Specific Gravity 0.7166 (Air = 1) 0.7166 (Air = 1) Tpc 392.7 R 218.2 K
MW of C7+ 101.53 kg/kmol 101.53 lb/lbmol Ppc* 661.0 psia 4.56 MPa
Density of C7+ 0.7325 g/cc 732.5 kg/m3 Tpc* 391.9 R 217.7 K
Dry 1,240.2 Btu/scf 46.29 MJ/m3 Dry 1,124.6 Btu/scf 41.98 MJ/m3
Wet 1,218.6 Btu/scf 45.49 MJ/m3 Wet 1,105.0 Btu/scf 41.25 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160343
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 58 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C3 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 2213 PSIA (15.26 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0081 0.0081
Carbon Dioxide CO2 0.0040 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8277 0.8310
Ethane C2 0.0850 0.0854
Propane C3 0.0390 0.0391 25.444 142.857
i-Butane i-C4 0.0051 0.0051 3.958 22.222
n-Butane n-C4 0.0128 0.0128 9.553 53.634
i-Pentane i-C5 0.0034 0.0034 2.966 16.651
n-Pentane n-C5 0.0050 0.0050 4.301 24.151
Hexanes C6 0.0047 0.0047 4.573 25.678
Heptanes C7 0.0030 0.0030 3.270 18.357
Octanes C8 0.0016 0.0016 1.954 10.968
Nonanes C9 0.0006 0.0007 0.868 4.872
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 56.887 319.390
Propanes Plus C3+ 0.0752 0.0755 56.887 319.390
Butanes Plus C4+ 0.0362 0.0364 31.442 176.533
C5+ 0.0183 0.0184 17.932 100.677
Molecular Weight 20.54 kg/kmol 20.54 lb/lb-mol Ppc 663.1 psia 4.57 MPa
Specific Gravity 0.7093 (Air = 1) 0.7093 (Air = 1) Tpc 390.8 R 217.1 K
MW of C7+ 102.47 kg/kmol 102.47 lb/lbmol Ppc* 661.7 psia 4.56 MPa
Density of C7+ 0.7343 g/cc 734.3 kg/m3 Tpc* 390.0 R 216.6 K
Dry 1,228.5 Btu/scf 45.86 MJ/m3 Dry 1,113.7 Btu/scf 41.57 MJ/m3
Wet 1,207.1 Btu/scf 45.06 MJ/m3 Wet 1,094.3 Btu/scf 40.85 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160344
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 59 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C4 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 1913 PSIA (13.19 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0076 0.0076
Carbon Dioxide CO2 0.0041 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8298 0.8333
Ethane C2 0.0866 0.0870
Propane C3 0.0384 0.0386 25.097 140.907
i-Butane i-C4 0.0049 0.0049 3.771 21.172
n-Butane n-C4 0.0120 0.0120 8.976 50.395
i-Pentane i-C5 0.0031 0.0031 2.676 15.025
n-Pentane n-C5 0.0045 0.0045 3.843 21.576
Hexanes C6 0.0041 0.0041 3.976 22.324
Heptanes C7 0.0027 0.0027 2.978 16.722
Octanes C8 0.0015 0.0015 1.858 10.431
Nonanes C9 0.0007 0.0007 0.910 5.109
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 54.085 303.661
Propanes Plus C3+ 0.0718 0.0721 54.085 303.661
Butanes Plus C4+ 0.0334 0.0335 28.988 162.754
C5+ 0.0166 0.0166 16.241 91.187
Molecular Weight 20.39 kg/kmol 20.39 lb/lb-mol Ppc 663.8 psia 4.58 MPa
Specific Gravity 0.7039 (Air = 1) 0.7039 (Air = 1) Tpc 389.6 R 216.5 K
MW of C7+ 102.86 kg/kmol 102.86 lb/lbmol Ppc* 662.4 psia 4.57 MPa
Density of C7+ 0.7349 g/cc 734.9 kg/m3 Tpc* 388.8 R 216.0 K
Dry 1,220.6 Btu/scf 45.56 MJ/m3 Dry 1,106.4 Btu/scf 41.30 MJ/m3
Wet 1,199.4 Btu/scf 44.77 MJ/m3 Wet 1,087.1 Btu/scf 40.58 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160345
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 60 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C5 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 1613 PSIA (11.12 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0068 0.0068
Carbon Dioxide CO2 0.0042 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8291 0.8326
Ethane C2 0.0899 0.0903
Propane C3 0.0390 0.0392 25.458 142.933
i-Butane i-C4 0.0047 0.0048 3.686 20.696
n-Butane n-C4 0.0116 0.0116 8.668 48.667
i-Pentane i-C5 0.0028 0.0028 2.465 13.838
n-Pentane n-C5 0.0040 0.0041 3.480 19.540
Hexanes C6 0.0035 0.0035 3.408 19.133
Heptanes C7 0.0024 0.0025 2.671 14.998
Octanes C8 0.0012 0.0012 1.500 8.422
Nonanes C9 0.0006 0.0006 0.755 4.240
Decanes C10 0.0000 0.0000 0.035 0.194
Undecane C11 0.0000 0.0000 0.000 0.002
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 52.126 292.664
Propanes Plus C3+ 0.0700 0.0703 52.126 292.664
Butanes Plus C4+ 0.0310 0.0311 26.669 149.731
C5+ 0.0146 0.0147 14.314 80.368
Molecular Weight 20.29 kg/kmol 20.29 lb/lb-mol Ppc 664.6 psia 4.58 MPa
Specific Gravity 0.7004 (Air = 1) 0.7004 (Air = 1) Tpc 389.3 R 216.3 K
MW of C7+ 102.71 kg/kmol 102.71 lb/lbmol Ppc* 663.2 psia 4.57 MPa
Density of C7+ 0.7345 g/cc 734.5 kg/m3 Tpc* 388.4 R 215.8 K
Dry 1,216.2 Btu/scf 45.40 MJ/m3 Dry 1,102.2 Btu/scf 41.14 MJ/m3
Wet 1,195.0 Btu/scf 44.61 MJ/m3 Wet 1,083.0 Btu/scf 40.42 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160346
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 61 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C6 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 1313 PSIA (9.05 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0061 0.0062
Carbon Dioxide CO2 0.0045 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8238 0.8276
Ethane C2 0.0954 0.0958
Propane C3 0.0404 0.0406 26.379 148.107
i-Butane i-C4 0.0048 0.0048 3.702 20.787
n-Butane n-C4 0.0115 0.0115 8.594 48.249
i-Pentane i-C5 0.0027 0.0027 2.360 13.252
n-Pentane n-C5 0.0038 0.0039 3.309 18.577
Hexanes C6 0.0032 0.0032 3.133 17.588
Heptanes C7 0.0018 0.0018 1.942 10.903
Octanes C8 0.0013 0.0013 1.559 8.755
Nonanes C9 0.0007 0.0007 0.893 5.013
Decanes C10 0.0000 0.0000 0.019 0.107
Undecane C11 0.0000 0.0000 0.000 0.002
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 51.891 291.341
Propanes Plus C3+ 0.0702 0.0705 51.891 291.341
Butanes Plus C4+ 0.0298 0.0299 25.511 143.234
C5+ 0.0135 0.0136 13.215 74.198
Molecular Weight 20.32 kg/kmol 20.32 lb/lb-mol Ppc 665.3 psia 4.59 MPa
Specific Gravity 0.7016 (Air = 1) 0.7016 (Air = 1) Tpc 390.3 R 216.8 K
MW of C7+ 104.38 kg/kmol 104.38 lb/lbmol Ppc* 663.7 psia 4.58 MPa
Density of C7+ 0.7376 g/cc 737.6 kg/m3 Tpc* 389.4 R 216.3 K
Dry 1,218.3 Btu/scf 45.47 MJ/m3 Dry 1,104.1 Btu/scf 41.21 MJ/m3
Wet 1,197.1 Btu/scf 44.68 MJ/m3 Wet 1,084.9 Btu/scf 40.50 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160347
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 62 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C7 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 1013 PSIA (6.98 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0047 0.0048
Carbon Dioxide CO2 0.0049 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8118 0.8157
Ethane C2 0.1051 0.1056
Propane C3 0.0442 0.0444 28.871 162.099
i-Butane i-C4 0.0051 0.0051 3.922 22.022
n-Butane n-C4 0.0120 0.0120 8.969 50.354
i-Pentane i-C5 0.0027 0.0027 2.313 12.988
n-Pentane n-C5 0.0037 0.0037 3.169 17.791
Hexanes C6 0.0028 0.0028 2.722 15.284
Heptanes C7 0.0017 0.0017 1.902 10.680
Octanes C8 0.0009 0.0010 1.151 6.461
Nonanes C9 0.0005 0.0005 0.650 3.650
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 53.670 301.329
Propanes Plus C3+ 0.0736 0.0739 53.670 301.329
Butanes Plus C4+ 0.0293 0.0295 24.798 139.230
C5+ 0.0123 0.0124 11.907 66.854
Molecular Weight 20.49 kg/kmol 20.49 lb/lb-mol Ppc 666.1 psia 4.59 MPa
Specific Gravity 0.7076 (Air = 1) 0.7076 (Air = 1) Tpc 393.4 R 218.5 K
MW of C7+ 103.12 kg/kmol 103.12 lb/lbmol Ppc* 664.4 psia 4.58 MPa
Density of C7+ 0.7353 g/cc 735.3 kg/m3 Tpc* 392.4 R 218.0 K
Dry 1,229.2 Btu/scf 45.88 MJ/m3 Dry 1,114.2 Btu/scf 41.59 MJ/m3
Wet 1,207.8 Btu/scf 45.08 MJ/m3 Wet 1,094.9 Btu/scf 40.87 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160349
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 63 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C8 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 713 PSIA (4.92 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0034 0.0035
Carbon Dioxide CO2 0.0054 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.7831 0.7873
Ethane C2 0.1228 0.1235
Propane C3 0.0525 0.0528 34.298 192.564
i-Butane i-C4 0.0060 0.0060 4.631 25.999
n-Butane n-C4 0.0138 0.0138 10.297 57.812
i-Pentane i-C5 0.0030 0.0030 2.586 14.520
n-Pentane n-C5 0.0040 0.0040 3.430 19.256
Hexanes C6 0.0030 0.0030 2.938 16.493
Heptanes C7 0.0015 0.0015 1.648 9.252
Octanes C8 0.0010 0.0010 1.223 6.868
Nonanes C9 0.0005 0.0006 0.732 4.110
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 61.782 346.875
Propanes Plus C3+ 0.0853 0.0857 61.782 346.875
Butanes Plus C4+ 0.0328 0.0329 27.484 154.311
C5+ 0.0130 0.0131 12.557 70.500
Molecular Weight 21.13 kg/kmol 21.13 lb/lb-mol Ppc 666.3 psia 4.59 MPa
Specific Gravity 0.7296 (Air = 1) 0.7296 (Air = 1) Tpc 401.4 R 223.0 K
MW of C7+ 104.10 kg/kmol 104.10 lb/lbmol Ppc* 664.5 psia 4.58 MPa
Density of C7+ 0.7371 g/cc 737.1 kg/m3 Tpc* 400.4 R 222.4 K
Dry 1,264.2 Btu/scf 47.19 MJ/m3 Dry 1,146.9 Btu/scf 42.81 MJ/m3
Wet 1,242.2 Btu/scf 46.37 MJ/m3 Wet 1,126.9 Btu/scf 42.07 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160350
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 64 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C9 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 313 PSIA (2.16 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0015 0.0015
Carbon Dioxide CO2 0.0064 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.6783 0.6826
Ethane C2 0.1775 0.1787
Propane C3 0.0863 0.0869 56.367 316.470
i-Butane i-C4 0.0096 0.0097 7.476 41.974
n-Butane n-C4 0.0223 0.0225 16.709 93.811
i-Pentane i-C5 0.0045 0.0045 3.920 22.006
n-Pentane n-C5 0.0060 0.0061 5.176 29.060
Hexanes C6 0.0039 0.0039 3.786 21.255
Heptanes C7 0.0020 0.0020 2.144 12.040
Octanes C8 0.0011 0.0011 1.282 7.195
Nonanes C9 0.0006 0.0006 0.814 4.569
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 97.672 548.381
Propanes Plus C3+ 0.1363 0.1372 97.672 548.381
Butanes Plus C4+ 0.0500 0.0503 41.306 231.911
C5+ 0.0180 0.0181 17.121 96.126
Molecular Weight 23.68 kg/kmol 23.68 lb/lb-mol Ppc 665.0 psia 4.58 MPa
Specific Gravity 0.8174 (Air = 1) 0.8174 (Air = 1) Tpc 431.8 R 239.9 K
MW of C7+ 103.41 kg/kmol 103.41 lb/lbmol Ppc* 663.1 psia 4.57 MPa
Density of C7+ 0.7358 g/cc 735.8 kg/m3 Tpc* 430.5 R 239.2 K
Dry 1,401.6 Btu/scf 52.32 MJ/m3 Dry 1,275.1 Btu/scf 47.60 MJ/m3
Wet 1,377.2 Btu/scf 51.41 MJ/m3 Wet 1,252.9 Btu/scf 46.77 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160351
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 65 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE C10 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
DIFFERENTIAL LIBERATION GAS @ 13 PSIA (0.09 MPa)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0002 0.0002
Carbon Dioxide CO2 0.0044 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.2572 0.2584
Ethane C2 0.2467 0.2478
Propane C3 0.2603 0.2615 169.985 954.385
i-Butane i-C4 0.0397 0.0399 30.790 172.871
n-Butane n-C4 0.1013 0.1017 75.755 425.325
i-Pentane i-C5 0.0224 0.0225 19.498 109.471
n-Pentane n-C5 0.0296 0.0298 25.484 143.081
Hexanes C6 0.0186 0.0187 18.152 101.912
Heptanes C7 0.0098 0.0098 10.679 59.960
Octanes C8 0.0044 0.0044 5.350 30.037
Nonanes C9 0.0019 0.0019 2.557 14.355
Decanes C10 0.0008 0.0008 1.206 6.772
Undecane C11 0.0006 0.0006 0.881 4.948
Dodecanes Plus C12+ 0.0021 0.0021 3.569 20.037
Total 1.0000 1.0000 363.906 2043.152
Propanes Plus C3+ 0.4915 0.4936 363.906 2043.152
Butanes Plus C4+ 0.2312 0.2322 193.920 1088.767
C5+ 0.0902 0.0906 87.376 490.572
Molecular Weight 38.94 kg/kmol 38.94 lb/lb-mol Ppc 629.1 psia 4.34 MPa
Specific Gravity 1.3446 (Air = 1) 1.3446 (Air = 1) Tpc 587.1 R 326.2 K
MW of C7+ 110.96 kg/kmol 110.96 lb/lbmol Ppc* 628.2 psia 4.33 MPa
Density of C7+ 0.7439 g/cc 743.9 kg/m3 Tpc* 586.2 R 325.7 K
Dry 2,229.6 Btu/scf 83.23 MJ/m3 Dry 2,047.7 Btu/scf 76.44 MJ/m3
Wet 2,190.8 Btu/scf 81.78 MJ/m3 Wet 2,012.1 Btu/scf 75.11 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160352
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 66 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix D
MULTI-STAGE SEPARATOR TEST-MATERIAL BALANCE
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 67 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE D1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
SEPARATOR TEST - MATERIAL BALANCE
Measured Calculated Absolute
Oil FVF Oil FVF Relative Error
(psia) (MPa) [1] [1] (% )
3154 Psat 21.74 1.5874 1.5902 0.1754
263 1.81 1.0891 1.0974 0.7524
13 0.09 1.0000 1.0000 0.0052
[1] (res bbl/STB) (res m3/m3)
Psat - Saturation Pressure
- Tank conditions: 60 F (288.7 K) @ 13 psia (0.09 MPa)
Pressure
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 68 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix E
MULTI-STAGE SEPARATOR TEST -LIBERATED GAS COMPOSITIONS
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 69 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE E1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
MULTI-STAGE SEPARATOR GAS @ 263 PSIA (1.81 MPa) & 77.0°F (25.0°C)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0090 0.0091
Carbon Dioxide CO2 0.0050 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.8218 0.8259
Ethane C2 0.1044 0.1050
Propane C3 0.0407 0.0409 26.578 149.224
i-Butane i-C4 0.0040 0.0041 3.128 17.563
n-Butane n-C4 0.0088 0.0088 6.555 36.805
i-Pentane i-C5 0.0016 0.0016 1.425 8.002
n-Pentane n-C5 0.0021 0.0021 1.811 10.165
Hexanes C6 0.0013 0.0013 1.263 7.093
Heptanes C7 0.0007 0.0007 0.736 4.133
Octanes C8 0.0003 0.0004 0.424 2.378
Nonanes C9 0.0002 0.0002 0.237 1.329
Decanes C10 0.0000 0.0000 0.015 0.084
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 42.172 236.777
Propanes Plus C3+ 0.0597 0.0600 42.172 236.777
Butanes Plus C4+ 0.0190 0.0191 15.594 87.553
Pentanes Plus C5+ 0.0062 0.0063 5.910 33.185
Molecular Weight 19.84 kg/kmol 19.84 lb/lb-mol Ppc 667.4 psia 4.60 MPa
Specific Gravity 0.6850 (Air = 1) 0.6850 (Air = 1) Tpc 386.4 R 214.7 K
MW of C7+ 103.16 kg/kmol 103.16 lb/lbmol Ppc* 665.7 psia 4.59 MPa
Density of C7+ 0.7353 g/cc 735.3 kg/m3 Tpc* 385.4 R 214.1 K
Dry 1,186.8 Btu/scf 44.30 MJ/m3 Dry 1,074.9 Btu/scf 40.12 MJ/m3
Wet 1,166.2 Btu/scf 43.53 MJ/m3 Wet 1,056.2 Btu/scf 39.42 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160408
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 70 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE E2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – RECOMBINED SAMPLE RESERVOIR FLUID STUDY
MULTI-STAGE SEPARATOR GAS @ 13 PSIA (0.09 MPa) & 60.0°F (15.6°C)
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0025 0.0025
Carbon Dioxide CO2 0.0055 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.4212 0.4235
Ethane C2 0.2528 0.2542
Propane C3 0.2105 0.2116 137.446 771.694
i-Butane i-C4 0.0253 0.0255 19.642 110.281
n-Butane n-C4 0.0559 0.0562 41.850 234.967
i-Pentane i-C5 0.0092 0.0092 7.955 44.664
n-Pentane n-C5 0.0108 0.0108 9.247 51.917
Hexanes C6 0.0044 0.0044 4.260 23.919
Heptanes C7 0.0016 0.0016 1.707 9.585
Octanes C8 0.0003 0.0003 0.407 2.285
Nonanes C9 0.0001 0.0001 0.195 1.094
Decanes C10 0.0000 0.0000 0.052 0.294
Undecane C11 0.0000 0.0000 0.000 0.002
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 222.763 1250.702
Propanes Plus C3+ 0.3181 0.3198 222.763 1250.702
Butanes Plus C4+ 0.1076 0.1082 85.316 479.008
Pentanes Plus C5+ 0.0263 0.0265 23.824 133.761
Molecular Weight 30.69 kg/kmol 30.69 lb/lb-mol Ppc 653.7 psia 4.51 MPa
Specific Gravity 1.0597 (Air = 1) 1.0597 (Air = 1) Tpc 511.3 R 284.0 K
MW of C7+ 100.19 kg/kmol 100.19 lb/lbmol Ppc* 652.3 psia 4.50 MPa
Density of C7+ 0.7296 g/cc 729.6 kg/m3 Tpc* 510.2 R 283.4 K
Dry 1,779.4 Btu/scf 66.42 MJ/m3 Dry 1,627.6 Btu/scf 60.75 MJ/m3
Wet 1,748.4 Btu/scf 65.26 MJ/m3 Wet 1,599.3 Btu/scf 59.70 MJ/m3
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC No.: A160412
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Mole Fraction Liquid Volume
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 71 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix F
SELECTED SEPARATOR SAMPLES VALIDATION
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 72 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE F1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – SAMPLE CYL3859 RESERVOIR FLUID STUDY
SEPARATOR GAS - SAMPLE COLLECTION DATA
Project File: CL-79574
Company: ARC RESOURCES LTD.
Pool: MONTNEY
Field: RED CREEK
Well Location: RED A02-04-086-22W6
Fluid Sample: CYL3589
Sample Description: RATE 3 SEP GAS
Sampling Company: WFT
Name of Sampler: NA
Sampling Date: 13-Nov-15
Sampling Point: SEPARATOR
Sampling Temperature: 77.0 F 25 C
Sampling Pressure: 150 psia 1.03 MPa
Reservoir Temperature: N/A F N/A C
Reservoir Pressure: N/A psia N/A MPa
Initial Reservoir Pressure (Pi) N/A psia N/A MPa
Depth of Reported Pi N/A mMD N/A mss
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 73 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE F2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – SAMPLE CYL3589 RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF SEPARATOR GAS
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0074 0.0074
Carbon Dioxide CO2 0.0046 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.7861 0.7897
Ethane C2 0.1135 0.1140
Propane C3 0.0578 0.0580 37.720 211.777
i-Butane i-C4 0.0068 0.0068 5.239 29.413
n-Butane n-C4 0.0152 0.0153 11.385 63.923
i-Pentane i-C5 0.0027 0.0028 2.386 13.396
n-Pentane n-C5 0.0034 0.0034 2.928 16.442
Hexanes C6 0.0017 0.0017 1.631 9.155
Heptanes C7 0.0007 0.0007 0.741 4.159
Octanes C8 0.0002 0.0002 0.255 1.433
Nonanes C9 0.0001 0.0001 0.077 0.434
Decanes C10 0.0000 0.0000 0.016 0.092
Undecane C11 0.0000 0.0000 0.001 0.007
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 62.380 350.232
Propanes Plus C3+ 0.0885 0.0889 62.380 350.232
Butanes Plus C4+ 0.0307 0.0309 24.660 138.455
Pentanes Plus C5+ 0.0088 0.0088 8.036 45.119
Molecular Weight 20.94 kg/kmol 20.94 lb/lb-mol Ppc 665.4 psia 4.59 MPa
Specific Gravity 0.7229 (Air = 1) 0.7229 (Air = 1) Tpc 398.9 R 221.6 K
MW of C7+ 100.42 kg/kmol 100.42 lb/lbmol Ppc* 663.9 psia 4.58 MPa
Density of C7+ 0.7303 g/cc 730.3 kg/m3 Tpc* 398.0 R 221.1 K
Dry 1,249.6 Btu/scf 46.64 MJ/m3 Dry 1,133.3 Btu/scf 42.30 MJ/m3
Wet 1,227.8 Btu/scf 45.83 MJ/m3 Wet 1,113.6 Btu/scf 41.57 MJ/m3
* - Corrected for Acid Gas Content
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC ID: A151429 ID: 22144
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Liquid VolumeMole Fraction
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 74 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE F3 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – SAMPLE W3A7801 RESERVOIR FLUID STUDY
SEPARATOR LIQUID- SAMPLE COLLECTION DATA
Project File: CL-79574
Company: ARC RESOURCES LTD.
Pool: MONTNEY
Field: RED CREEK
Well Location: RED A02-4-86-22W6
Fluid Sample: W3A7801
Sample Description: RATE 3 LIQUID
Sampling Company: WFT
Name of Sampler: NA
Sampling Date: 13-Nov-15
Sampling Point: SEPARATOR
Sampling Temperature: 77.0 F 25 C
Sampling Pressure: 150 psia 1.03 MPa
Reservoir Temperature: N/A F N/A C
Reservoir Pressure: N/A psia N/A MPa
Initial Reservoir Pressure (Pi) N/A psia N/A MPa
Depth of Reported Pi N/A mMD N/A mss
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 75 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE F4 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – SAMPLE W3A7801 RESERVOIR FLUID STUDY
SEPARATOR LIQUID- SAMPLE VALIDATION DATA
INITIAL RESERVOIR CONDITIONSReservoir Pressure N/A psia N/A MPa
Reservoir Temperature: N/A F N/A C
SINGLE-STAGE SEPARATOR TEST @ 1,638 psia (11.29 MPa) AND 140.0 F (333.2 K)At Separator Test Conditions
Oil Formation Volume Factor 1.0531 res.bbl/STB 1.0531 res.m3/m
3
Solution Gas-Oil Ratio 102.67 scf/STB 18.29 m3/m
3
Oil Density 0.7868 g/cm3
786.8 kg/m3
At Tank Conditions
Residual Oil Density 0.7956 g/cm3
795.6 kg/m3
API Gravity 46.35 46.35
SINGLE-STAGE SEPARATOR TEST - MATERIAL BALANCE CHECK
Oil FVF @ 1638 psia (11.29 MPa) (Measured) 1.0531 res.bbl/STB (res.m3/m
3)
Oil FVF @ 1638 psia (11.29 MPa) (Calculated) 1.0496 res.bbl/STB (res.m3/m
3)
Absolute Relative Error 0.3342 (%)
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 76 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE F5 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – SAMPLE W3A7801 RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF SEPARATOR FLUID
Boiling Point Component Chemical Mole Mass (K) Name Symbol Fraction Fraction
77.4 Nitrogen N2 0.0006 0.0001 Total Sample194.6 Carbon Dioxide CO2 0.0004 0.0001212.8 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 141.85111.5 Methane C1 0.0271 0.0031184.3 Ethane C2 0.0319 0.0068231.0 Propane C3 0.0655 0.0204 C6+ Fraction261.5 i-Butane i-C4 0.0209 0.0086272.6 n-Butane n-C4 0.0713 0.0292 Molecular Weight 182.38301.0 i-Pentane i-C5 0.0359 0.0182 Mole Fraction 0.6822309.3 n-Pentane n-C5 0.0596 0.0303 Density (g/cc) 0.8331
309.3 - 342 Hexanes C6 0.0730 0.0444342 - 371.4 Heptanes C7 0.0630 0.0445 C7+ Fraction
371.4 - 398.8 Octanes C8 0.0660 0.0531398.8 - 423.8 Nonanes C9 0.0555 0.0502 Molecular Weight 194.71
423.8 - 447 Decanes C10 0.0444 0.0446 Mole Fraction 0.5815447 - 469.3 Undecanes C11 0.0399 0.0413 Density (g/cc) 0.8430
469.3 - 488.2 Dodecanes C12 0.0311 0.0353488.2 - 508.2 Tridecanes C13 0.0318 0.0392 C12+ Fraction508.2 - 525.4 Tetradecanes C14 0.0244 0.0327525.4 - 543.8 Pentadecanes C15 0.0193 0.0281 Molecular Weight 294.26543.8 - 560.9 Hexadecanes C16 0.0148 0.0232 Mole Fraction 0.2667560.9 - 564.8 Heptadecanes C17 0.0140 0.0234 Density (g/cc) 0.8880564.8 - 590.4 Octadecanes C18 0.0136 0.0241590.4 - 603.2 Nonadecanes C19 0.0126 0.0233 C30+ Fraction603.2 - 617.5 Eicosanes C20 0.0098 0.0190617.5 - 630.4 Heneicosanes C21 0.0089 0.0182 Molecular Weight 603.51630.4 - 642.5 Docosanes C22 0.0077 0.0166 Mole Fraction 0.0420642.5 - 653.2 Tricosanes C23 0.0071 0.0160 Density (g/cc) 0.9864653.2 - 664.3 Tetracosanes C24 0.0061 0.0143664.3 - 674.9 Pentacosanes C25 0.0059 0.0142674.9 - 685.4 Hexacosanes C26 0.0052 0.0131 Recombination Parameters685.4 - 695.4 Heptacosanes C27 0.0045 0.0120695.4 - 704.9 Octacosanes C28 0.0041 0.0113 Gas-Oil Ratio (cc/cc) 18.29704.9 - 714.3 Nonacosanes C29 0.0036 0.0103 Dead Oil Density (g/cc) 0.7956Above 714.3 Tricontanes Plus C30+ 0.0420 0.1789 Dead Oil MW (g/mol) 157.54
NAPHTHENES322.0 Cyclopentane C5H10 0.0047 0.0023345.4 Methylcyclopentane C6H12 0.0123 0.0073354.3 Cyclohexane C6H12 0.0118 0.0070374.3 Methylcyclohexane C7H14 0.0195 0.0135
AROMATICS353.2 Benzene C6H6 0.0035 0.0019383.8 Toluene C7H8 0.0069 0.0045
409.3 - 412 Ethylbenzene & p,m-Xylen C8H10 0.0052 0.0039417.5 o-Xylene C8H10 0.0075 0.0056442.0 1, 2, 4-Trimethylbenzene C9H12 0.0069 0.0058
Total 1.0000 1.0000Note: Physical properties are calculated based on GPA 2145-00 physical constants ID.: 9571-3838
Calculated Properties
0.00
0.02
0.04
0.06
0.08
0.10
0.12
N2
CO
2H
2S
C1
C2
C3
C4
C5
C6
C7
C8
C9
C10
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
+
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 77 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE F6 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – SAMPLE W3A7801 RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED OIL
Boiling Point Component Chemical Mole Mass (K) Name Symbol Fraction Fraction
77.4 Nitrogen N2 0.0000 0.0000 Total Sample194.6 Carbon Dioxide CO2 0.0000 0.0000212.8 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 157.54111.5 Methane C1 0.0000 0.0000 Density (g/cc) 0.8057184.3 Ethane C2 0.0000 0.0000231.0 Propane C3 0.0274 0.0077 C6+ Fraction261.5 i-Butane i-C4 0.0162 0.0060272.6 n-Butane n-C4 0.0633 0.0233 Molecular Weight 182.58301.0 i-Pentane i-C5 0.0379 0.0174 Mole Fraction 0.7904309.3 n-Pentane n-C5 0.0648 0.0297 Density (g/cc) 0.8332
309.3 - 342 Hexanes C6 0.0828 0.0453342 - 371.4 Heptanes C7 0.0726 0.0462 C7+ Fraction
371.4 - 398.8 Octanes C8 0.0760 0.0551398.8 - 423.8 Nonanes C9 0.0639 0.0521 Molecular Weight 194.82
423.8 - 447 Decanes C10 0.0512 0.0463 Mole Fraction 0.7021447 - 469.3 Undecanes C11 0.0460 0.0429 Density (g/cc) 0.8430
469.3 - 488.2 Dodecanes C12 0.0358 0.0366488.2 - 508.2 Tridecanes C13 0.0366 0.0407 C12+ Fraction508.2 - 525.4 Tetradecanes C14 0.0282 0.0340525.4 - 543.8 Pentadecanes C15 0.0223 0.0291 Molecular Weight 294.26543.8 - 560.9 Hexadecanes C16 0.0171 0.0241 Mole Fraction 0.3074560.9 - 564.8 Heptadecanes C17 0.0161 0.0242 Density (g/cc) 0.8880564.8 - 590.4 Octadecanes C18 0.0157 0.0250590.4 - 603.2 Nonadecanes C19 0.0145 0.0242 C30+ Fraction603.2 - 617.5 Eicosanes C20 0.0113 0.0198617.5 - 630.4 Heneicosanes C21 0.0103 0.0189 Molecular Weight 603.51630.4 - 642.5 Docosanes C22 0.0089 0.0172 Mole Fraction 0.0485642.5 - 653.2 Tricosanes C23 0.0082 0.0166 Density (g/cc) 0.9864653.2 - 664.3 Tetracosanes C24 0.0071 0.0149664.3 - 674.9 Pentacosanes C25 0.0067 0.0148674.9 - 685.4 Hexacosanes C26 0.0060 0.0136685.4 - 695.4 Heptacosanes C27 0.0052 0.0124695.4 - 704.9 Octacosanes C28 0.0047 0.0117704.9 - 714.3 Nonacosanes C29 0.0042 0.0107Above 714.3 Tricontanes Plus C30+ 0.0485 0.1857
NAPHTHENES322.0 Cyclopentane C5H10 0.0055 0.0024345.4 Methylcyclopentane C6H12 0.0142 0.0076354.3 Cyclohexane C6H12 0.0136 0.0073374.3 Methylcyclohexane C7H14 0.0224 0.0140
AROMATICS353.2 Benzene C6H6 0.0040 0.0020383.8 Toluene C7H8 0.0080 0.0047
409.3 - 412 Ethylbenzene & p,m-Xylen C8H10 0.0060 0.0040417.5 o-Xylene C8H10 0.0087 0.0059442.0 1, 2, 4-Trimethylbenzene C9H12 0.0080 0.0061
Total 1.0000 1.0000Note: Physical properties are calculated based on GPA 2145-00 physical constants GC ID: B151056
Calculated Properties
0.00
0.02
0.04
0.06
0.08
0.10
0.12
N2
CO
2H
2S
C1
C2
C3
C4
C5
C6
C7
C8
C9
C10
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
+
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 78 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE F7 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – SAMPLE W3A7801 RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED GAS
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0043 0.0044
Carbon Dioxide CO2 0.0029 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.2040 0.2046
Ethane C2 0.2404 0.2411
Propane C3 0.3144 0.3153 205.305 1152.688
i-Butane i-C4 0.0514 0.0516 39.908 224.063
n-Butane n-C4 0.1237 0.1240 92.516 519.434
i-Pentane i-C5 0.0226 0.0226 19.623 110.174
n-Pentane n-C5 0.0260 0.0261 22.380 125.653
Hexanes C6 0.0090 0.0090 8.796 49.386
Heptanes C7 0.0012 0.0012 1.282 7.198
Octanes C8 0.0001 0.0001 0.114 0.641
Nonanes C9 0.0000 0.0000 0.000 0.000
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 389.925 2189.236
Propanes Plus C3+ 0.5484 0.5500 389.925 2189.236
Butanes Plus C4+ 0.2340 0.2347 184.620 1036.548
Pentanes Plus C5+ 0.0589 0.0591 52.195 293.051
Molecular Weight 39.20 kg/kmol 39.20 lb/lb-mol Ppc 628.9 psia 4.34 MPa
Specific Gravity 1.3533 (Air = 1) 1.3533 (Air = 1) Tpc 596.6 R 331.4 K
MW of C7+ 96.82 kg/kmol 96.82 lb/lbmol Ppc* 628.3 psia 4.33 MPa
Density of C7+ 0.7237 g/cc 723.7 kg/m3 Tpc* 596.0 R 331.1 K
Dry 2,238.0 Btu/scf 83.54 MJ/m3 Dry 2,055.4 Btu/scf 76.72 MJ/m3
Wet 2,199.0 Btu/scf 82.08 MJ/m3 Wet 2,019.6 Btu/scf 75.39 MJ/m3
* - Corrected for Acid Gas Content
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC ID: A151481
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Liquid VolumeMole Fraction
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 79 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix G
WFT OIL SYSTEM CHARACTERIZATION PROTOCOL
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 80 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 81 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix H
HIGH GOR RECOMBINED FLUID
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 82 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE H1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – HIGH GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
SAMPLE COLLECTION DATA
Project File: CL-79574
Company: ARC RESOURCES LTD.
Pool: MONTNEY
Field: RED CREEK
Well Location: RED A02-4-86-22W6
Fluid Sample: RECOMBINED
Sample Description: RECOMBINED AT 1083 M3/M3
Sampling Company: WFT
Name of Sampler: NA
Sampling Date: 13-Nov-15
Sampling Point: SEPARATOR
Sampling Temperature: 77.0 F 25 C
Sampling Pressure: 165.0 psia 1.14 MPa
Reservoir Temperature: 143.6 F 62.0 C
Reservoir Pressure: 3154.0 psia 21.75 MPa
Initial Reservoir Pressure (Pi) N/A psia N/A MPa
Depth of Reported Pi N/A mMD N/A mss
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 83 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE H2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – HIGH GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
SAMPLE VALIDATION DATA
INITIAL RESERVOIR CONDITIONSReservoir Pressure 3154 psia 21.75 MPa
Reservoir Temperature: 143.6 F 62.0 C
SINGLE-STAGE SEPARATOR TEST @ 6,553 psia (45.18 MPa) AND 143.6 F (335.2 K)At Separator Test Conditions
Oil Formation Volume Factor 4.2431 res.bbl/STB 4.2431 res.m3/m
3
Solution Gas-Oil Ratio 6458.31 scf/STB 1150.23 m3/m
3
Oil Density 0.4438 g/cm3
443.8 kg/m3
At Tank Conditions
Residual Oil Density 0.8099 g/cm3
809.9 kg/m3
API Gravity 43.21 43.21
SINGLE-STAGE SEPARATOR TEST - MATERIAL BALANCE CHECK
Oil FVF @ 6553 psia (45.18 MPa) (Measured) 4.2431 res.bbl/STB (res.m3/m
3)
Oil FVF @ 6553 psia (45.18 MPa) (Calculated) 4.2331 res.bbl/STB (res.m3/m
3)
Absolute Relative Error 0.2363 (%)
SATURATION PRESSURE @ 143.6 F (335.2 K)Apparent Dew Point Pressure 6370 psia 43.92 Mpa
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 84 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE H3 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – HIGH GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF RECOMBINED FLUID
Boiling Point Component Chemical Mole Mass (K) Name Symbol Fraction Fraction
77.4 Nitrogen N2 0.0083 0.0066 Total Sample194.6 Carbon Dioxide CO2 0.0041 0.0051212.8 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 35.20111.5 Methane C1 0.6909 0.3150184.3 Ethane C2 0.1056 0.0902231.0 Propane C3 0.0617 0.0773 C6+ Fraction261.5 i-Butane i-C4 0.0084 0.0139272.6 n-Butane n-C4 0.0213 0.0351 Molecular Weight 176.94301.0 i-Pentane i-C5 0.0061 0.0124 Mole Fraction 0.0844309.3 n-Pentane n-C5 0.0090 0.0185 Density (g/cc) 0.8280
309.3 - 342 Hexanes C6 0.0112 0.0275342 - 371.4 Heptanes C7 0.0084 0.0240 C7+ Fraction
371.4 - 398.8 Octanes C8 0.0079 0.0256398.8 - 423.8 Nonanes C9 0.0067 0.0245 Molecular Weight 187.78
423.8 - 447 Decanes C10 0.0050 0.0204 Mole Fraction 0.0700447 - 469.3 Undecanes C11 0.0046 0.0192 Density (g/cc) 0.8404
469.3 - 488.2 Dodecanes C12 0.0036 0.0165488.2 - 508.2 Tridecanes C13 0.0037 0.0186 C12+ Fraction508.2 - 525.4 Tetradecanes C14 0.0030 0.0162525.4 - 543.8 Pentadecanes C15 0.0023 0.0136 Molecular Weight 290.51543.8 - 560.9 Hexadecanes C16 0.0018 0.0114 Mole Fraction 0.0314560.9 - 564.8 Heptadecanes C17 0.0017 0.0116 Density (g/cc) 0.8859564.8 - 590.4 Octadecanes C18 0.0017 0.0118590.4 - 603.2 Nonadecanes C19 0.0015 0.0114 C30+ Fraction603.2 - 617.5 Eicosanes C20 0.0012 0.0092617.5 - 630.4 Heneicosanes C21 0.0010 0.0085 Molecular Weight 603.51630.4 - 642.5 Docosanes C22 0.0009 0.0081 Mole Fraction 0.0047642.5 - 653.2 Tricosanes C23 0.0008 0.0073 Density (g/cc) 0.9864653.2 - 664.3 Tetracosanes C24 0.0007 0.0070664.3 - 674.9 Pentacosanes C25 0.0007 0.0069674.9 - 685.4 Hexacosanes C26 0.0006 0.0057 Recombination Parameters685.4 - 695.4 Heptacosanes C27 0.0005 0.0055695.4 - 704.9 Octacosanes C28 0.0005 0.0052 Gas-Oil Ratio (cc/cc) 1150.23704.9 - 714.3 Nonacosanes C29 0.0004 0.0047 Dead Oil Density (g/cc) 0.8099Above 714.3 Tricontanes Plus C30+ 0.0047 0.0800 Dead Oil MW (g/mol) 167.97
NAPHTHENES322.0 Cyclopentane C5H10 0.0004 0.0008345.4 Methylcyclopentane C6H12 0.0015 0.0037354.3 Cyclohexane C6H12 0.0012 0.0028374.3 Methylcyclohexane C7H14 0.0024 0.0068
AROMATICS353.2 Benzene C6H6 0.0004 0.0009383.8 Toluene C7H8 0.0009 0.0023
409.3 - 412 Ethylbenzene & p,m-Xylen C8H10 0.0009 0.0027417.5 o-Xylene C8H10 0.0006 0.0019442.0 1, 2, 4-Trimethylbenzene C9H12 0.0011 0.0036
Total 1.0000 1.0000Note: Physical properties are calculated based on GPA 2145-00 physical constants ID.: 9743-3838
Calculated Properties
0.00
0.10
0.20
0.30
0.40
0.50
0.60
0.70
0.80
N2
CO
2H
2S
C1
C2
C3
C4
C5
C6
C7
C8
C9
C10
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
+
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 85 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE H4 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – HIGH GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED OIL
Boiling Point Component Chemical Mole Mass (K) Name Symbol Fraction Fraction
77.4 Nitrogen N2 0.0000 0.0000 Total Sample194.6 Carbon Dioxide CO2 0.0000 0.0000212.8 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 167.97111.5 Methane C1 0.0000 0.0000 Density (g/cc) 0.8173184.3 Ethane C2 0.0000 0.0000231.0 Propane C3 0.0179 0.0047 C6+ Fraction261.5 i-Butane i-C4 0.0081 0.0028272.6 n-Butane n-C4 0.0347 0.0120 Molecular Weight 183.49301.0 i-Pentane i-C5 0.0249 0.0107 Mole Fraction 0.8706309.3 n-Pentane n-C5 0.0438 0.0188 Density (g/cc) 0.8334
309.3 - 342 Hexanes C6 0.0881 0.0452342 - 371.4 Heptanes C7 0.0760 0.0453 C7+ Fraction
371.4 - 398.8 Octanes C8 0.0838 0.0570398.8 - 423.8 Nonanes C9 0.0724 0.0553 Molecular Weight 195.11
423.8 - 447 Decanes C10 0.0558 0.0473 Mole Fraction 0.7783447 - 469.3 Undecanes C11 0.0509 0.0445 Density (g/cc) 0.8427
469.3 - 488.2 Dodecanes C12 0.0400 0.0384488.2 - 508.2 Tridecanes C13 0.0414 0.0431 C12+ Fraction508.2 - 525.4 Tetradecanes C14 0.0331 0.0375525.4 - 543.8 Pentadecanes C15 0.0257 0.0315 Molecular Weight 290.51543.8 - 560.9 Hexadecanes C16 0.0201 0.0266 Mole Fraction 0.3479560.9 - 564.8 Heptadecanes C17 0.0191 0.0269 Density (g/cc) 0.8859564.8 - 590.4 Octadecanes C18 0.0183 0.0274590.4 - 603.2 Nonadecanes C19 0.0169 0.0265 C30+ Fraction603.2 - 617.5 Eicosanes C20 0.0131 0.0214617.5 - 630.4 Heneicosanes C21 0.0114 0.0198 Molecular Weight 603.51630.4 - 642.5 Docosanes C22 0.0103 0.0187 Mole Fraction 0.0517642.5 - 653.2 Tricosanes C23 0.0090 0.0170 Density (g/cc) 0.9864653.2 - 664.3 Tetracosanes C24 0.0083 0.0163664.3 - 674.9 Pentacosanes C25 0.0078 0.0161674.9 - 685.4 Hexacosanes C26 0.0061 0.0131685.4 - 695.4 Heptacosanes C27 0.0057 0.0128695.4 - 704.9 Octacosanes C28 0.0052 0.0120704.9 - 714.3 Nonacosanes C29 0.0045 0.0109Above 714.3 Tricontanes Plus C30+ 0.0517 0.1857
NAPHTHENES322.0 Cyclopentane C5H10 0.0042 0.0018345.4 Methylcyclopentane C6H12 0.0131 0.0065354.3 Cyclohexane C6H12 0.0131 0.0066374.3 Methylcyclohexane C7H14 0.0234 0.0137
AROMATICS353.2 Benzene C6H6 0.0036 0.0017383.8 Toluene C7H8 0.0095 0.0052
409.3 - 412 Ethylbenzene & p,m-Xylen C8H10 0.0100 0.0063417.5 o-Xylene C8H10 0.0068 0.0043442.0 1, 2, 4-Trimethylbenzene C9H12 0.0118 0.0085
Total 1.0000 1.0000Note: Physical properties are calculated based on GPA 2145-00 physical constants GC ID: B160202
Calculated Properties
0.00
0.02
0.04
0.06
0.08
0.10
0.12
0.14
N2
CO
2H
2S
C1
C2
C3
C4
C5
C6
C7
C8
C9
C10
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
+
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 86 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE H5 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – HIGH GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED GAS
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0091 0.0091
Carbon Dioxide CO2 0.0045 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.7595 0.7629
Ethane C2 0.1160 0.1166
Propane C3 0.0660 0.0663 43.116 242.075
i-Butane i-C4 0.0084 0.0085 6.531 36.670
n-Butane n-C4 0.0199 0.0200 14.908 83.702
i-Pentane i-C5 0.0042 0.0042 3.652 20.505
n-Pentane n-C5 0.0056 0.0056 4.772 26.791
Hexanes C6 0.0036 0.0036 3.523 19.780
Heptanes C7 0.0022 0.0022 2.418 13.576
Octanes C8 0.0007 0.0007 0.875 4.914
Nonanes C9 0.0002 0.0002 0.252 1.413
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 80.047 449.426
Propanes Plus C3+ 0.1108 0.1113 80.047 449.426
Butanes Plus C4+ 0.0448 0.0450 36.931 207.351
Pentanes Plus C5+ 0.0165 0.0166 15.492 86.980
Molecular Weight 22.01 kg/kmol 22.01 lb/lb-mol Ppc 662.3 psia 4.57 MPa
Specific Gravity 0.7600 (Air = 1) 0.7600 (Air = 1) Tpc 408.8 R 227.1 K
MW of C7+ 100.05 kg/kmol 100.05 lb/lbmol Ppc* 660.8 psia 4.56 MPa
Density of C7+ 0.7299 g/cc 729.9 kg/m3 Tpc* 407.9 R 226.6 K
Dry 1,304.7 Btu/scf 48.70 MJ/m3 Dry 1,184.8 Btu/scf 44.23 MJ/m3
Wet 1,282.0 Btu/scf 47.85 MJ/m3 Wet 1,164.2 Btu/scf 43.46 MJ/m3
* - Corrected for Acid Gas Content
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC ID: A160279
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Liquid VolumeMole Fraction
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 87 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix I
LOW GOR RECOMBINED FLUID
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 88 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE I1 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – LOW GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
SAMPLE COLLECTION DATA
Project File: CL-79574
Company: ARC RESOURCES LTD.
Pool: MONTNEY
Field: RED CREEK
Well Location: RED A02-4-86-22W6
Fluid Sample: RECOMBINED
Sample Description: RECOMBINED AT 249 M3/M3
Sampling Company: WFT
Name of Sampler: NA
Sampling Date: 13-Nov-15
Sampling Point: SEPARATOR
Sampling Temperature: 77.0 F 25 C
Sampling Pressure: 165.0 psia 1.14 MPa
Reservoir Temperature: 143.6 F 62.0 C
Reservoir Pressure: 3154.0 psia 21.75 MPa
Initial Reservoir Pressure (Pi) N/A psia N/A MPa
Depth of Reported Pi N/A mMD N/A mss
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 89 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE I2 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – LOW GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
SAMPLE VALIDATION DATA
INITIAL RESERVOIR CONDITIONSReservoir Pressure 3154 psia 21.75 MPa
Reservoir Temperature: 143.6 F 62.0 C
SINGLE-STAGE SEPARATOR TEST @ 5,107 psia (35.21 MPa) AND 143.6 F (335.2 K)At Separator Test Conditions
Oil Formation Volume Factor 1.8366 res.bbl/STB 1.8366 res.m3/m
3
Solution Gas-Oil Ratio 1527.89 scf/STB 272.12 m3/m
3
Oil Density 0.5817 g/cm3
581.7 kg/m3
At Tank Conditions
Residual Oil Density 0.8040 g/cm3
804.0 kg/m3
API Gravity 44.50 44.50
SINGLE-STAGE SEPARATOR TEST - MATERIAL BALANCE CHECK
Oil FVF @ 5107 psia (35.21 MPa) (Measured) 1.8366 res.bbl/STB (res.m3/m
3)
Oil FVF @ 5107 psia (35.21 MPa) (Calculated) 1.8335 res.bbl/STB (res.m3/m
3)
Absolute Relative Error 0.1726 (%)
SATURATION PRESSURE @ 143.6 F (335.2 K)Apparent Bubble Point Pressure 3690 psia 25.44 Mpa
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 90 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE I3 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – LOW GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF RECOMBINED FLUID
Boiling Point Component Chemical Mole Mass (K) Name Symbol Fraction Fraction
77.4 Nitrogen N2 0.0064 0.0028 Total Sample194.6 Carbon Dioxide CO2 0.0031 0.0021212.8 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 64.84111.5 Methane C1 0.5129 0.1270184.3 Ethane C2 0.0839 0.0389231.0 Propane C3 0.0611 0.0415 C6+ Fraction261.5 i-Butane i-C4 0.0105 0.0094272.6 n-Butane n-C4 0.0307 0.0275 Molecular Weight 178.38301.0 i-Pentane i-C5 0.0120 0.0134 Mole Fraction 0.2586309.3 n-Pentane n-C5 0.0192 0.0213 Density (g/cc) 0.8300
309.3 - 342 Hexanes C6 0.0300 0.0399342 - 371.4 Heptanes C7 0.0252 0.0389 C7+ Fraction
371.4 - 398.8 Octanes C8 0.0252 0.0444398.8 - 423.8 Nonanes C9 0.0211 0.0418 Molecular Weight 190.09
423.8 - 447 Decanes C10 0.0163 0.0358 Mole Fraction 0.2180447 - 469.3 Undecanes C11 0.0147 0.0334 Density (g/cc) 0.8407
469.3 - 488.2 Dodecanes C12 0.0115 0.0286488.2 - 508.2 Tridecanes C13 0.0116 0.0314 C12+ Fraction508.2 - 525.4 Tetradecanes C14 0.0093 0.0272525.4 - 543.8 Pentadecanes C15 0.0072 0.0228 Molecular Weight 291.99543.8 - 560.9 Hexadecanes C16 0.0055 0.0189 Mole Fraction 0.0971560.9 - 564.8 Heptadecanes C17 0.0051 0.0186 Density (g/cc) 0.8871564.8 - 590.4 Octadecanes C18 0.0050 0.0195590.4 - 603.2 Nonadecanes C19 0.0045 0.0184 C30+ Fraction603.2 - 617.5 Eicosanes C20 0.0036 0.0153617.5 - 630.4 Heneicosanes C21 0.0031 0.0141 Molecular Weight 603.51630.4 - 642.5 Docosanes C22 0.0028 0.0130 Mole Fraction 0.0150642.5 - 653.2 Tricosanes C23 0.0024 0.0120 Density (g/cc) 0.9864653.2 - 664.3 Tetracosanes C24 0.0022 0.0112664.3 - 674.9 Pentacosanes C25 0.0021 0.0113674.9 - 685.4 Hexacosanes C26 0.0017 0.0093 Recombination Parameters685.4 - 695.4 Heptacosanes C27 0.0016 0.0091695.4 - 704.9 Octacosanes C28 0.0014 0.0087 Gas-Oil Ratio (cc/cc) 272.12704.9 - 714.3 Nonacosanes C29 0.0013 0.0079 Dead Oil Density (g/cc) 0.8040Above 714.3 Tricontanes Plus C30+ 0.0150 0.1400 Dead Oil MW (g/mol) 162.03
NAPHTHENES322.0 Cyclopentane C5H10 0.0017 0.0018345.4 Methylcyclopentane C6H12 0.0048 0.0063354.3 Cyclohexane C6H12 0.0044 0.0057374.3 Methylcyclohexane C7H14 0.0076 0.0115
AROMATICS353.2 Benzene C6H6 0.0013 0.0016383.8 Toluene C7H8 0.0027 0.0038
409.3 - 412 Ethylbenzene & p,m-Xylen C8H10 0.0028 0.0046417.5 o-Xylene C8H10 0.0020 0.0033442.0 1, 2, 4-Trimethylbenzene C9H12 0.0033 0.0061
Total 1.0000 1.0000Note: Physical properties are calculated based on GPA 2145-00 physical constants ID.: 9742-3838
Calculated Properties
0.00
0.10
0.20
0.30
0.40
0.50
0.60
N2
CO
2H
2S
C1
C2
C3
C4
C5
C6
C7
C8
C9
C10
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
+
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 91 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE I4 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – LOW GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED OIL
Boiling Point Component Chemical Mole Mass (K) Name Symbol Fraction Fraction
77.4 Nitrogen N2 0.0000 0.0000 Total Sample194.6 Carbon Dioxide CO2 0.0000 0.0000212.8 Hydrogen Sulphide H2S 0.0000 0.0000 Molecular Weight 162.03111.5 Methane C1 0.0000 0.0000 Density (g/cc) 0.8117184.3 Ethane C2 0.0000 0.0000231.0 Propane C3 0.0259 0.0070 C6+ Fraction261.5 i-Butane i-C4 0.0104 0.0037272.6 n-Butane n-C4 0.0423 0.0152 Molecular Weight 180.05301.0 i-Pentane i-C5 0.0274 0.0122 Mole Fraction 0.8465309.3 n-Pentane n-C5 0.0475 0.0211 Density (g/cc) 0.8314
309.3 - 342 Hexanes C6 0.0900 0.0479342 - 371.4 Heptanes C7 0.0796 0.0492 C7+ Fraction
371.4 - 398.8 Octanes C8 0.0830 0.0585398.8 - 423.8 Nonanes C9 0.0698 0.0552 Molecular Weight 192.12
423.8 - 447 Decanes C10 0.0541 0.0475 Mole Fraction 0.7509447 - 469.3 Undecanes C11 0.0488 0.0443 Density (g/cc) 0.8413
469.3 - 488.2 Dodecanes C12 0.0381 0.0379488.2 - 508.2 Tridecanes C13 0.0386 0.0417 C12+ Fraction508.2 - 525.4 Tetradecanes C14 0.0308 0.0361525.4 - 543.8 Pentadecanes C15 0.0238 0.0302 Molecular Weight 291.99543.8 - 560.9 Hexadecanes C16 0.0183 0.0251 Mole Fraction 0.3218560.9 - 564.8 Heptadecanes C17 0.0169 0.0247 Density (g/cc) 0.8871564.8 - 590.4 Octadecanes C18 0.0167 0.0259590.4 - 603.2 Nonadecanes C19 0.0150 0.0244 C30+ Fraction603.2 - 617.5 Eicosanes C20 0.0119 0.0202617.5 - 630.4 Heneicosanes C21 0.0104 0.0187 Molecular Weight 603.51630.4 - 642.5 Docosanes C22 0.0091 0.0172 Mole Fraction 0.0499642.5 - 653.2 Tricosanes C23 0.0081 0.0159 Density (g/cc) 0.9864653.2 - 664.3 Tetracosanes C24 0.0073 0.0148664.3 - 674.9 Pentacosanes C25 0.0070 0.0150674.9 - 685.4 Hexacosanes C26 0.0056 0.0123685.4 - 695.4 Heptacosanes C27 0.0052 0.0120695.4 - 704.9 Octacosanes C28 0.0048 0.0115704.9 - 714.3 Nonacosanes C29 0.0042 0.0104Above 714.3 Tricontanes Plus C30+ 0.0499 0.1857
NAPHTHENES322.0 Cyclopentane C5H10 0.0055 0.0024345.4 Methylcyclopentane C6H12 0.0150 0.0078354.3 Cyclohexane C6H12 0.0146 0.0076374.3 Methylcyclohexane C7H14 0.0245 0.0149
AROMATICS353.2 Benzene C6H6 0.0041 0.0020383.8 Toluene C7H8 0.0088 0.0050
409.3 - 412 Ethylbenzene & p,m-Xylen C8H10 0.0092 0.0060417.5 o-Xylene C8H10 0.0066 0.0043442.0 1, 2, 4-Trimethylbenzene C9H12 0.0110 0.0081
Total 1.0000 1.0000Note: Physical properties are calculated based on GPA 2145-00 physical constants GC ID: B160201
Calculated Properties
0.00
0.02
0.04
0.06
0.08
0.10
0.12
0.14
N2
CO
2H
2S
C1
C2
C3
C4
C5
C6
C7
C8
C9
C10
C11
C12
C13
C14
C15
C16
C17
C18
C19
C20
C21
C22
C23
C24
C25
C26
C27
C28
C29
C30
+
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 92 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
TABLE I5 ARC RESOURCES LTD.
WELL A02-4-86-22W6 – LOW GOR RECOMBINED SAMPLE RESERVOIR FLUID STUDY
COMPOSITIONAL ANALYSIS OF FLASHED GAS
Component Chemical
Name Symbol As Analyzed Acid Gas Free STB/MMscf mL/m3
Nitrogen N2 0.0091 0.0092
Carbon Dioxide CO2 0.0044 0.0000
Hydrogen Sulphide H2S 0.0000 0.0000
Methane C1 0.7344 0.7377
Ethane C2 0.1201 0.1206
Propane C3 0.0763 0.0766 49.813 279.674
i-Butane i-C4 0.0105 0.0106 8.185 45.953
n-Butane n-C4 0.0257 0.0258 19.226 107.945
i-Pentane i-C5 0.0054 0.0054 4.679 26.272
n-Pentane n-C5 0.0070 0.0070 5.995 33.661
Hexanes C6 0.0041 0.0041 3.995 22.430
Heptanes C7 0.0022 0.0022 2.428 13.632
Octanes C8 0.0006 0.0006 0.729 4.095
Nonanes C9 0.0001 0.0001 0.190 1.065
Decanes C10 0.0000 0.0000 0.000 0.000
Undecane C11 0.0000 0.0000 0.000 0.000
Dodecanes Plus C12+ 0.0000 0.0000 0.000 0.000
Total 1.0000 1.0000 95.240 534.726
Propanes Plus C3+ 0.1319 0.1325 95.240 534.726
Butanes Plus C4+ 0.0557 0.0559 45.427 255.052
Pentanes Plus C5+ 0.0194 0.0195 18.017 101.155
Molecular Weight 22.85 kg/kmol 22.85 lb/lb-mol Ppc 660.4 psia 4.55 MPa
Specific Gravity 0.7890 (Air = 1) 0.7890 (Air = 1) Tpc 417.7 R 232.0 K
MW of C7+ 99.43 kg/kmol 99.43 lb/lbmol Ppc* 659.0 psia 4.54 MPa
Density of C7+ 0.7287 g/cc 728.7 kg/m3 Tpc* 416.8 R 231.6 K
Dry 1,350.0 Btu/scf 50.39 MJ/m3 Dry 1,227.0 Btu/scf 45.80 MJ/m3
Wet 1,326.5 Btu/scf 49.51 MJ/m3 Wet 1,205.7 Btu/scf 45.00 MJ/m3
* - Corrected for Acid Gas Content
Standard Conditions: 60 F (288.7 K) @ 14.696 psia (0.101325 MPa) GC ID: A160278
Calculated Gas Properties @ Standard Conditions Calculated Pseudocritical Properties
Calculated Gross Heating Value @ Standard Conditions Calculated Net Heating Value @ Standard Conditions
Liquid VolumeMole Fraction
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 93 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
Appendix J
EXCESS GAS CORRECTION
ARC Resources Ltd.
Formation: Montney, Field: Red Creek 94 Weatherford Labs File #: CL-79574 Location: A02-4-86-22W6
ARC RESOURCES LTD. WELL A02-4-86-22W6 – LOW GOR RECOMBINED SAMPLE
RESERVOIR FLUID STUDY EXCESS GAS CORRECTION
Production GOR, m3/m3 277.0 Corrected GOR, m3/m3 199.2Saturation Pressure,psia 3690 Corrected Saturation Pressure, psia 3154Reservoir pressure, psia 3154
Reservoir temperature, degC 62
Components Separator Oil Separator Gas Gas Cap (Egas) Corrected Solution Gas Target Reservoir Oil N2 0.0006 0.0066 0.0129 0.0072 0.0045CO2 0.0004 0.0087 0.0061 0.0053 0.0033H2S 0.0000 0.0000 0.0000 0.0000 0.0000C1 0.0271 0.7953 0.8050 0.7729 0.4677C2 0.0319 0.1115 0.0882 0.1243 0.0865C3 0.0655 0.0516 0.0431 0.0639 0.0646i‐C4 0.0209 0.0084 0.0064 0.0070 0.0127n‐C4 0.0713 0.0113 0.0166 0.0146 0.0378i‐C5 0.0359 0.0025 0.0054 0.0017 0.0157n‐C5 0.0596 0.0021 0.0080 0.0017 0.0254C6+ 0.6868 0.0021 0.0084 0.0013 0.2818Total 1.0000 1.0000 1.0000 1.0000 1.0000
CL79574 ARC A02‐04‐086‐22W6CORRECTED SOLUTION GAS AND GOR