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Originated: Delivered to:9-Dec-24
Alaska Oil & Gas Conservation Commiss 09Dec24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
1R-03A 50-029-21406-01-00 200-021 Kuparuk River WL IPROF FINAL FIELD 8-Nov-24
3S-718 50-103-20884-00-00 224-034 Kuparuk River WL TTiX PPROF FINAL FIELD 20-Nov-24
2B-11 50-029-21089-00-00 184-035 Kuparuk River WL IPROF FINAL FIELD 22-Nov-24
3S-617 50-103-20864-00-00 223-085 Kuparuk River WL IPROF FINAL FIELD 30-Nov-24
3M-22 50-029-21740-00-00 187-067 Kuparuk River WL LDL FINAL FIELD 2-Dec-24
1J-156 50-029-23311-00-00 206-067 Kuparuk River WL IPROF FINAL FIELD 2-Dec-24
2H-11 50-103-20052-00-00 185-261 Kuparuk River WL IPROF FINAL FIELD 4-Dec-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T39843
T39844
T39845
T39846
T39847
T39848
T39849
3S-617 50-103-20864-00-00 223-085 Kuparuk River WL IPROF FINAL FIELD 30-Nov-24
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.12.10 08:20:31
-09'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, July 22, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
3S-617
KUPARUK RIV UNIT 3S-617
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/22/2024
3S-617
50-103-20864-00-00
223-085-0
W
SPT
5027
2230850 1500
50 50 50 50
516 613 606 602
INITAL P
Sully Sullivan
6/3/2024
Initial MIT-IA on new well
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 3S-617
Inspection Date:
Tubing
OA
Packer Depth
760 1805 1770 1760IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS240604110054
BBL Pumped:1.3 BBL Returned:1.2
Monday, July 22, 2024 Page 1 of 1
9
9
99
99
9 À
9 9
9 9
9 9 9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2024.07.22 15:15:24 -08'00'
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________
ConocoPhillips Alaska, Inc. Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number):8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 21,276 feet feet
true vertical 5,162 feet feet
Effective Depth measured 21,276 feet 8020/8331 feet
true vertical 5,162 feet 5027/5130 feet
Perforation depth Measured depth N/A feet
True Vertical depth N/A feet
Tubing (size, grade, measured and true vertical depth)4.5" 12.6# L-80 8,157' MD 5,075' TVD
HAL TNT 8,020' MD 5,027' TVD
Packers and SSSV (type, measured and true vertical depth)SLZXP LTP 8,331' MD 5,130' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:Torok Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date:18-Mar-24 Contact Name:Baskoro Tejo
Contact Email:Baskoro.tejo@conocophillips.com
Authorized Title:Completion Engineer Contact Phone:907-265-6462
324-078
Sr Pet Eng:
9210
Sr Pet Geo:Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
TBD
Gas-Mcf
MD
8,904' MD - 21,038' MD
Size
97
N/A
7-5/8"
11590
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-085
50-103-20864-00-00
P.O. Box 100360 Anchorage, AK 99510-03603. Address:
Job logs attached
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL380107 / ADL380106 / ADL025528 / ADL393883
Kuparuk Field/ Torok Oil Pool
KRU 3S-617
Plugs
Junk measured
4.948 MMlbs of 16/20 Wanli Ceramic Proppant, 111,000 lbs of 100 Mesh, and 3579 psi treating pressure/ 4500 psi BHG pressure
Length
97
2778
97Conductor
Surface
Intermediate
20"
10-3/4"
measured
TVD
Intermediate
Liner
7489
842
13092
Casing
Structural
4796
5130
4-1/2"
7489
8331
21240 5157.6
4790
7850
5210
6890
10860
2778 2551
Burst Collapse
2470
p
k
ft
t
Fra
O
s O
223
6. A
G
L
PG
,
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 8:23 am, Mar 18, 2024
RBDMS JSB 032824
DSR-3/21/24
CDW 03/31/2024
Sales Order#
Prepared By:
William Martin
James Campbell
Nannook Crew
0909172317
Intervals 1-24
Notice:Althoughtheinformationcontainedinthisreportisbasedonsoundengineeringpractices,thecopyright
owner(s)does(do)notacceptanyresponsibilitywhatsoever,innegligenceorotherwise,foranylossordamage
arisingfromthepossessionoruseofthereportwhetherintermsofcorrectnessorotherwise.Theapplication,
therefore,bytheuserofthisreportoranypartthereof,issolelyattheuser’sownrisk.
3S-617
Conoco Phillips
Harrison Bay County, AK
Post Job Report
Stimulation Treatment
API: 50-103-20864
Prepared for: Manabu Nozaki
March 14, 2024
Torok Formation
30# Hybor G
Table of Contents
Section Page(s)
ExecutiveSummary
ActualDesign
WellboreInformation
IntervalSummary
FluidSystemͲProppantSummary
Interval1Plots
Interval2Plots
Interval3Plots
Interval4Plots
Interval5Plots
Interval6Plots
Interval7Plots
Interval8Plots
Interval9Plots
Interval10Plots
Interval11Plots
Interval12Plots
Interval13Plots
Interval14Plots
Interval15Plots
Interval16Plots
Interval17Plots
Interval18Plots
Interval19Plots
Interval20Plots
Interval21Plots
Interval22Plots
Interval23Plots
Interval24Plots
Appendix
WellSummary
ChemicalSummary
PlannedDesign
WaterStraps2Ͳ26
WaterStraps2Ͳ27
WaterStraps2Ͳ29
WaterStraps3Ͳ1
WaterStraps3Ͳ2
WaterStraps3Ͳ7
WaterStraps3Ͳ9
WaterStraps3Ͳ12
WaterStraps3Ͳ13
WaterAnalysis2Ͳ26
WaterAnalysis2Ͳ27
WaterAnalysis2Ͳ29
WaterAnalysis3Ͳ1
WaterAnalysis3Ͳ2
WaterAnalysis3Ͳ6
WaterAnalysis3Ͳ7
WaterAnalysis3Ͳ12
WaterAnalysis3Ͳ13
RealͲTimeQC
EventLog2Ͳ26
EventLog2Ͳ27
EventLog2Ͳ29
EventLog3Ͳ01
EventLog3Ͳ02
EventLog3Ͳ07
EventLog3Ͳ09
EventLog3Ͳ12
EventLog3Ͳ13
PrejobBreakTest
Fann15MinTestInterval15
Fann15MinTestInterval17
Fann15MinTestInterval18
Fann15MinTestInterval19
Fann15MinTestInterval22
Fann15MinTestInterval23
Fann15MinTestInterval24
SandSieveAnalysis 243Ͳ244
238
239
240
241
242
233
234
235
236
237
228
229
230
231
232
223
224
225
226
227
218
219
220
221
222
213
214
215
216
217
208
209
210
211
212
195
196
197
198Ͳ206
207
175Ͳ178
179Ͳ182
183Ͳ186
187Ͳ190
191Ͳ194
141Ͳ152
153Ͳ156
157Ͳ160
161Ͳ164
165Ͳ174
137Ͳ140
3
4Ͳ9
10
56Ͳ66
67Ͳ70
71Ͳ78
11Ͳ34
35
36Ͳ51
52Ͳ55
79Ͳ85
86Ͳ93
122Ͳ136
94Ͳ99
100Ͳ109
110Ͳ113
114Ͳ117
118Ͳ121
ConocoPhillipsͲ3SͲ617 TOC 2
2,171,786 gallons of 30# Hybor G
133,109 gallons of 30# Linear
63,885 gallons of Seawater
22,220 gallons of Freeze Protect
4,829,400 pounds of Wanli 16/20 Ceramic
100,000 pounds of 100M
2,261,907 gallons of 30# Hybor G
132,169 gallons of 30# Linear
71,727 gallons of Seawater
37,590 gallons of Freeze Protect
4,948,809 pounds of Wanli 16/20 Ceramic
111,000 pounds of 100M
Thank you,
Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may
have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions
provider for future projects.
EngineeringExecutiveSummary
On February 26, 2024 a stimulation treatment was performed in the Torok formation on the 3S-617 well in Harrison Bay
County, AK. The 3S-617 was a 24 stage Horizontal Sleeve Design. The proposed treatment consisted of:
The actual treatment fully completed 22 of 24 stages. 0 stages were skipped, 0 stage screened out and 2 stages were cut short
of design. The actual treatment consisted of:
A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided
to summarize events and changes to the proposed treatment:
While pumping interval 06, the blender screen froze and could not be electronically controlled, the well was flushed and the
decision was made to cut interval 06 short, 39.4% of proppant was placed. While pumping interval 08, in the 5.5 ppg proppant
stage there was a leak on the ground iron due to a washout. A hard shut down was called to replace the washed iron and then
the well was flushed. Interval 08 was cut short after pumping 55.6% of proppant. While pumping interval 15, in the 2.0 ppg
proppant stage there was a leak on the low pressure side of the manifold, pumping was halted to swap hoses to the other side of
the manifold so the well could be flushed. The next pumping day, interval 15 was resumed from the beginning increasing the
designed proppant to 207,000 lb from 200,000 of 16/20.
Of the 37,590 gal of Freeze Protect used, 23,730 gal was used for priming up and pressure testing.
Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid
volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are
performed before each job in order to optimize the performance of the treatment fluids.
MO-67 was adjusted on the fly so that the XL pH was reading around 9.0 which was typically around a set point of 0.45 gal/Mgal
with raw MO-67. Carrying over with the testing from 3S-624, at some points when water temperature was low, CL-28 was
brought up to a 2.2 gal/Mgal setpoint.The QAQC computer crashed and the Real Time QAQC, and 15 min Fann readings were
lost from interval 01-11.
William Martin
Senior Technical Professional
ConocoPhillipsͲ3SͲ617 ExecutiveSummary 3
CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.54 LAT70.39411269
LEASE 3SͲ617 SALESORDE BHST(°F)140 LONG Ͳ150.1934482
FORMATION Torok DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure*
Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 CatͲ3WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer Catalyst
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)
1Ͳ1 ShutͲIn ShutͲIn Ͳ
1Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 2,100 50 50
1Ͳ3 ShutͲIn ShutͲIn Ͳ
1Ͳ4 Seawater ArsenalSleeveShift 5.0 1,260 627 15 15 0.15
1Ͳ5 Seawater DFIT 10.0 1,680 1,712 41 41 0.15
1Ͳ6 ShutͲIn ShutͲIn Ͳ
1Ͳ7 30#HyborG EstablishStableFluid15.0 8,400 13,178 314 314 2.00 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ8 30#HyborG Pad 37.0 39,520 51,648 1,230 1,230 2.00 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ9 Seawater Flush 37.0 13,886 14,774 352 352 1.00 2.00 0.25 0.15
1Ͳ10 ShutͲIn ShutͲIn Ͳ
1Ͳ11 30#HyborG EstablishStableFluid15.0 8,400 8,576 204 204 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ12 30#HyborG Pad 37.0 39,520 10,500 250 250 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ13 Seawater Flush 37.0 13,886 14,519 346 346 1.00 2.00 0.25 0.15
1Ͳ14 ShutͲIn ShutͲIn Ͳ
1Ͳ15 FreezeProtect PrimeUpPressureTest 5.0 1,000 1,050 25 25
1Ͳ16 ShutͲIn ShutͲIn Ͳ
1Ͳ17 FreezeProtect PrimeUpPressureTest 5.0 1,000 Ͳ
1Ͳ18 ShutͲIn ShutͲIn Ͳ
1Ͳ19 30#HyborG EstablishStableFluid15.0 8,400 11,052 263 263 2.00 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ20 30#HyborG Pad 37.0 39,520 39,582 942 942 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ21 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,067 359 363 4,000 4,031 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ22 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 18,000 18,020 429 446 18,000 16,292 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ23 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 27,000 27,073 645 702 54,000 53,692 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ24 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 27,000 27,037 644 729 81,000 80,363 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ25 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 18,000 18,022 429 507 72,000 72,970 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ26 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 15,000 16,314 388 466 75,000 73,408 2.20 1.00 0.39 0.50 30.00 2.00 0.25 0.15
1Ͳ27 30#HyborGSpacerandBallDrop 37.0 1,260 2,164 52 52 2.20 1.00 0.39 0.50 30.00 2.00 0.25 0.15
1Ͳ28 30#HyborG Pad 37.0 37,000 12,652 301 301 2.20 1.00 0.39 30.00 2.00 0.25 0.15
1Ͳ29 30#Linear SpacerandBallDrop 37.0 1,260 3,584 85 85 2.20 1.00 30.00 2.00 0.25 0.15
2Ͳ1 30#Linear DisplaceBalltoSeat 15.0 13,445 12,174 290 290 2.20 1.00 0.50 30.00 2.00 0.25 0.15
2Ͳ2 30#HyborG EstablishStableFluid15.0 8,400 5,836 139 139 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ3 30#HyborG Pad 37.0 37,000 38,332 913 913 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ4 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 18,163 432 437 4,000 3,898 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 18,000 18,017 429 445 18,000 15,058 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 22,500 22,678 540 586 45,000 43,073 2.00 1.00 0.39 0.50 30.00 2.00 0.25 0.15
2Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 25,000 25,361 604 685 75,000 76,064 2.00 1.00 0.39 0.50 30.00 2.00 0.25 0.15
2Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 11,250 11,241 268 317 45,000 46,657 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 9,300 9,414 224 268 41,850 41,172 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 7,770 7,768 185 224 38,850 36,896 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 6,600 7,922 189 227 36,300 35,985 2.00 1.00 0.39 30.00 2.00 0.25 0.15
2Ͳ12 30#HyborGSpacerandBallDrop 37.0 1,260 1,932 46 46 2.00 1.00 0.39 30.00 2.00 0.25 0.15
3Ͳ1 30#HyborG MinifracͲTreatment 37.0 18,900 19,225 458 458 2.00 1.00 0.39 30.00 2.00 0.25 0.15
3Ͳ2 30#Linear MinifracͲFlush37.0 13,270 13,280 316 316 1.00 30.00 2.00 0.25 0.15
3Ͳ3 ShutͲIn ShutͲIn Ͳ
3Ͳ4 FreezeProtect FreezeProtect 5.0 1,050 1,260 30 30
3Ͳ5 ShutͲIn ShutͲIn Ͳ
3Ͳ6 ShutͲIn ShutͲIn Ͳ
3Ͳ7 FreezeProtect PrimeUpPressureTest 5.0 1,000 2,100 50 50
3Ͳ8 ShutͲIn ShutͲIn Ͳ
3Ͳ9 30#Linear SpacerandBallDrop 15.0 1,260 3,048 73 73 1.00 30.00 2.00 0.25 0.15
3Ͳ10 30#HyborG EstablishStableFluid15.0 8,400 21,935 522 522 2.00 1.00 0.80 30.00 2.00 0.25 0.15
3Ͳ11 30#HyborG Pad 37.0 36,000 36,131 860 860 2.00 1.00 0.80 30.00 2.00 0.25 0.15
3Ͳ12 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,953 380 383 4,000 2,578 2.00 1.00 0.80 30.00 2.00 0.25 0.15
3Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 18,000 17,988 428 444 18,000 14,557 2.00 1.00 0.39 30.00 2.00 0.25 0.15
3Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 22,500 22,486 535 582 45,000 43,521 2.00 1.00 0.39 30.00 2.00 0.25 0.15
3Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 21,000 20,970 499 564 63,000 61,158 2.00 1.00 0.39 30.00 2.00 0.25 0.15
3Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 15,000 14,965 356 423 60,000 62,763 2.00 1.00 0.39 30.00 2.00 0.25 0.15
3Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 12,000 12,038 287 349 60,000 58,549 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
3Ͳ18 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 9,000 11,752 280 346 54,000 62,137 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
3Ͳ19 30#HyborGSpacerandBallDrop 37.0 13,270 1,428 34 34 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
4Ͳ1 30#HyborG Pad 37.0 28,225 28,185 671 671 2.00 1.00 0.39 30.00 2.00 0.25 0.15
4Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,946 380 382 4,000 2,576 2.00 1.00 0.39 30.00 2.00 0.25 0.15
4Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,750 12,745 303 314 12,750 9,658 2.00 1.00 0.39 30.00 2.00 0.25 0.15
4Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 12,750 12,722 303 330 25,500 25,943 2.00 1.00 0.39 30.00 2.00 0.25 0.15
4Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 12,000 11,974 285 326 36,000 38,530 2.00 1.00 0.39 30.00 2.00 0.25 0.15
4Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 13,500 13,450 320 378 54,000 54,346 2.00 1.00 0.39 30.00 2.00 0.25 0.15
4Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 12,000 11,980 285 351 60,000 62,366 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
4Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 10,500 10,458 249 318 63,000 65,317 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
4Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 7,500 9,309 222 272 48,750 47,287 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
4Ͳ10 30#Linear Flush 37.0 12,965 13,131 313 313 1.00 0.50 30.00 2.00 1.50 0.15
4Ͳ11 ShutͲIn ShutͲIn Ͳ
4Ͳ12 FreezeProtect FreezeProtect 5.0 1,500 840 20 20
4Ͳ13 ShutͲIn ShutͲIn ͲInterval 1Torok@ 21034.42 - 21038.28 ft 138 °FInterval 2Torok@ 20548.49 - 20552.35 ft 138 °FInterval 3Torok@ 20070.59 - 20074.45 ft 138 °FInterval 4Torok@ 19593.73 - 19597.59 ft 138 °FLiquidAdditives DryAdditives
50Ͳ103Ͳ20864
0909172317
ConocoPhillipsͲ3SͲ617 ActualDesign 4
CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.54 LAT70.39411269
LEASE 3SͲ617 SALESORDE BHST(°F)140 LONG Ͳ150.1934482
FORMATION Torok DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure*
Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 CatͲ3WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer Catalyst
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)
LiquidAdditives DryAdditives
50Ͳ103Ͳ20864
0909172317
5Ͳ1 ShutͲIn ShutͲIn Ͳ
5Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 2,100 50 50
5Ͳ3 ShutͲIn ShutͲIn Ͳ
5Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 2,193 52 52 1.00 30.00 2.00 0.25 0.15
5Ͳ5 30#HyborG EstablishStableFluid15.0 8,400 7,188 171 171 2.00 1.00 0.39 30.00 2.00 0.25 0.15
5Ͳ6 30#HyborG Pad 37.0 19,800 19,826 472 472 2.00 1.00 0.39 30.00 2.00 0.25 0.15
5Ͳ7 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 18,035 429 435 4,000 5,438 2.00 1.00 0.39 30.00 2.00 0.25 0.15
5Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 3,000 2,996 71 74 3,000 2,103 2.00 1.00 0.42 30.00 2.00 0.25 0.15
5Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 3,750 3,708 88 95 7,500 6,057 2.00 1.00 0.42 30.00 2.00 0.25 0.15
5Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 6,000 5,959 142 160 18,000 17,474 2.00 1.00 0.42 30.00 2.00 0.25 0.15
5Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 7,275 7,258 173 201 29,100 26,354 2.00 1.00 0.42 30.00 2.00 0.25 0.15
5Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 7,500 7,485 178 213 33,750 32,571 2.00 1.00 0.42 30.00 2.00 0.25 0.15
5Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 8,115 8,176 195 236 40,575 39,261 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
5Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 8,250 8,926 213 262 45,375 46,601 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
5Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 8,700 8,788 209 263 52,200 50,382 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
5Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 6,000 6,016 143 185 39,000 39,685 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
5Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 4,500 7,734 184 230 31,500 43,422 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
5Ͳ18 30#HyborGSpacerandBallDrop 37.0 1,260 1,439 34 34 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
6Ͳ1 30#HyborG MinifracͲTreatment 37.0 18,900 18,855 449 449 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
6Ͳ2 30#Linear MinifracͲFlush37.0 12,409 12,449 296 296 1.00 0.50 30.00 2.00 1.50 0.15
6Ͳ3 ShutͲIn ShutͲIn Ͳ
6Ͳ4 30#Linear StepRateTest 15.0 2,940 2,378 57 57 1.00 30.00 2.00 0.25 0.15
6Ͳ5 30#HyborG EstablishStableFluid15.0 8,400 7,548 180 180 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ6 30#HyborG Pad 37.0 19,800 19,737 470 470 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ7 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,175 385 390 4,000 4,226 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 3,000 3,025 72 74 3,000 1,874 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 3,750 3,747 89 96 7,500 6,268 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 6,000 5,203 124 143 18,000 17,908 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 7,275 7,248 173 203 29,100 28,313 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 15,000 14,918 355 420 67,500 61,276 2.00 1.00 0.65 30.00 2.00 0.25 0.15
6Ͳ13 30#Linear Flush 37.0 12,409 17,223 410 410 1.00 30.00 2.00 0.15
6Ͳ14 Seawater Displacement 15.0 12,409 12,755 304 304 0.15
6Ͳ15 ShutͲIn ShutͲIn Ͳ
6Ͳ16 FreezeProtect FreezeProtect 5.0 1,500 1,680 40 40
6Ͳ17 ShutͲIn ShutͲIn Ͳ
7Ͳ1 ShutͲIn ShutͲIn Ͳ
7Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 1,260 30 30
7Ͳ3 ShutͲIn ShutͲIn Ͳ
7Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 2,602 62 62 1.00 30.00 2.00 0.25 0.15
7Ͳ5 30#HyborG EstablishStableFluid15.0 8,400 7,931 189 189 2.00 1.00 0.65 30.00 2.00 0.25 0.15
7Ͳ6 30#HyborG Pad 37.0 19,800 19,837 472 472 2.00 1.00 0.65 30.00 2.00 0.25 0.15
7Ͳ7 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,978 380 385 4,000 3,899 2.00 1.00 0.65 30.00 2.00 0.25 0.15
7Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 3,000 3,022 72 74 3,000 1,906 2.00 1.00 0.65 30.00 2.00 0.25 0.15
7Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 3,750 3,740 89 95 7,500 5,653 2.00 1.00 0.65 30.00 2.00 0.25 0.15
7Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 6,000 5,987 143 161 18,000 17,113 2.00 1.00 0.65 30.00 2.00 0.25 0.15
7Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 7,275 7,201 171 201 29,100 27,579 2.00 1.00 0.65 30.00 2.00 0.25 0.15
7Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 7,500 7,460 178 212 33,750 32,324 2.00 1.00 0.50 30.00 2.00 0.25 0.15
7Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 8,115 8,113 193 233 40,575 37,830 2.00 1.00 0.50 30.00 2.00 0.25 0.15
7Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 8,250 8,298 198 244 45,375 44,007 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
7Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 8,700 8,748 208 263 52,200 51,159 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
7Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 6,000 6,041 144 186 39,000 39,816 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
7Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 4,500 8,237 196 244 31,500 45,054 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
7Ͳ18 30#HyborGSpacerandBallDrop 37.0 1,260 1,372 33 33 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
8Ͳ1 30#HyborG Pad 37.0 19,800 19,921 474 474 2.00 1.00 0.50 30.00 2.00 0.25 0.15
8Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,925 379 384 4,000 4,214 2.00 1.00 0.50 30.00 2.00 0.25 0.15
8Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 3,000 3,034 72 74 3,000 1,995 2.00 1.00 0.50 30.00 2.00 0.25 0.15
8Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 3,750 3,772 90 96 7,500 6,246 2.00 1.00 0.50 30.00 2.00 0.25 0.15
8Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 6,000 6,091 145 164 18,000 17,808 2.00 1.00 0.50 30.00 2.00 0.25 0.15
8Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 7,275 7,287 174 204 29,100 28,392 2.00 1.00 0.47 30.00 2.00 0.25 0.15
8Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 7,500 7,499 179 213 33,750 32,861 2.00 1.00 0.47 30.00 2.00 0.25 0.15
8Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 8,115 8,094 193 234 40,575 39,221 2.00 1.00 0.47 30.00 2.00 0.25 0.15
8Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 8,250 7,023 167 207 45,375 37,778 2.00 1.00 0.47 0.50 30.00 2.00 1.50 0.15
8Ͳ10 30#Linear Flush 37.0 11,902 12,234 291 291 1.00 30.00 2.00 0.25 0.15
8Ͳ11 ShutͲIn ShutͲIn Ͳ
8Ͳ12 FreezeProtect FreezeProtect 5.0 1,500 1,050 25 25
8Ͳ13 ShutͲIn ShutͲIn Ͳ
9Ͳ1 ShutͲIn ShutͲIn Ͳ
9Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 4,620 110 110
9Ͳ3 ShutͲIn ShutͲIn Ͳ
9Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 141 3 3 1.00 30.00 2.00 0.25 0.15
9Ͳ5 30#HyborG EstablishStableFluid15.0 8,400 12,895 307 307 2.00 1.00 0.45 30.00 2.00 0.25 0.15
9Ͳ6 30#HyborG Pad 37.0 7,810 7,800 186 186 2.00 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ7 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,974 380 385 4,000 4,123 2.00 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,986 47 49 2,000 1,375 2.00 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,492 59 63 5,000 3,757 2.00 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,021 96 107 12,000 10,855 2.00 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,847 115 136 19,400 19,404 2.20 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,060 120 144 22,500 22,304 2.20 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,430 129 157 27,050 25,687 2.20 1.00 0.40 30.00 2.00 0.25 0.15
9Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,485 131 162 30,250 29,181 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
9Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,808 138 175 34,800 34,621 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
9Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,014 96 121 26,000 23,838 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
9Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 6,345 151 184 21,000 31,267 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
9Ͳ18 30#HyborGSpacerandBallDrop 37.0 1,260 1,763 42 42 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15Interval 6Torok@ 18723.67 - 18727.53 ft 138 °FInterval 7Torok@ 18327.39 - 18331.25 ft 138.1 °FInterval 8Torok@ 17930.24 - 17934.1 ft 138 °FInterval 9Torok@ 17492.94 - 17494.99 ft 138 °FInterval 5Torok@ 19076.7 - 19080.56 ft 138 °FConocoPhillipsͲ3SͲ617 ActualDesign 5
CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.54 LAT70.39411269
LEASE 3SͲ617 SALESORDE BHST(°F)140 LONG Ͳ150.1934482
FORMATION Torok DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure*
Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 CatͲ3WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer Catalyst
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)
LiquidAdditives DryAdditives
50Ͳ103Ͳ20864
0909172317
10Ͳ1 30#HyborG Pad 37.0 7,810 7,870 187 187 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,007 381 385 4,000 3,266 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,029 48 49 2,000 971 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,527 60 64 5,000 3,996 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,004 95 107 12,000 11,145 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,862 116 136 19,400 19,409 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,997 119 142 22,500 22,146 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,508 131 160 27,050 27,054 2.20 1.00 0.40 30.00 2.00 0.25 0.15
10Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,619 134 169 30,250 32,901 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
10Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,802 138 175 34,800 34,709 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
10Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,032 96 122 26,000 24,668 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
10Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,906 141 172 21,000 29,549 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
10Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 2,303 55 55 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
11Ͳ1 30#HyborG Pad 37.0 7,810 7,851 187 187 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,041 382 387 4,000 4,467 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,959 47 48 2,000 1,330 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 3,045 73 77 5,000 4,686 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,981 95 106 12,000 10,480 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,832 115 134 19,400 17,789 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,035 120 144 22,500 22,412 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,424 129 158 27,050 26,750 2.20 1.00 0.40 30.00 2.00 0.25 0.15
11Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,491 131 162 30,250 29,352 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
11Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,779 138 173 34,800 32,898 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
11Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,992 95 120 26,000 23,909 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
11Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,661 135 166 21,000 29,133 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
11Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,260 2,024 48 48 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
12Ͳ1 30#HyborG Pad 37.0 7,810 8,337 199 199 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,010 381 386 4,000 4,635 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 3,138 75 77 2,000 2,082 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,475 59 63 5,000 3,616 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,016 96 106 12,000 10,130 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,873 116 136 19,400 18,478 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,983 119 143 22,500 22,615 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,382 128 157 27,050 27,044 2.20 1.00 0.40 30.00 2.00 0.25 0.15
12Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,476 130 162 30,250 30,075 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
12Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,832 139 172 34,800 31,209 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
12Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,090 97 123 26,000 24,487 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
12Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,992 143 174 21,000 29,166 2.20 1.00 0.40 0.50 30.00 2.00 1.50 0.15
12Ͳ13 30#Linear Flush 37.0 11,061 11,284 269 269 1.00 0.50 30.00 2.00 1.50 0.15
12Ͳ14 FreezeProtect FreezeProtect 5.0 1,260 2,730 65 65
12Ͳ15 ShutͲIn ShutͲIn Ͳ
13Ͳ1 ShutͲIn ShutͲIn Ͳ
13Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 4,200 100 100
13Ͳ3 ShutͲIn ShutͲIn Ͳ
13Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 230 5 5 1.00 30.00 2.00 0.25 0.15
13Ͳ5 30#HyborG EstablishStableFluid15.0 8,400 9,335 222 222 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ6 Seawater Displacement 15.0 10,703 10,779 257 257 0.15
13Ͳ7 ShutͲIn ShutͲIn Ͳ
13Ͳ8 ShutͲIn ShutͲIn Ͳ
13Ͳ9 FreezeProtect PrimeUpPressureTest 5.0 1,000 3,150 75 75
13Ͳ10 ShutͲIn ShutͲIn Ͳ
13Ͳ11 30#Linear SpacerandBallDrop 15.0 1,260 184 4 4 1.00 30.00 2.00 0.25 0.15
13Ͳ12 30#HyborG EstablishStableFluid15.0 8,400 9,776 233 233 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ13 30#HyborG Pad 37.0 7,810 7,765 185 185 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ14 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,979 380 384 4,000 3,484 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,032 48 50 2,000 1,062 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,542 61 64 5,000 3,728 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,988 95 107 12,000 11,314 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ18 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,843 115 135 19,400 18,584 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ19 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,025 120 143 22,500 22,269 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ20 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,415 129 158 27,050 27,075 2.00 1.00 0.39 30.00 2.00 0.25 0.15
13Ͳ21 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,504 131 164 30,250 30,649 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
13Ͳ22 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,800 138 177 34,800 36,187 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
13Ͳ23 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,012 96 124 26,000 27,033 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
13Ͳ24 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,672 111 138 21,000 24,982 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
13Ͳ25 30#HyborGSpacerandBallDrop 37.0 1,428 1,991 47 47 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
14Ͳ1 30#HyborG Pad 37.0 7,810 7,773 185 185 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,985 381 385 4,000 3,748 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,981 47 49 2,000 1,404 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,533 60 65 5,000 4,017 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,002 95 107 12,000 11,348 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,861 116 136 19,400 19,283 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,986 119 142 22,500 22,278 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,418 129 158 27,050 27,660 2.00 1.00 0.39 30.00 2.00 0.25 0.15
14Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,504 131 162 30,250 29,315 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
14Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,843 139 176 34,800 34,286 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
14Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,080 97 124 26,000 25,515 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
14Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,468 130 159 21,000 27,025 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15
14Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,428 1,835 44 44 2.00 1.00 0.39 0.50 30.00 2.00 1.50 0.15Interval 10Torok@ 17015.01 - 17017.06 ft 138 °FInterval 11Torok@ 16494.74 - 16496.79 ft 137.9 °FInterval 12Torok@ 16016.35 - 16018.4 ft 137.9 °FInterval 13Torok@ 15453.29 - 15455.34 ft 138.1 °FInterval 14Torok@ 14890.38 - 14892.43 ft 138.2 °FConocoPhillipsͲ3SͲ617 ActualDesign 6
CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.54 LAT70.39411269
LEASE 3SͲ617 SALESORDE BHST(°F)140 LONG Ͳ150.1934482
FORMATION Torok DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure*
Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 CatͲ3WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer Catalyst
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)
LiquidAdditives DryAdditives
50Ͳ103Ͳ20864
0909172317
15Ͳ1 30#HyborG Pad 37.0 7,810 7,654 182 182 2.00 1.00 0.39 30.00 2.00 0.25 0.15
15Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,012 381 386 4,000 3,997 2.00 1.00 0.39 30.00 2.00 0.25 0.15
15Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,029 48 50 2,000 1,496 2.00 1.00 0.39 30.00 2.00 0.25 0.15
15Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 3,611 86 92 5,000 5,611 2.00 1.00 0.39 30.00 2.00 0.25 0.15
15Ͳ5 Seawater Flush 20.0 9,961 10,130 241 241 0.15
15Ͳ6 FreezeProtect FreezeProtect 5.0 1,470 1,050 25 25
15Ͳ7 ShutͲIn ShutͲIn Ͳ
15Ͳ8 ShutͲIn ShutͲIn Ͳ
15Ͳ9 FreezeProtect PrimeUpPressureTest 5.0 1,000 3,150 75 75
15Ͳ10 ShutͲIn ShutͲIn Ͳ
15Ͳ11 30#Linear SpacerandBallDrop 15.0 1,260 128 3 3 1.00 30.00 2.00 0.25 0.15
15Ͳ12 30#HyborG EstablishStableFluid15.0 8,400 16,127 384 384 2.00 1.00 0.40 30.00 2.00 0.25 0.15
15Ͳ13 30#HyborG Pad 37.0 7,810 7,879 188 188 2.00 1.00 0.40 30.00 2.00 0.25 0.15
15Ͳ14 30#HyborG ConditioningPad Wanli16/20Ceramic 0.25 37.0 16,000 16,091 383 388 4,000 4,498 2.20 1.00 0.40 30.00 2.00 0.25 0.15
15Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,963 47 48 2,000 1,280 2.20 1.00 0.40 30.00 2.00 0.25 0.15
15Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,485 59 63 5,000 4,043 2.20 1.00 0.40 30.00 2.00 0.25 0.15
15Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,079 97 109 12,000 11,466 2.20 1.00 0.40 30.00 2.00 0.25 0.15
15Ͳ18 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,800 114 135 19,400 19,399 2.20 1.00 0.42 30.00 2.00 0.25 0.15
15Ͳ19 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,979 119 142 22,500 22,413 2.20 1.00 0.42 30.00 2.00 0.25 0.15
15Ͳ20 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,331 127 155 27,050 26,325 2.20 1.00 0.42 30.00 2.00 0.25 0.15
15Ͳ21 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,449 130 162 30,250 30,301 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
15Ͳ22 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,783 138 173 34,800 33,122 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
15Ͳ23 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,973 95 122 26,000 26,036 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
15Ͳ24 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,399 129 157 21,000 26,989 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
15Ͳ25 30#HyborGSpacerandBallDrop 37.0 1,428 1,820 43 43 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
16Ͳ1 30#HyborG Pad 37.0 7,810 7,828 186 186 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 16,025 382 385 4,000 3,503 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,031 48 49 2,000 1,070 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,454 58 62 5,000 3,625 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,005 95 107 12,000 10,683 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,887 116 137 19,400 19,070 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,992 119 142 22,500 21,991 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,450 130 158 27,050 26,952 2.20 1.00 0.42 30.00 2.00 0.25 0.15
16Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,533 132 163 30,250 29,877 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
16Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,795 138 174 34,800 34,255 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
16Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,007 95 124 26,000 27,140 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
16Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,066 121 150 21,000 27,715 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
16Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,428 1,802 43 43 2.20 1.00 0.42 0.50 30.00 2.00 1.50 0.15
17Ͳ1 30#HyborG Pad 37.0 1,000 1,038 25 25 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 17,002 405 409 4,000 3,998 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,400 2,453 58 60 1,400 1,367 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,750 1,830 44 47 3,500 2,814 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,800 2,884 69 76 8,400 7,079 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,395 3,554 85 97 13,580 12,120 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,500 3,552 85 100 15,750 14,267 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,787 3,867 92 111 18,935 18,008 2.00 1.00 0.45 30.00 2.00 0.25 0.15
17Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,850 3,911 93 115 21,175 20,196 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
17Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 4,060 4,173 99 123 24,360 22,607 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
17Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,800 3,329 79 99 18,200 19,030 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
17Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 2,100 5,081 121 149 14,700 26,221 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
17Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,428 1,908 45 45 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
18Ͳ1 30#HyborG Pad 37.0 1,000 1,244 30 30 2.00 1.00 0.45 30.00 2.00 0.15
18Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 4,000 5,531 132 133 1,000 944 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ3 Seawater Displacement 10.0 100 6,431 153 153 0.15
18Ͳ4 30#HyborG EstablishStableFluid15.0 8,400 8,959 213 213 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ5 30#HyborG ConditioningPad 100M 0.25 37.0 12,000 14,048 334 338 3,000 3,615 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,400 1,358 32 33 1,400 738 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,750 1,773 42 45 3,500 2,529 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,800 2,860 68 76 8,400 7,540 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,395 3,446 82 95 13,580 12,568 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,500 3,531 84 101 15,750 15,945 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,787 3,817 91 112 18,935 19,535 2.00 1.00 0.45 30.00 2.00 0.25 0.15
18Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,850 3,881 92 116 21,175 22,017 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
18Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 4,060 4,042 96 122 24,360 24,532 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
18Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,800 2,835 68 88 18,200 19,112 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
18Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 2,100 4,733 113 136 14,700 22,017 2.00 1.00 0.45 0.50 30.00 2.00 1.50 0.15
18Ͳ16 30#Linear Flush 37.0 8,831 9,137 218 218 1.00 0.50 30.00 2.00 1.50 0.15
18Ͳ17 FreezeProtect FreezeProtect 5.0 1,470 3,150 75 75
18Ͳ18 ShutͲIn ShutͲIn ͲInterval 17Torok@ 13130.09 - 13132.14 ft 138.7 °FInterval 16Torok@ 13692.74 - 13694.79 ft 138.5 °FInterval 18Torok@ 12525.58 - 12527.63 ft 138.8 °FInterval 15Torok@ 14292.34 - 14294.39 ft 138.3 °FConocoPhillipsͲ3SͲ617 ActualDesign 7
CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.54 LAT70.39411269
LEASE 3SͲ617 SALESORDE BHST(°F)140 LONG Ͳ150.1934482
FORMATION Torok DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure*
Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 CatͲ3WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer Catalyst
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)
LiquidAdditives DryAdditives
50Ͳ103Ͳ20864
0909172317
19Ͳ1 ShutͲIn ShutͲIn Ͳ
19Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 2,100 50 50
19Ͳ3 ShutͲIn ShutͲIn Ͳ
19Ͳ4 30#Linear SpacerandBallDrop 15.0 1,260 1,036 25 25 1.00 30.00 2.00 0.25 0.15
19Ͳ5 30#Linear DisplaceBalltoSeat 15.0 7,620 6,571 156 156 1.00 30.00 2.00 0.25 0.15
19Ͳ6 30#Linear StepRateTest 10.0 8,400 2,595 62 62 1.00 30.00 2.00 0.25 0.15
19Ͳ7 30#HyborG EstablishStableFluid17.0 8,400 16,269 387 387 2.00 1.00 0.50 30.00 2.00 0.25 0.15
19Ͳ8 30#HyborG Pad 37.0 1,000 4,703 112 112 2.00 1.00 0.50 30.00 2.00 0.25 0.15
19Ͳ9 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 21,941 522 527 4,000 4,034 2.00 1.00 0.50 30.00 2.00 0.25 0.15
19Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,400 1,435 34 35 1,400 752 2.00 1.00 0.50 30.00 2.00 0.25 0.15
19Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,750 1,784 42 45 3,500 2,791 2.00 1.00 0.50 30.00 2.00 0.25 0.15
19Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,800 2,797 67 74 8,400 6,897 2.00 1.00 0.50 30.00 2.00 0.25 0.15
19Ͳ13 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,395 3,394 81 95 13,580 13,616 2.00 1.00 0.50 30.00 2.00 0.25 0.15
19Ͳ14 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,500 3,614 86 104 15,750 16,601 2.00 1.00 0.50 30.00 2.00 1.50 0.15
19Ͳ15 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,787 3,789 90 108 18,935 16,697 2.00 1.00 0.50 30.00 2.00 1.50 0.15
19Ͳ16 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,850 4,208 100 116 21,175 15,181 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
19Ͳ17 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 4,060 4,077 97 114 24,360 15,744 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
19Ͳ18 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,800 2,806 67 85 18,200 16,766 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
19Ͳ19 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 2,100 6,820 162 201 14,700 35,989 2.00 1.00 0.50 0.50 30.00 2.00 0.25 0.15
19Ͳ20 30#HyborGSpacerandBallDrop 37.0 1,470 1,851 44 44 2.00 1.00 0.50 0.50 30.00 2.00 0.25 0.15
20Ͳ1 30#HyborG Pad 37.0 1,000 3,041 72 72 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 19,463 463 469 4,000 4,897 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,400 1,400 33 34 1,400 1,013 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,750 1,752 42 45 3,500 3,277 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,800 2,832 67 76 8,400 7,860 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,395 3,404 81 95 13,580 13,222 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,500 3,501 83 99 15,750 14,880 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,787 3,816 91 110 18,935 18,052 2.00 1.00 0.50 30.00 2.00 0.25 0.15
20Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,850 3,851 92 113 21,175 20,114 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
20Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 4,060 4,072 97 121 24,360 22,737 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
20Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,800 2,804 67 85 18,200 17,054 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
20Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 2,100 3,325 79 94 14,700 14,161 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
20Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,470 1,651 39 39 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
21Ͳ1 30#HyborG Pad 37.0 1,000 3,223 77 77 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,210 362 366 4,000 3,180 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,400 1,477 35 36 1,400 663 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,750 2,975 71 76 3,500 4,767 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,800 4,707 112 127 8,400 13,681 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,395 3,424 82 96 13,580 13,267 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,500 3,525 84 100 15,750 15,418 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,787 3,900 93 114 18,935 19,504 2.00 1.00 0.50 30.00 2.00 0.25 0.15
21Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,850 3,878 92 115 21,175 21,499 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
21Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 4,060 4,070 97 123 24,360 24,889 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
21Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,800 2,746 65 84 18,200 17,415 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
21Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 2,100 2,453 58 67 14,700 8,467 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
21Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,470 1,815 43 43 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
22Ͳ1 30#HyborG Pad 37.0 1,000 2,086 50 50 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ2 30#HyborG ConditioningPad 100M 0.25 37.0 16,000 15,050 358 362 4,000 3,588 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 1,400 1,419 34 35 1,400 1,208 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 1,750 1,809 43 46 3,500 2,982 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 2,800 2,798 67 74 8,400 7,192 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 3,395 3,419 81 94 13,580 12,247 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 3,500 3,512 84 100 15,750 15,572 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 3,787 3,788 90 110 18,935 18,425 2.00 1.00 0.50 30.00 2.00 0.25 0.15
22Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 3,850 3,873 92 114 21,175 20,846 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
22Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 4,060 4,855 116 138 24,360 21,242 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
22Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 2,800 2,803 67 85 18,200 16,771 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
22Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 2,100 4,507 107 132 14,700 22,914 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
22Ͳ13 30#HyborGSpacerandBallDrop 37.0 1,470 1,817 43 43 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15Interval 19Torok@ 11920.95 - 11923 ft 139 °FInterval 20Torok@ 11316.79 - 11318.84 ft 139.3 °FInterval 21Torok@ 10712.52 - 10714.57 ft 139.5 °FInterval 22Torok@ 10108.63 - 10110.68 ft 139.5 °FConocoPhillipsͲ3SͲ617 ActualDesign 8
CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.54 LAT70.39411269
LEASE 3SͲ617 SALESORDE BHST(°F)140 LONG Ͳ150.1934482
FORMATION Torok DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure*
Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M LosurfͲ300D MOͲ67 CatͲ3WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6
Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Surfactant Buffer Catalyst
Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt)
LiquidAdditives DryAdditives
50Ͳ103Ͳ20864
0909172317
23Ͳ1 30#HyborG Pad 25.0 1,000 3,437 82 82 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ2 30#HyborG ConditioningPad 100M 0.25 25.0 16,000 15,263 363 368 4,000 3,887 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 25.0 1,400 1,417 34 35 1,400 918 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 25.0 1,750 1,747 42 45 3,500 2,998 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 25.0 2,800 2,813 67 76 8,400 8,150 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 25.0 3,395 3,408 81 96 13,580 13,580 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 25.0 3,500 3,520 84 100 15,750 15,065 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 25.0 3,787 3,833 91 110 18,935 17,726 2.00 1.00 0.50 30.00 2.00 0.25 0.15
23Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 25.0 3,850 3,857 92 113 21,175 19,967 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
23Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 25.0 4,060 4,106 98 124 24,360 24,552 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
23Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 25.0 2,800 2,815 67 86 18,200 17,771 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
23Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 25.0 2,100 3,711 88 109 14,700 19,746 2.00 1.00 0.50 0.50 30.00 2.00 1.50 0.15
23Ͳ13 30#HyborGSpacerandBallDrop 25.0 1,470 1,568 37 37 2.00 1.00 0.50 30.00 2.00 1.50 0.15
24Ͳ1 30#HyborG Pad 25.0 1,000 2,098 50 50 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ2 30#HyborG ConditioningPad 100M 0.25 25.0 16,000 17,973 428 432 4,000 3,834 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ3 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 1.00 25.0 1,400 1,414 34 35 1,400 1,126 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ4 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 2.00 25.0 1,750 1,743 42 45 3,500 2,959 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ5 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 3.00 25.0 2,800 2,812 67 75 8,400 7,875 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ6 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.00 25.0 3,395 3,405 81 95 13,580 12,916 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ7 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 4.50 25.0 3,500 3,519 84 100 15,750 14,878 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ8 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.00 25.0 3,787 3,821 91 108 18,935 16,441 2.00 1.00 0.55 30.00 2.00 0.25 0.15
24Ͳ9 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 5.50 25.0 3,850 3,840 91 114 21,175 21,019 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
24Ͳ10 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.00 25.0 4,060 4,062 97 121 24,360 23,273 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
24Ͳ11 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 6.50 25.0 2,800 2,846 68 88 18,200 19,379 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
24Ͳ12 30#HyborG ProppantLadenFluid Wanli16/20Ceramic 7.00 25.0 2,100 5,518 131 163 14,700 29,416 2.00 1.00 0.55 0.50 30.00 2.00 1.50 0.15
24Ͳ13 30#Linear Flush 25.0 6,517 6,567 156 156 1.00 30.00 2.00 1.50 0.15
24Ͳ14 FreezeProtect FreezeProtect 10.0 1,470 Ͳ
24Ͳ15 ShutͲIn ShutͲIn Ͳ
2,391,000 2,510,168 59,766 65,011 4,929,400 4,938,276
DesignTotal(gal)ActualTotal(gal)DesignTotal(lbs)CalculatedTotal(lbs)TicketTotal(lbs)CLͲ28M LosurfͲ300D MOͲ67 CatͲ3WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6
2,171,786 2,261,907 4,829,400 4,843,272 4,948,809 (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs)
133,109 132,169 100,000 94,060 111,000 InitialDesignMaterialVolume 4,343.6 2,320.7 879.4 244.4 68,774.6 4,604.9 1,242.3 355.3
63,885 71,727 ͲͲ Ͳ ActualDesignMaterialVolume 4,674.3 2,423.4 1,030.1 297.5 71,822.3 4,846.7 1,255.2 369.9
22,220 37,590 23730 ͲͲ Ͳ PhysicalMaterialVolumePumped 4,814 2,531 1067 287 70923 4,690 1,300 366
ͲͲ ͲͲͲ PhysicalMaterialVolumeDeviance 3% 4% 4%Ͳ4%Ͳ1%Ͳ3% 4%Ͳ1%
ͲͲ **IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedonmultiplevariables MicroMotionVolumePumped 4,459 2,291 979 323 80,764 4,554 1,231 Ͳ
ͲͲ **ProppantisbilledfromWeightTicketvolumes MicroMotionVolumeDeviance Ͳ5%Ͳ5%Ͳ5% 8% 12%Ͳ6%Ͳ2%Ͳ
ͲͲ
Ͳ
Ͳ
ͲInterval 23Torok@ 9507.18 - 9509.23 ft 139.5 °FInterval 24Torok@ 8904.18 - 8906.23 ft 139.3 °FͲ
FluidType
30#HyborG
30#Linear
Seawater
FreezeProtect
Ͳ
ProppantType
Wanli16/20Ceramic
100M
Ͳ
Ͳ
ConocoPhillipsͲ3SͲ617 ActualDesign 9
ConocoPhillips
Torok
3SͲ617
50Ͳ103Ͳ20864
*Exceeds80%ofburstpressure*
Description OD(in) ID(in) Wt(#) Grade
FUF
(gal/ft)MDTop(ft) MDBtm(ft) Volume(gal)TubularBurst
Pressure(psi)
Tubing 4.5 3.958 12.6 LͲ80 0.6392 0 8,148 5,208 8,430
Tubing 4.5 3.958 12.6 LͲ80 0.6392 8,148 21,240 8,368 8,430
Total 21,240 13,577
ft 1.51
ft 139.5
ft
ft 1.51
ft 139.5
ft
TopMD(ft) BtmMD(ft)Average
TVD(ft)Interval# FormationDescriptor AverageInterval
Temperature(F)
BallDropTime
(HH:MM)
BallHitTime
(HH:MM)
JSVDrop
(bbl)
JSVSlow
Down(bbl)JSVHit(bbl)Early(bbl)
SurfaceSeat
Pressure
(psi)
SurfacePeak
Pressure
(psi)
SurfaceDifferential(psi)
BHSeat
Pressure
(psi)
BHPeak
Pressure
(psi)
BH
Differential
(psi)
RateatShift
(bpm)
Toe 21034.42 21038.28 5,164 1 Torok 138.0 Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ ͲͲ Ͳ ͲͲͲͲ
20548.49 20552.35 5,167 2 Torok 138.0 1:33:00PM 1:52:00PM 4,847 5,130 5,119 40.7 1,9306,0564,1263,9467,6353,68910.3
20070.59 20074.45 5,165 3 Torok 138.0 3:57:00PM 4:07:00PM 9,409 9,684 9,696 18.5 1,8115,0973,2863,8927,0553,16310.2
19593.73 19597.59 5,166 4 Torok 138.0 3:19:00PM 3:29:00PM 4,566 4,834 4,856 8.2 2,0267,0645,0383,9629,1755,21310.3
19076.70 19080.56 5,167 5 Torok 138.0 10:57:00AM 11:17:00AM 42 302 324 8.3 1,8286,1454,3173,5557,9744,41910.5
18723.67 18727.53 5,168 6 Torok 138.0 12:41:00PM 12:49:00PM 3,071 3,326 3,343 13.0 1,7415,0593,3183,7567,1013,34510.3
18327.39 18331.25 5,170 7 Torok 138.1 11:56:00AM 12:16:00PM 50 299 323 5.9 1,6644,9433,2793,4276,5843,15710.4
17930.24 17934.10 5,167 8 Torok 138.0 1:31:00PM 1:40:00PM 3,042 3,285 3,305 9.9 1,8715,0393,1683,8986,7642,86610.0
17492.94 17494.99 5,164 9 Torok 138.0 1:17:00PM 1:35:00PM 4 240 257 13.4 1,4405,2863,8463,4846,8703,38611.2
17015.01 17017.06 5,164 10 Torok 138.0 2:32:00PM 2:41:00PM 2,212 2,441 2,460 11.0 1,8474,3312,4843,8576,2412,38411.1
16494.74 16496.79 5,160 11 Torok 137.9 3:27:00PM 3:36:00PM 4,123 4,344 4,361 13.0 1,6084,9803,3723,6446,8923,24810.9
16016.35 16018.40 5,162 12 Torok 137.9 4:22:00PM 4:32:00PM 6,024 6,238 6,259 8.8 1,5444,2952,7513,6006,3292,72910.4
15453.29 15455.34 5,169 13 Torok 138.1 11:52:00AM 12:09:00PM 4 209 227 12.0 9262,5761,6502,8874,5201,63310.6
14890.38 14892.43 5,179 14 Torok 138.2 5:37:00PM 5:45:00PM 2,100 2,297 2,318 8.6 1,5683,3451,7773,5495,2401,69110.0
14292.34 14294.39 5,185 15 Torok 138.3 6:32:00PM 6:41:00PM 3,985 4,173 4,195 7.5 1,4593,1691,7103,4585,1461,68810.3
13692.74 13694.79 5,199 16 Torok 138.5 9:32:00PM 9:39:00PM 2,264 2,442 2,463 9.4 1,4553,3571,9023,5575,1921,63510.4
13130.09 13132.14 5,211 17 Torok 138.7 10:28:00PM 10:36:00PM 4,141 4,311 4,333 7.8 1,3653,2151,8503,4505,2961,84610.1
12525.58 12527.63 5,216 18 Torok 138.8 11:11:00PM 11:18:00PM 5,591 5,752 5,775 6.6 1,3412,2038623,4574,32186410.2
11920.95 11923.00 5,231 19 Torok 139.0 9:15:00AM 9:27:00PM 4 155 174 10.9 5502,0441,4942,5983,8201,22210.5
11316.79 11318.84 5,249 20 Torok 139.3 10:43:00PM 10:48:00PM 2,281 2,423 2,449 4.2 1,3492,5561,2073,4274,40697910.3
10712.52 10714.57 5,266 21 Torok 139.5 11:26:00PM 11:32:00PM 3,732 3,865 3,889 6.0 1,3231,7504273,3593,74939010.8
10108.63 10110.68 5,265 22 Torok 139.5 12:07:00AM 12:12:00AM 5,149 5,273 5,307 Ͳ4.2 1,2913,0091,7183,4654,7271,26210.4
9507.18 9509.23 5,265 23 Torok 139.5 12:47:00AM 12:52:00AM 6,526 6,641 6,668 2.7 1,1952,7151,5203,2394,7431,50410.3
Heel 8904.18 8906.23 5,254 24 Torok 139.3 1:42:00AM 1:48:00AM 7,903 8,009 8,029 9.5 1,3272,9681,6413,3174,27495710.4
Temp.Gradient(°F/100ft)
BHST(°F)TVDatBottomPerf
MDatBottomPerf
5,266
21,038
KOP
Avg.TVD
TotalMD
7
8
9
10
11
2
3
4
5
6
17
18
19
20
21
12
13
14
15
16
Sleeve/PerfDepth Sleeves
235.2
226.6
217.5
Interval#
1
MaxPressure(psi)
8,500
IsolationType
SwellPacker
TreatmentTubulars
Customer
Formation
Lease
API
Date
TemperatureData
Temp.Gradient(°F/100ft)
BHST(°F)
DirectionalData
5,195
2,237
21,240
DirectionalData
2,237
2/26/2024
KOP
TemperatureData
22
23
24
12,829 305.5
12,524
12,194
11,968
DisplacementtoTop
Sleeve/Perf(gal)(BBLS)
13,445 320.1
13,135 312.7
298.2
290.3
285.0
10,238
9,878
9,518
9,136
8,752
11,715
11,461
11,181
10,876
10,543
6,077
5,692
8,393
8,006
7,620
7,234
6,847
6,461
278.9
272.9
266.2
259.0
251.0
243.8
163.0
153.8
144.7
135.5
208.4
199.8
190.6
181.4
172.2
ConocoPhillipsͲ3SͲ617 WellboreInformation 10
2/27/24 10:28
2/27/24 13:52
204 min
-bpm
-psi
-psi
-bbl
37.6 bpm
4,427 psi
5,956 psi
36.0 bpm
3,598 psi
3,493 psi
5,176 psi
3,175 hhp
431 psi
0 psi
634 psi
5.44 ppg
5
5
59 %
52 %
29 cP
89.4 F
8.8
296,725 lbs
4,031 lbs
300,756 lbs
300,756 lbs
270,885 gal 6,450 bbls
3,584 gal 85 bbls
31,632 gal 753 bbls
3,150 gal 75 bbls
3,150 gal 75 bbls
114,382 gal 2,723 bbls
15,067 gal 359 bbls
106,466 gal 2,535 bbls
5,748 gal 137 bbls
29,293 gal 697 bbls
32,806 gal 781 bbls
1,712 gal 41 bbls
627 gal 15 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
100M Pumped:
Proppant in Formation:
30# Hybor G Volume:
30# Linear Volume:
Seawater Volume:
Dart/Ball Early :
Average pH:
Pump Time:
Pad Percentage Actual
Wanli 16/20 Ceramic Pumped:
Average Visc:
Average Temp:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Interval Summary
3S-617 - Torok - Interval 1
Interval Summary
Start Date/Time:
End Date/Time:
Average Missile Pressure:
Open Well Pressure:
Initial OA Pressure:
Average Surface Pressure:
Average Rate:
Max OA Pressure:
Pumps Starting Stage:
Pad Percentage Design
Average Missile HHP:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Pumps Ending Stage:
Max Proppant Concentration:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
During the pad stage, OA pressure started increasing so the decision was made to shut down and bleed it
down. After bleeding downthe OA, another attempt was made to start the interval. However during the
second Pad, the OA again started behaving erratically. The transducer read almost 4000 psi so the job was
shut down immediately. The crew replaced the OA transducer and the well was flushed of XL. Due to the
late time in the afternoon, the crew resumed the interval the next day. Interval 1 was pumped as per design
on the 2nd day of pumping. Ball 02 did not seat, a second ball was loaded which had to be displaced with
Linear Gel.
DFIT Volume:
Arsenal Sleeve Shift Volume:
Proppant Summary
Freeze Protect Volume:
Greg Clayton
Willie Martin
Total Proppant Pumped* :
Prime Up Pressure Test Volume:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Flush Volume:
Establish Stable Fluid Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Spacer and Ball Drop Volume:
Interval Status:
Nate Brzezinski
James Campbell
ConocoPhillipsͲ3SͲ617 IntervalSummary 11
2/27/24 13:52
2/27/24 15:57
125 min
10.3 bpm
6,056 psi
7,635 psi
41 bbl
37.6 bpm
4,555 psi
6,072 psi
34.1 bpm
3,487 psi
3,383 psi
5,070 psi
2,914 hhp
449 psi
581 psi
5.99 ppg
5
5
32 %
33 %
28 cP
81.8 F
9.1
3381 psi
0.654 psi/ft
3374 psi
3364 psi
3356 psi
294,905 lbs
3,898 lbs
298,803 lbs
298,803 lbs
166,664 gal 3,968 bbls
12,174 gal 290 bbls
12,174 gal 290 bbls
38,332 gal 913 bbls
18,163 gal 432 bbls
102,401 gal 2,438 bbls
1,932 gal 46 bbls
5,836 gal 139 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Pad Percentage Design
Pad Percentage Actual
ISDP:
Final Fracture Gradient:
Final 5 min:
Final 10 min:
Displace Ball to Seat Volume:
Proppant in Formation:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Interval Summary
Start Date/Time:
End Date/Time:
Pump Time:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
3S-617 - Torok - Interval 2
Average BH Pressure:
Average Missile HHP:
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Pumps Starting Stage:
Pumps Ending Stage:
Average Visc:
Average Temp:
Average pH:
Final 15 min:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
30# Hybor G Volume:
30# Linear Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
Interval Status:
Sleeve 2 was successfully shifted with linear gel. An establish stable fluid stage was added to the interval.
The stage was pumped as per design.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Willie Martin
Nate Brzezinski
James Campbell
ConocoPhillipsͲ3SͲ617 IntervalSummary 12
2/29/24 12:50
2/29/24 15:19
149 min
10.2 bpm
5,097 psi
7,055 psi
18 bbl
37.6 bpm
5,193 psi
6,556 psi
35.5 bpm
3,762 psi
3,711 psi
5,233 psi
3,277 hhp
415 psi
186 psi
807 psi
6.81 ppg
5
4
32 %
31 %
27 cP
75.4 F
8.9
302,685 lbs
2,578 lbs
305,263 lbs
305,241 lbs
194,871 gal 4,640 bbls
16,328 gal 389 bbls
3,360 gal 80 bbls
2,100 gal 50 bbls
36,131 gal 860 bbls
15,953 gal 380 bbls
100,199 gal 2,386 bbls
4,476 gal 107 bbls
1,260 gal 30 bbls
21,935 gal 522 bbls
19,225 gal 458 bbls
13,280 gal 316 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Summary
Spacer and Ball Drop Volume:
Wanli 16/20 Ceramic Pumped:
Pad Volume:
Interval Summary
Average Missile HHP:
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
Average pH:
30# Linear Volume:
100M Pumped:
Max OA Pressure:
Max Proppant Concentration:
Open Well Pressure:
Pad Percentage Design
Pad Percentage Actual
Freeze Protect Volume:
Average Visc:
Initial OA Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Minifrac - Treatment Volume:
Minifrac - Flush Volume:
3S-617 - Torok - Interval 3
End Date/Time:
Max BH Pressure:
Average Rate:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Max Surface Pressure:
Pump Time:
Initial Rate (Breakdown):
Fluid Summary (by stage description)
Conditioning Pad Volume:
Establish Stable Fluid Volume:
30# Hybor G Volume:
Willie Martin
Craig Karpinski
James Campbell
Interval Status:
After completing interval 02, a ball for interval 03 was dropped and a minifrac was pumped as the final
activity for day 2 of pumping. During Interval 3, rate had to be dropped due to a water tank going dry. Pump
358 was brought offline due to a passing valve.
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Proppant Laden Fluid Volume:
Freeze Protect Volume:
Prime Up Pressure Test Volume:
Greg Clayton
ConocoPhillipsͲ3SͲ617 IntervalSummary 13
2/29/24 15:19
2/29/24 17:21
122 min
10.3 bpm
7,064 psi
9,175 psi
8 bbl
37.4 bpm
3,870 psi
5,468 psi
30.4 bpm
3,248 psi
3,210 psi
4,995 psi
2,422 hhp
672 psi
811 psi
6.99 ppg
4
3
32 %
32 %
28 cP
78.7 F
8.8
3482 psi
0.674 psi/ft
3488 psi
3457 psi
3430 psi
303,447 lbs
2,576 lbs
306,023 lbs
306,023 lbs
126,769 gal 3,018 bbls
13,131 gal 313 bbls
840 gal 20 bbls
28,185 gal 671 bbls
15,946 gal 380 bbls
82,638 gal 1,968 bbls
13,131 gal 313 bbls
840 gal 20 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Fluid Summary (by fluid description)
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial Rate (Breakdown):
Proppant in Formation:
Max Surface Pressure:
Freeze Protect Volume:
30# Hybor G Volume:
30# Linear Volume:
Average Rate:
Average Missile Pressure:
Average BH Pressure:
Average Missile HHP:
Pumps Ending Stage:
Pad Percentage Actual
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Flush Volume:
Interval Summary
Start Date/Time:
Initial Surface Pressure (Breakdown):
End Date/Time:
Pump Time:
3S-617 - Torok - Interval 4
Max BH Pressure:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Total Proppant Pumped* :
Pad Percentage Design
Average Surface Pressure:
Pumps Starting Stage:
Final Fracture Gradient:
Final 5 min:
100M Pumped:
ISDP:
Max OA Pressure:
Max Proppant Concentration:
Average Visc:
Final 10 min:
Final 15 min:
Average Temp:
Average pH:
Initial OA Pressure:
Pump 329 was taken offline due to a packing. Rate was dropped to 30bpm to preserve the Horsepower to
the end of the stage. Interval 04 was flushed and the last stage pumped for the day.
James Campbell
Pad Volume:
Conditioning Pad Volume:
Freeze Protect Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Interval Status:
Greg Clayton
Willie Martin
Craig Karpinski
ConocoPhillipsͲ3SͲ617 IntervalSummary 14
3/1/24 10:52
3/1/24 12:49
117 min
10.5 bpm
6,145 psi
7,974 psi
8 bbl
39.4 bpm
5,206 psi
6,730 psi
33.3 bpm
3,840 psi
3,819 psi
5,469 psi
3,133 hhp
540 psi
314 psi
748 psi
7.67 ppg
5
4
32 %
32 %
26.5 cP
93 F
8.6
303,910 lbs
5,438 lbs
309,348 lbs
309,154 lbs
113,534 gal 2,703 bbls
2,193 gal 52 bbls
2,100 gal 50 bbls
2,100 gal 50 bbls
19,826 gal 472 bbls
18,035 gal 429 bbls
67,046 gal 1,596 bbls
3,632 gal 86 bbls
7,188 gal 171 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Missile Pressure:
Max OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Temp:
Initial Surface Pressure (Breakdown):
Max Rate:
Pump Time:
Craig Karpinski
During 1 ppg 16/20 a pump neutraled out due to low pre-load pressure. The stage was pumped to
completion.
Pumps Starting Stage:
Pumps Ending Stage:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
James Campbell
Total Proppant Pumped* :
Initial Rate (Breakdown):
Spacer and Ball Drop Volume:
Establish Stable Fluid Volume:
30# Hybor G Volume:
Proppant Laden Fluid Volume:
Interval Status:
Average pH:
Pad Percentage Actual
3S-617 - Torok - Interval 5
Average BH Pressure:
Initial OA Pressure:
Max Proppant Concentration:
Start Date/Time:
Pad Percentage Design
Average Rate:
Proppant in Formation:
Pad Volume:
Prime Up Pressure Test Volume:
Willie Martin
Average Missile HHP:
Open Well Pressure:
Average Visc:
Max Surface Pressure:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Wanli 16/20 Ceramic Pumped:
Conditioning Pad Volume:
Freeze Protect Volume:
30# Linear Volume:
100M Pumped:
End Date/Time:
Max BH Pressure:
Average Surface Pressure:
ConocoPhillipsͲ3SͲ617 IntervalSummary 15
3/1/24 12:49
3/1/24 17:48
299 min
10.3 bpm
5,059 psi
7,101 psi
13 bbl
37.8 bpm
5,036 psi
6,457 psi
30.8 bpm
3,433 psi
3,323 psi
4,959 psi
2,595 hhp
765 psi
504 psi
717 psi
4.98 ppg
4
4
47 %
48 %
29 cP
83 F
8.7
MiniFrac
34.680 bpm
4474 psi
5858 psi
36.09 bpm
5024 psi
6495 psi
5859 psi
1.134 psi/ft
3412 psi
3392 psi
3398 psi
115,639 lbs
4,226 lbs
119,865 lbs
119,865 lbs
96,456 gal 2,297 bbls
32,050 gal 763 bbls
12,755 gal 304 bbls
1,680 gal 40 bbls
19,737 gal 470 bbls
16,175 gal 385 bbls
34,141 gal 813 bbls
12,755 gal 304 bbls
17,223 gal 410 bbls
1,680 gal 40 bbls
2,378 gal 57 bbls
7,548 gal 180 bbls
18,855 gal 449 bbls
12,449 gal 296 bbls
Cut Short
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Proppant Concentration:
Diagnostic method
Pad Percentage Actual
Proppant Laden Fluid Volume:
Freeze Protect Volume:
End Date/Time:
Max Surface Pressure:
Max BH Pressure:
Seawater Volume:
Open Well Pressure:
Max OA Pressure:
Minifrac - Flush Volume:
Flush Volume:
Pad Volume:
Wanli 16/20 Ceramic Pumped:
Pad Percentage Design
Average Temp:
Total Proppant Pumped* :
Final Fracture Gradient:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Initial OA Pressure:
Start Date/Time:
Average Surface Pressure:
Average BH Pressure:
100M Pumped:
Pumps Ending Stage:
Conditioning Pad Volume:
Interval Status:
Minifrac Average Rate:
Minifrac Max DH Pressure:
Average Visc:
Proppant in Formation:
Minifrac Average DH Pressure:
30# Hybor G Volume:
30# Linear Volume:
A minifrac was pumped at the beginning of interval 06. After analyzing decline, a step rate test was pumped
before getting back into the stage and establishing XL. During the 4.5 ppg sand stage, the blender screen
froze and the blender could not be electronically controlled. Screws were cut while trying to regain
connection. Rate readings had to be swapped to the pumps. After regaining control of the blender, the crew
did not have enough CL-28 to continue pumping due to settling of the totes.
Final 15 min:
Minifrac - Treatment Volume:
Willie Martin
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Minifrac Max Surface Pressure:
Minifrac Max Rate:
3S-617 - Torok - Interval 6
Interval Summary
Average pH:
Minifrac Average Pressure:
Final 5 min:
Final 10 min:
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Establish Stable Fluid Volume:
Displacement Volume:
Pumps Starting Stage:
Max Rate:
Average Missile Pressure:
Freeze Protect Volume:
Step Rate Test Volume:
ISDP:
Average Rate:
Pump Time:
Initial Rate (Breakdown):
Average Missile HHP:
ConocoPhillipsͲ3SͲ617 IntervalSummary 16
3/2/24 11:45
3/2/24 13:40
115 min
10.4 bpm
4,943 psi
6,584 psi
6 bbl
37.8 bpm
5,734 psi
7,192 psi
35.5 bpm
4,406 psi
4,320 psi
5,935 psi
3,837 hhp
480 psi
340 psi
722 psi
7.06 ppg
5
5
32 %
31 %
28 cP
81.6 F
8.8
302,441 lbs
3,899 lbs
306,340 lbs
306,242 lbs
111,965 gal 2,666 bbls
2,602 gal 62 bbls
1,260 gal 30 bbls
1,260 gal 30 bbls
19,837 gal 472 bbls
15,978 gal 380 bbls
66,847 gal 1,592 bbls
3,974 gal 95 bbls
7,931 gal 189 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant in Formation:
Proppant Laden Fluid Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Average Visc:
Average BH Pressure:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
Max Surface Pressure:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Conditioning Pad Volume:
Total Proppant Pumped* :
Average Temp:
Average Missile HHP:
Average pH:
Max Proppant Concentration:
Pad Volume:
3S-617 - Torok - Interval 7
End Date/Time:
Dart/Ball Early :
Pad Percentage Actual
Initial OA Pressure:
Pad Percentage Design
Pumps Starting Stage:
Proppant Summary
Open Well Pressure:
Pumps Ending Stage:
100M Pumped:
Pump Time:
Max Rate:
Initial BH Pressure (Breakdown):
Start Date/Time:
Interval Summary
Interval Status:
Interval 07 was pumped as per design.
Fluid Summary (by fluid description)
Spacer and Ball Drop Volume:
30# Hybor G Volume:
Greg Clayton
Prime Up Pressure Test Volume:
Establish Stable Fluid Volume:
Freeze Protect Volume:
Willie Martin
James Campbell
Fluid Summary (by stage description)
Craig Karpinski
30# Linear Volume:
ConocoPhillipsͲ3SͲ617 IntervalSummary 17
3/2/24 13:40
3/2/24 14:30
50 min
10.0 bpm
5,039 psi
6,764 psi
10 bbl
37.0 bpm
3,604 psi
5,339 psi
36.1 bpm
3,327 psi
3,252 psi
4,858 psi
2,944 hhp
715 psi
808 psi
5.92 ppg
5
5
41 %
42 %
26 cP
78.6 F
9
3481 psi
0.674 psi/ft
164,301 lbs
4,214 lbs
168,515 lbs
168,515 lbs
78,646 gal 1,873 bbls
12,234 gal 291 bbls
1,050 gal 25 bbls
19,921 gal 474 bbls
15,925 gal 379 bbls
42,800 gal 1,019 bbls
12,234 gal 291 bbls
1,050 gal 25 bbls
Cut Short
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Flush Volume:
During 4 ppg 16/20, a pump neutraled due to pre-load pressures. During the 5.5 ppg 16/20 sand stand, a
sharp pressure decrease was observed on surface and downhole. Ground boss called for a shut down due
to a leak on ground iron after the manifold. The well was shut-in, the iron replaced, and then the well was
flushed with Linear Gel.
Proppant Laden Fluid Volume:
Max OA Pressure:
Pumps Ending Stage:
Max BH Pressure:
Dart/Ball Early :
End Date/Time:
Pump Time:
Average pH:
Average Surface Pressure:
Pumps Starting Stage:
ISDP:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial OA Pressure:
Average Rate:
Max Proppant Concentration:
Average BH Pressure:
Initial Surface Pressure (Breakdown):
Start Date/Time:
Initial BH Pressure (Breakdown):
Average Missile Pressure:
Initial Rate (Breakdown):
Max Surface Pressure:
Freeze Protect Volume:
Proppant Summary
Freeze Protect Volume:
Max Rate:
Interval Summary
3S-617 - Torok - Interval 8
Pad Volume:
Average Visc:
Total Proppant Pumped* :
30# Linear Volume:
Final Fracture Gradient:
Conditioning Pad Volume:
Average Missile HHP:
Fluid Summary (by stage description)
Pad Percentage Actual
Pad Percentage Design
Proppant in Formation:
Average Temp:
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Fluid Summary (by fluid description)
30# Hybor G Volume:
Interval Status:
Willie Martin
Greg Clayton
Craig Karpinski
James Campbell
ConocoPhillipsͲ3SͲ617 IntervalSummary 18
3/7/24 13:11
3/7/24 14:41
90 min
11.2 bpm
5,286 psi
6,870 psi
13 bbl
38.2 bpm
5,589 psi
7,237 psi
33.7 bpm
4,364 psi
4,315 psi
5,897 psi
3,604 hhp
346 psi
4,464 psi
610 psi
6.67 ppg
5
5
32 %
31 %
30 cP
52.3 F
9.1
202,289 lbs
4,123 lbs
206,412 lbs
206,399 lbs
83,920 gal 1,998 bbls
141 gal 3 bbls
4,620 gal 110 bbls
4,620 gal 110 bbls
7,800 gal 186 bbls
15,974 gal 380 bbls
45,488 gal 1,083 bbls
1,904 gal 45 bbls
12,895 gal 307 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Pad Volume:
Average Missile HHP:
Initial OA Pressure:
Average Rate:
100M Pumped:
Pad Percentage Actual
After the ball seated, pressure trended high before slowly breaking down. Interval 09 was pumped as per
design.
Proppant in Formation:
Max OA Pressure:
James Campbell
Average BH Pressure:
Average Missile Pressure:
Interval Summary
Open Well Pressure:
Dart/Ball Early :
Average Visc:
Pad Percentage Design
Total Proppant Pumped* :
Max Surface Pressure:
Max BH Pressure:
Initial Rate (Breakdown):
Max Rate:
Pumps Ending Stage:
Initial Surface Pressure (Breakdown):
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Establish Stable Fluid Volume:
Spacer and Ball Drop Volume:
30# Hybor G Volume:
30# Linear Volume:
3S-617 - Torok - Interval 9
Prime Up Pressure Test Volume:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Initial BH Pressure (Breakdown):
Freeze Protect Volume:
Fluid Summary (by stage description)
Average pH:
Fluid Summary (by fluid description)
Start Date/Time:
End Date/Time:
Pump Time:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Willie Martin
Craig Karpinski
Average Temp:
Max Proppant Concentration:
Pumps Starting Stage:
Average Surface Pressure:
Greg Clayton
ConocoPhillipsͲ3SͲ617 IntervalSummary 19
3/7/24 14:41
3/7/24 15:36
55 min
11.1 bpm
4,331 psi
6,241 psi
11 bbl
37.3 bpm
4,308 psi
5,885 psi
34.8 bpm
3,516 psi
3,451 psi
5,052 psi
3,000 hhp
606 psi
725 psi
7.32 ppg
5
5
32 %
31 %
30 cP
67.4 F
9.1
206,548 lbs
3,266 lbs
209,814 lbs
209,814 lbs
71,466 gal 1,702 bbls
7,870 gal 187 bbls
16,007 gal 381 bbls
45,286 gal 1,078 bbls
2,303 gal 55 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Average Surface Pressure:
Proppant Laden Fluid Volume:
Pad Volume:
Conditioning Pad Volume:
100M Pumped:
Average Temp:
Max Surface Pressure:
Max BH Pressure:
Pumps Ending Stage:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Proppant Summary
Average Missile Pressure:
Average Rate:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Willie Martin
Max Rate:
Total Proppant Pumped* :
Proppant in Formation:
Fluid Summary (by fluid description)
Average Missile HHP:
Wanli 16/20 Ceramic Pumped:
Initial OA Pressure:
Max Proppant Concentration:
Interval 10 showed stable net pressure growth throughout the interval. The interval was pumped as per
design.
Interval Summary
Pump Time:
Start Date/Time:
3S-617 - Torok - Interval 10
End Date/Time:
Initial BH Pressure (Breakdown):
Pad Percentage Actual
Pumps Starting Stage:
Dart/Ball Early :
30# Hybor G Volume:
Average Visc:
Pad Percentage Design
Max OA Pressure:
Average pH:
Average BH Pressure:
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
ConocoPhillipsͲ3SͲ617 IntervalSummary 20
3/7/24 15:36
3/7/24 16:32
56 min
10.9 bpm
4,980 psi
6,892 psi
13 bbl
37.9 bpm
4,143 psi
5,457 psi
34.2 bpm
3,213 psi
3,136 psi
4,722 psi
2,692 hhp
673 psi
745 psi
7.32 ppg
5
5
32 %
31 %
29 cP
64.6 F
9.1
198,739 lbs
4,467 lbs
203,206 lbs
203,003 lbs
71,115 gal 1,693 bbls
7,851 gal 187 bbls
16,041 gal 382 bbls
45,199 gal 1,076 bbls
2,024 gal 48 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Max Surface Pressure:
Spacer and Ball Drop Volume:
Average Missile Pressure:
Proppant Laden Fluid Volume:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Start Date/Time:
Interval Status:
Willie Martin
Average Missile HHP:
Pumps Starting Stage:
100M Pumped:
Conditioning Pad Volume:
Max BH Pressure:
Average Rate:
Average BH Pressure:
Pad Percentage Actual
Initial OA Pressure:
Interval Summary
Proppant Summary
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
Pumps Ending Stage:
Pump Time:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
30# Hybor G Volume:
3S-617 - Torok - Interval 11
End Date/Time:
Max Proppant Concentration:
Average Visc:
Average Temp:
Max Rate:
Wanli 16/20 Ceramic Pumped:
Average pH:
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Pad Percentage Design
Average Surface Pressure:
Max OA Pressure:
Fluid Summary (by stage description)
Pad Volume:
During 3.0 ppg 16/20, rate had to be dropped due to suction issues on the blender due to a tank running
low. During the spacer, rate was dropped to 7bpm due to suction issues on the blender but all tanks were at
40". Stage was pumped to completion.
Greg Clayton
ConocoPhillipsͲ3SͲ617 IntervalSummary 21
3/7/24 16:32
3/7/24 17:26
54 min
10.4 bpm
4,295 psi
6,329 psi
9 bbl
37.3 bpm
5,124 psi
6,644 psi
35.9 bpm
3,617 psi
3,534 psi
5,119 psi
3,183 hhp
681 psi
761 psi
7.36 ppg
5
5
32 %
31 %
27 cP
67.8 F
8.9
3328 psi
0.645 psi/ft
3263 psi
3223 psi
3183 psi
198,902 lbs
4,635 lbs
203,537 lbs
203,537 lbs
70,604 gal 1,681 bbls
11,284 gal 269 bbls
2,730 gal 65 bbls
8,337 gal 199 bbls
16,010 gal 381 bbls
46,257 gal 1,101 bbls
11,284 gal 269 bbls
2,730 gal 65 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Flush Volume:
Freeze Protect Volume:
Conditioning Pad Volume:
Pad Volume:
Proppant in Formation:
Final 15 min:
Final 5 min:
Total Proppant Pumped* :
100M Pumped:
Max Surface Pressure:
ISDP:
Final 10 min:
Wanli 16/20 Ceramic Pumped:
Pumps Ending Stage:
Pad Percentage Design
Freeze Protect Volume:
Proppant Laden Fluid Volume:
Average Temp:
Interval Status:
Interval 12 was pumped as per design. It was the final interval pumped for the day. Willie Martin
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
30# Linear Volume:
Greg Clayton
Proppant Summary
Fluid Summary (by fluid description)
30# Hybor G Volume:
Fluid Summary (by stage description)
Start Date/Time:
Average Rate:
Average Missile Pressure:
Final Fracture Gradient:
Pad Percentage Actual
Initial Rate (Breakdown):
Average BH Pressure:
Dart/Ball Early :
Max BH Pressure:
Average Visc:
Average Surface Pressure:
End Date/Time:
Average Missile HHP:
Initial Surface Pressure (Breakdown):
Max OA Pressure:
Average pH:
Max Rate:
Initial OA Pressure:
Pumps Starting Stage:
Max Proppant Concentration:
Pump Time:
3S-617 - Torok - Interval 12
Interval Summary
Initial BH Pressure (Breakdown):
ConocoPhillipsͲ3SͲ617 IntervalSummary 22
3/9/24 16:24
3/9/24 17:45
81 min
10.6 bpm
2,576 psi
4,520 psi
12 bbl
37.5 bpm
3,582 psi
5,047 psi
34.9 bpm
3,039 psi
2,989 psi
4,564 psi
2,601 hhp
286 psi
328 psi
609 psi
7.54 ppg
5
5
32 %
31 %
30 cP
66 F
9.0
202,883 lbs
3,484 lbs
206,367 lbs
206,367 lbs
88,679 gal 2,111 bbls
414 gal 10 bbls
10,779 gal 257 bbls
7,350 gal 175 bbls
7,350 gal 175 bbls
7,765 gal 185 bbls
15,979 gal 380 bbls
43,833 gal 1,044 bbls
10,779 gal 257 bbls
2,405 gal 57 bbls
19,111 gal 455 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Freeze Protect Volume:
Establish Stable Fluid Volume:
Interval Status:
100M Pumped:
Seawater Volume:
Proppant in Formation:
Prime Up Pressure Test Volume:
Displacement Volume:
30# Hybor G Volume:
Max Rate:
Wanli 16/20 Ceramic Pumped:
Average BH Pressure:
Average Temp:
Dart/Ball Early :
Pumps Ending Stage:
Open Well Pressure:
Pad Volume:
Average Surface Pressure:
Start Date/Time:
3S-617 - Torok - Interval 13
Average Rate:
Pad Percentage Design
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Max Surface Pressure:
Max Proppant Concentration:
Proppant Summary
Pumps Starting Stage:
Max BH Pressure:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial BH Pressure (Breakdown):
Average Missile Pressure:
Pump Time:
Greg Clayton
Max OA Pressure:
Average Visc:
Average pH:
Initial OA Pressure:
Average Missile HHP:
30# Linear Volume:
Interval Summary
End Date/Time:
Total Proppant Pumped* :
Conditioning Pad Volume:
Spacer and Ball Drop Volume:
Pad Percentage Actual
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
After dropping the ball and trying to establish XL, and oil leak was observed on the ADP coming from the
rear main seal. The XL in the wellbore was flushed before shutting down to rig out the ADP. The interval
was resumed the next day without issue and pumped to completion.
Willie Martin
Craig Karpinski
James Campbell
Fluid Summary (by fluid description)
ConocoPhillipsͲ3SͲ617 IntervalSummary 23
3/9/24 17:45
3/9/24 18:41
56 min
10.0 bpm
3,345 psi
5,240 psi
9 bbl
37.5 bpm
4,301 psi
5,793 psi
34.4 bpm
3,158 psi
3,107 psi
4,741 psi
2,663 hhp
596 psi
747 psi
7.20 ppg
5
5
32 %
31 %
28.6 cP
74.2 F
9
202,131 lbs
3,748 lbs
205,879 lbs
205,879 lbs
70,269 gal 1,673 bbls
7,773 gal 185 bbls
15,985 gal 381 bbls
44,676 gal 1,064 bbls
1,835 gal 44 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Rate:
Average Missile Pressure:
Pumps Ending Stage:
Interval Status:
Initial BH Pressure (Breakdown):
Average Surface Pressure:
Pad Percentage Design
Pad Percentage Actual
100M Pumped:
End Date/Time:
Average Temp:
Dart/Ball Early :
Max Surface Pressure:
Max OA Pressure:
Max Proppant Concentration:
Initial Rate (Breakdown):
Proppant Summary
Greg Clayton
Interval 14 was pumped as per design.
Pump Time:
Average pH:
Wanli 16/20 Ceramic Pumped:
Max Rate:
Max BH Pressure:
3S-617 - Torok - Interval 14
Average Visc:
Initial OA Pressure:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Willie Martin
Interval Summary
Start Date/Time:
Average Missile HHP:
Pumps Starting Stage:
Average BH Pressure:
Initial Surface Pressure (Breakdown):
Total Proppant Pumped* :
Proppant Laden Fluid Volume:
Pad Volume:
Proppant in Formation:
Fluid Summary (by fluid description)
30# Hybor G Volume:
Conditioning Pad Volume:
ConocoPhillipsͲ3SͲ617 IntervalSummary 24
3/12/24 20:10
3/12/24 21:39
89 min
10.3 bpm
3,169 psi
5,146 psi
8 bbl
37.8 bpm
3,481 psi
5,953 psi
32.6 bpm
2,891 psi
2,735 psi
4,455 psi
2,309 hhp
139 psi
424 psi
650 psi
7.37 ppg
5
5
46 %
45 %
29 cP
70.8 F
9.1
212,979 lbs
3,997 lbs
216,976 lbs
216,951 lbs
115,464 gal 2,749 bbls
128 gal 3 bbls
10,130 gal 241 bbls
4,200 gal 100 bbls
3,150 gal 75 bbls
15,533 gal 370 bbls
32,103 gal 764 bbls
49,881 gal 1,188 bbls
1,948 gal 46 bbls
10,130 gal 241 bbls
1,050 gal 25 bbls
16,127 gal 384 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Rate:
Start Date/Time:
Seawater Volume:
30# Hybor G Volume:
Proppant Laden Fluid Volume:
Greg Clayton
Pumps Starting Stage:
Proppant Summary
Total Proppant Pumped* :
Proppant in Formation:
Average Temp:
Open Well Pressure:
Fluid Summary (by fluid description)
Freeze Protect Volume:
Spacer and Ball Drop Volume:
Average Surface Pressure:
Wanli 16/20 Ceramic Pumped:
30# Linear Volume:
Max Surface Pressure:
Fluid Summary (by stage description)
Freeze Protect Volume:
Pump Time:
Initial Rate (Breakdown):
Initial OA Pressure:
Max OA Pressure:
Max Proppant Concentration:
Conditioning Pad Volume:
100M Pumped:
Average Visc:
Average pH:
Initial BH Pressure (Breakdown):
Average BH Pressure:
Average Missile HHP:
Craig Karpinski
James Campbell
During the first attempt at pumping interval 15 during 2 ppg proppant, there was a leak on the low pressure
side of the manifold that required shutting down. The well was flushed. During the second attempt at
interval 15, the 100 Mesh quarter pound stage was substituted with 0.25 ppg 16/20. Rate fluctuated due to
pre-loads and mechanical problems on the pumps. The interval was pumped to completion.
Dart/Ball Early :
3S-617 - Torok - Interval 15
Interval Summary
Average Missile Pressure:
Pad Percentage Actual
Pumps Ending Stage:
Pad Percentage Design
End Date/Time:
Max BH Pressure:
Max Rate:
Initial Surface Pressure (Breakdown):
Pad Volume:
Prime Up Pressure Test Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Establish Stable Fluid Volume:
Flush Volume:
Willie Martin
Interval Status:
ConocoPhillipsͲ3SͲ617 IntervalSummary 25
3/12/24 21:39
3/12/24 22:36
57 min
10.4 bpm
3,357 psi
5,192 psi
9 bbl
37.7 bpm
4,110 psi
5,620 psi
33.6 bpm
2,886 psi
2,707 psi
4,464 psi
2,377 hhp
650 psi
865 psi
7.28 ppg
5
5
32 %
31 %
30 cP
89.9 F
9
202,378 lbs
3,503 lbs
205,881 lbs
205,881 lbs
69,875 gal 1,664 bbls
7,828 gal 186 bbls
16,025 gal 382 bbls
44,220 gal 1,053 bbls
1,802 gal 43 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Spacer and Ball Drop Volume:
Fluid Summary (by stage description)
Total Proppant Pumped* :
Interval Status:
During the 100 Mesh sand stage and 4 ppg 16/20, rate fluctuated due to mechanical issues on pumps.
100M Pumped:
30# Hybor G Volume:
Pad Volume:
Average Surface Pressure:
Fluid Summary (by fluid description)
Pumps Starting Stage:
Start Date/Time:
Average BH Pressure:
Average Rate:
Wanli 16/20 Ceramic Pumped:
Average Temp:
Average pH:
Proppant in Formation:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Interval Summary
Pad Percentage Actual
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Average Missile HHP:
Max OA Pressure:
Max Proppant Concentration:
Pad Percentage Design
Average Visc:
Pump Time:
3S-617 - Torok - Interval 16
Max Rate:
End Date/Time:
Max BH Pressure:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Pumps Ending Stage:
Max Surface Pressure:
Average Missile Pressure:
Proppant Summary
Willie Martin
Craig Karpinski
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
ConocoPhillipsͲ3SͲ617 IntervalSummary 26
3/12/24 22:36
3/12/24 23:18
42 min
10.1 bpm
3,215 psi
5,296 psi
8 bbl
37.6 bpm
4,189 psi
5,724 psi
34.4 bpm
2,831 psi
2,655 psi
4,400 psi
2,384 hhp
855 psi
914 psi
6.90 ppg
5
5
33 %
31 %
30 cP
93.5 F
9.1
143,709 lbs
3,998 lbs
147,707 lbs
147,707 lbs
54,582 gal 1,300 bbls
1,038 gal 25 bbls
17,002 gal 405 bbls
34,634 gal 825 bbls
1,908 gal 45 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Interval Status:
Average Visc:
Average Temp:
Max OA Pressure:
Average Surface Pressure:
Max Rate:
Initial OA Pressure:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
Pumps Starting Stage:
Average Missile HHP:
Pump Time:
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Pumps Ending Stage:
Pad Percentage Design
Pad Percentage Actual
Average BH Pressure:
Total Proppant Pumped* :
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
During 2 ppg 16/20 rate dropped due to preload pressures. The interval was pumped to completion. Willie Martin
Craig Karpinski
James Campbell
Spacer and Ball Drop Volume:
Start Date/Time:
End Date/Time:
Max Proppant Concentration:
100M Pumped:
Fluid Summary (by fluid description)
Greg Clayton
Average Missile Pressure:
Initial Rate (Breakdown):
Dart/Ball Early :
Wanli 16/20 Ceramic Pumped:
3S-617 - Torok - Interval 17
Interval Summary
Average pH:
Proppant Summary
Average Rate:
Pad Volume:
Proppant in Formation:
30# Hybor G Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
ConocoPhillipsͲ3SͲ617 IntervalSummary 27
3/12/24 23:18
3/13/24 0:28
70 min
10.2 bpm
2,203 psi
4,321 psi
7 bbl
37.3 bpm
3,064 psi
4,703 psi
32.4 bpm
2,686 psi
2,520 psi
4,230 psi
2,135 hhp
842 psi
892 psi
7.95 ppg
5
5
33 %
35 %
29 cP
81.7 F
9
3274 psi
0.628 psi/ft
3202 psi
3167 psi
3135 psi
146,533 lbs
4,559 lbs
153,924 lbs
153,924 lbs
62,058 gal 1,478 bbls
9,137 gal 218 bbls
6,431 gal 153 bbls
3,150 gal 75 bbls
1,244 gal 30 bbls
19,579 gal 466 bbls
32,276 gal 768 bbls
6,431 gal 153 bbls
9,137 gal 218 bbls
3,150 gal 75 bbls
8,959 gal 213 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Proppant Laden Fluid Volume:
Initial OA Pressure:
Max OA Pressure:
Seawater Volume:
Average Missile Pressure:
Fluid Summary (by fluid description)
Total Proppant Pumped* :
Proppant in Formation:
Final 5 min:
Wanli 16/20 Ceramic Pumped:
Establish Stable Fluid Volume:
Final Fracture Gradient:
30# Hybor G Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Flush Volume:
Pad Volume:
Start Date/Time:
Average Surface Pressure:
Fluid Summary (by stage description)
Initial Rate (Breakdown):
Average Rate:
Conditioning Pad Volume:
James Campbell
Displacement Volume:
Greg Clayton
Willie Martin
Craig Karpinski
3S-617 - Torok - Interval 18
Pump Time:
Interval Status:
Freeze Protect Volume:
While seating the ball for interval 18, the ADP stopped mixing gel due to the tachometer sensor falling off
the mixing bowl. After seating the ball the crew shut down until the ADP could be fixed. The interval was
resumed with an Establish Stable Fluid Stage before continuing with 100 Mesh. The interval was pumped to
completion. This was the final interval of the day.
Average Visc:
Max Surface Pressure:
Freeze Protect Volume:
100M Pumped:
Final 15 min:
Final 10 min:
Average BH Pressure:
Pumps Starting Stage:
Pumps Ending Stage:
30# Linear Volume:
Average Missile HHP:
Max Rate:
Max BH Pressure:
Initial Surface Pressure (Breakdown):
End Date/Time:
Dart/Ball Early :
Initial BH Pressure (Breakdown):
Pad Percentage Design
Max Proppant Concentration:
Pad Percentage Actual
Interval Summary
Average Temp:
Average pH:
ISDP:
Proppant Summary
ConocoPhillipsͲ3SͲ617 IntervalSummary 28
3/13/24 21:11
3/13/24 22:48
97 min
10.5 bpm
2,044 psi
3,820 psi
11 bbl
37.6 bpm
3,010 psi
4,453 psi
32.8 bpm
2,461 psi
2,341 psi
4,003 psi
1,975 hhp
381 psi
791 psi
6.76 ppg
5
5
33 %
40 %
32 cP
82.2 F
9
141,034 lbs
4,034 lbs
145,068 lbs
145,068 lbs
79,488 gal 1,893 bbls
10,202 gal 243 bbls
2,100 gal 50 bbls
2,100 gal 50 bbls
6,571 gal 156 bbls
4,703 gal 112 bbls
21,941 gal 522 bbls
34,724 gal 827 bbls
2,887 gal 69 bbls
2,595 gal 62 bbls
16,269 gal 387 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
3S-617 - Torok - Interval 19
Initial Surface Pressure (Breakdown):
Pad Percentage Design
Proppant Summary
Max Proppant Concentration:
Proppant in Formation:
100M Pumped:
Conditioning Pad Volume:
Total Proppant Pumped* :
30# Linear Volume:
Displace Ball to Seat Volume:
Proppant Laden Fluid Volume:
Fluid Summary (by stage description)
Average Missile HHP:
Pumps Ending Stage:
Interval Summary
Average Visc:
Start Date/Time:
End Date/Time:
Dart/Ball Early :
Pumps Starting Stage:
Max Rate:
Initial Rate (Breakdown):
Max BH Pressure:
Average Rate:
Pad Percentage Actual
Max Surface Pressure:
Pump Time:
Initial OA Pressure:
Initial BH Pressure (Breakdown):
Max OA Pressure:
Average Surface Pressure:
30# Hybor G Volume:
Before starting the XL stages of Interval 19, a step rate test was pumped with linear gel. During 5.5 ppg
16/20, sand concetration dropped due to the hopper going dry and the mover hydraulics taking time to
respond and open again. A pump also neutralled due to pre-load pressures. Interval 19 was pumped to
completion.
Willie Martin
Nathan Brzezinski
James Campbell
Fluid Summary (by fluid description)
Pad Volume:
Wanli 16/20 Ceramic Pumped:
Freeze Protect Volume:
Greg Clayton
Average Temp:
Average Missile Pressure:
Average pH:
Average BH Pressure:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Step Rate Test Volume:
Establish Stable Fluid Volume:
Spacer and Ball Drop Volume:
Prime Up Pressure Test Volume:
Interval Status:
ConocoPhillipsͲ3SͲ617 IntervalSummary 29
3/13/24 22:48
3/13/24 23:32
44 min
10.3 bpm
2,556 psi
4,406 psi
4 bbl
37.5 bpm
2,942 psi
4,426 psi
33.3 bpm
2,379 psi
2,256 psi
3,969 psi
1,941 hhp
790 psi
868 psi
6.53 ppg
5
4
33 %
38 %
31 cP
83 F
8.9
132,370 lbs
4,897 lbs
137,267 lbs
137,210 lbs
54,912 gal 1,307 bbls
3,041 gal 72 bbls
19,463 gal 463 bbls
30,757 gal 732 bbls
1,651 gal 39 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
During the first 16/20 sand stages, rate slowly started decreasing due to bad valves on pump 210. That
pump was taken offline and rate gained on the remaining pumps. Interval 20 was pumped as per design.
Interval Status:
Willie Martin
Nathan Brzezinski
Pad Percentage Design
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
Max Surface Pressure:
Pumps Ending Stage:
Average BH Pressure:
Max Proppant Concentration:
Average Visc:
Initial Rate (Breakdown):
James Campbell
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.Greg Clayton
Pumps Starting Stage:
Pump Time:
3S-617 - Torok - Interval 20
Average Temp:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Max OA Pressure:
Pad Percentage Actual
Average Missile HHP:
Initial OA Pressure:
Interval Summary
Start Date/Time:
End Date/Time:
Pad Volume:
Max BH Pressure:
Average Rate:
Average Missile Pressure:
Average Surface Pressure:
Average pH:
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
Proppant Summary
Wanli 16/20 Ceramic Pumped:
100M Pumped:
Total Proppant Pumped* :
Proppant in Formation:
30# Hybor G Volume:
Conditioning Pad Volume:
ConocoPhillipsͲ3SͲ617 IntervalSummary 30
3/13/24 23:32
3/14/24 0:12
40 min
10.8 bpm
1,750 psi
3,749 psi
6 bbl
37.8 bpm
2,715 psi
4,186 psi
35.3 bpm
2,421 psi
2,305 psi
3,966 psi
2,092 hhp
836 psi
914 psi
6.85 ppg
4
4
33 %
32 %
31 cP
83 F
8.9
139,570 lbs
3,180 lbs
142,750 lbs
142,750 lbs
53,403 gal 1,272 bbls
3,223 gal 77 bbls
15,210 gal 362 bbls
33,155 gal 789 bbls
1,815 gal 43 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Total Proppant Pumped* :
30# Hybor G Volume:
During the 100 Mesh stage, CL-28 LA readings became erratic so the decision was made to swap to the
back up LA. Interval 21 was pumped to completion.
3S-617 - Torok - Interval 21
Nathan Brzezinski
James Campbell
Greg Clayton
Interval Status:
Max Surface Pressure:
Average BH Pressure:
Pumps Starting Stage:
Willie Martin
Average Temp:
Average Missile Pressure:
Average Surface Pressure:
Pad Percentage Actual
Average Rate:
Pad Volume:
Max Proppant Concentration:
Pad Percentage Design
Average pH:
Max BH Pressure:
Proppant in Formation:
Initial Rate (Breakdown):
Initial Surface Pressure (Breakdown):
Initial BH Pressure (Breakdown):
Dart/Ball Early :
Max Rate:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Initial OA Pressure:
Max OA Pressure:
100M Pumped:
Average Missile HHP:
Pumps Ending Stage:
Average Visc:
Start Date/Time:
End Date/Time:
Pump Time:
Interval Summary
Proppant Summary
Wanli 16/20 Ceramic Pumped:
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Spacer and Ball Drop Volume:
ConocoPhillipsͲ3SͲ617 IntervalSummary 31
3/14/24 0:12
3/14/24 0:52
40 min
10.4 bpm
3,009 psi
4,727 psi
-4 bbl
37.8 bpm
3,501 psi
5,072 psi
34.6 bpm
2,516 psi
2,401 psi
4,069 psi
2,136 hhp
836 psi
872 psi
7.02 ppg
4
4
33 %
31 %
30 cP
83 F
9
139,399 lbs
3,588 lbs
142,987 lbs
142,987 lbs
51,736 gal 1,232 bbls
2,086 gal 50 bbls
15,050 gal 358 bbls
32,783 gal 781 bbls
1,817 gal 43 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
100M Pumped:
Initial Rate (Breakdown):
Interval Status:
3S-617 - Torok - Interval 22
Proppant Summary
Greg Clayton
Wanli 16/20 Ceramic Pumped:
Max Proppant Concentration:
Initial Surface Pressure (Breakdown):
Pad Percentage Design
Average Visc:
Average Temp:
Initial BH Pressure (Breakdown):
Average pH:
30# Hybor G Volume:
Conditioning Pad Volume:
Interval Summary
Dart/Ball Early :
Average Missile Pressure:
Initial OA Pressure:
Average Surface Pressure:
Max OA Pressure:
Max Surface Pressure:
Average Missile HHP:
Average BH Pressure:
Max BH Pressure:
Max Rate:
Start Date/Time:
End Date/Time:
Pump Time:
Average Rate:
Pad Percentage Actual
Pumps Starting Stage:
Pumps Ending Stage:
Total Proppant Pumped* :
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Pad Volume:
Spacer and Ball Drop Volume:
During 6.0 ppg 16/20, Sand concetration dropped due to having to swap bins on the mover. Interval 22 was
pumped to completion.
Willie Martin
Nathan Brzezinski
James Campbell
Proppant in Formation:
Proppant Laden Fluid Volume:
ConocoPhillipsͲ3SͲ617 IntervalSummary 32
3/14/24 0:52
3/14/24 1:48
56 min
10.3 bpm
2,715 psi
4,743 psi
3 bbl
25.9 bpm
2,948 psi
7 psi
24.4 bpm
1,740 psi
1,670 psi
3,645 psi
1,040 hhp
795 psi
841 psi
7.41 ppg
4
4
33 %
33 %
30 cP
83 F
8.9
140,473 lbs
3,887 lbs
144,360 lbs
144,221 lbs
51,495 gal 1,226 bbls
3,437 gal 82 bbls
15,263 gal 363 bbls
31,227 gal 744 bbls
1,568 gal 37 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Pad Volume:
Proppant in Formation:
30# Hybor G Volume:
Interval 23 was pumped at 25 bpm due to a request from town to try and build net pressure. The interval
was pumped as per design.
Max Proppant Concentration:
Wanli 16/20 Ceramic Pumped:
Average pH:
Average Surface Pressure:
Initial OA Pressure:
Pumps Starting Stage:
Initial BH Pressure (Breakdown):
3S-617 - Torok - Interval 23
Initial Rate (Breakdown):
Start Date/Time:
Average Missile HHP:
Average Visc:
Average Temp:
Total Proppant Pumped* :
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
End Date/Time:
Max BH Pressure:
Average Rate:
Max Surface Pressure:
Interval Summary
Pad Percentage Actual
Initial Surface Pressure (Breakdown):
Max Rate:
Pumps Ending Stage:
Max OA Pressure:
Pad Percentage Design
Average BH Pressure:
Pump Time:
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Dart/Ball Early :
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Spacer and Ball Drop Volume:
100M Pumped:
Average Missile Pressure:
Greg Clayton
Interval Status:
Nathan Brzezinski
Willie Martin
James Campbell
ConocoPhillipsͲ3SͲ617 IntervalSummary 33
3/14/24 1:48
3/14/24 2:29
41 min
10.4 bpm
2,968 psi
4,274 psi
10 bbl
37.5 bpm
2,227 psi
3,635 psi
35.1 bpm
2,015 psi
1,915 psi
3,533 psi
1,733 hhp
762 psi
796 psi
7.69 ppg
4
4
33 %
34 %
31 cP
83 F
9.2
3172 psi
0.604 psi/ft
3103 psi
3070 psi
3037 psi
149,282 lbs
3,834 lbs
153,116 lbs
153,017 lbs
53,051 gal 1,263 bbls
6,567 gal 156 bbls
2,098 gal 50 bbls
17,973 gal 428 bbls
32,980 gal 785 bbls
6,567 gal 156 bbls
Completed
Comments:
Engineer:
Treater:
Supervisor:
Customer Engineer:
Customer Rep:
Average Rate:
Initial Surface Pressure (Breakdown):
Max Rate:
Max BH Pressure:
ISDP:
Dart/Ball Early :
Max Surface Pressure:
Initial BH Pressure (Breakdown):
Average Temp:
Average pH:
Pump Time:
30# Hybor G Volume:
Average Missile HHP:
Max OA Pressure:
Average BH Pressure:
Average Surface Pressure:
30# Linear Volume:
Final 5 min:
Average Missile Pressure:
Initial OA Pressure:
Initial Rate (Breakdown):
Max Proppant Concentration:
Pumps Starting Stage:
Pad Volume:
Proppant in Formation:
Final 15 min:
Wanli 16/20 Ceramic Pumped:
Pumps Ending Stage:
Final Fracture Gradient:
100M Pumped:
Flush Volume:
*Values for proppant are taken from software calculations based on multiple variables.
Proppant is billed off of weight ticket volumes and may vary slightly from this number.
Final 10 min:
Average Visc:
Total Proppant Pumped* :
Conditioning Pad Volume:
Proppant Laden Fluid Volume:
Greg Clayton
Pad Percentage Design
Pad Percentage Actual
Proppant Summary
Fluid Summary (by fluid description)
Fluid Summary (by stage description)
Willie Martin
Nathan Brzezinski
James Campbell
3S-617 - Torok - Interval 24
Interval Summary
Start Date/Time:
End Date/Time:
Interval Status:
Interval 24 was pumped as per design.
ConocoPhillipsͲ3SͲ617 IntervalSummary 34
Customer
Formation
Lease
API
Date
WellSummary
Wanli16/20Ceramic 100M TotalProppant
rfacePress Rate Visc Temp pH rfacePress Rate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs
1 3493 36.0 29 89.4 8.8 4427 37.6 6,4503,5848531,6327533,15075309,2517,363296,7254,031300,756
2 3383 34.1 28 82 9.1 4555 37.6 3,96812,174290178,8384,258294,9053,898298,803
3 3711 35.5 27 75 8.9 5193 37.6 4,64016,3283893,36080214,5595,109302,6852,578305,263
4 3210 30.4 28 79 8.8 3870 37.4 3,01813,13131384020140,7403,351303,4472,576306,023
5 3819 33.3 27 93 8.6 5206 39.4 2,7032,193522,10050117,8272,805303,9105,438309,348
6 3323 30.8 29 83 8.7 5036 37.8 2,29732,05076312,7553041,68040142,9413,403115,6394,226119,865
7 4320 35.5 28 82 8.8 5734 37.8 2,6662,602621,26030115,8272,758302,4413,899306,340
8 3252 36.1 26 79 9.0 3604 37.0 1,87312,2342911,0502591,9302,189164,3014,214168,515
9 4315 33.7 30 52 9.1 5589 38.2 1,99814134,62011088,6812,111202,2894,123206,412
10 3451 34.8 30 67 9.1 4308 37.3 1,70271,4661,702206,5483,266209,814
11 3136 34.2 29 65 9.1 4143 37.9 1,69371,1151,693198,7394,467203,206
12 3534 35.9 27 68 8.9 5124 37.3 1,68111,2842692,7306584,6182,015198,9024,635203,537
13 2989 34.9 30 66 9.0 3582 37.5 2,1114141010,7792577,350175107,2222,553202,8833,484206,367
14 3107 34.4 29 74 9.0 4301 37.5 1,67370,2691,673202,1313,748205,879
15 2735 32.6 29 71 9.1 3481 37.8 2,749128310,1302414,200100129,9223,093212,9793,997216,976
16 2707 33.6 30 90 9.0 4110 37.7 1,66469,8751,664202,3783,503205,881
17 2655 34.4 30 94 9.1 4189 37.6 1,30054,5821,300143,7093,998147,707
18 2520 32.4 29 82 9.0 3064 37.3 1,4789,1372186,4311533,1507587,5512,085146,5334,559153,924
19 2341 32.8 32 82 9.0 3010 37.6 1,89310,2022432,1005091,7902,185141,0344,034145,068
20 2256 33.3 31 83 8.9 2942 37.5 1,30754,9121,307132,3704,897137,267
21 2305 35.3 31 83 8.9 2715 37.8 1,27253,4031,272139,5703,180142,750
22 2401 34.6 30 83 9.0 3501 37.8 1,23251,7361,232139,3993,588142,987
23 1670 24.4 30 83 8.9 2948 25.9 1,22651,4951,226140,4733,887144,360
24 1915 35.1 31 83 9.2 2227 37.5 1,2636,56715659,6181,419149,2823,834153,116
Minimum 122612836431153840205149512261156392576119865
Average 224488112101434534228926910459024902018033919205840
Maximum 64503205076331632753735017530925173633039105438309348
Wanli16/20Ceramic 100M TotalProppant
Pressure Rate Visc Temp pH Pressure Rate bbl gal bbl gal bbl gal bbl gal bbl lbs lbs Total
Planned 51,709 133,109 3,169 63,885 1,521 22,220 529 2,391,000 56,929 4,833,400 96,000 4,929,400
Recorded 3579 34.2 28 76 8.91 5734 39.4 53,855 132,169 3,147 71,727 1,708 37,590 895 2,510,168 59,766 4,843,272 94,060 4,940,164
WeightTickets 4,948,809 111,000 5,059,809
**ProppantisbilledfromWeightTicketvolumes
February26,2024
50Ͳ103Ͳ20864
3SͲ617
Torok
ConocoPhillips
Interval Average Max Seawater
Average Max Seawater30#HyborG 30#Linear
30#HyborG 30#Linear
**IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedon
TotalFluid
Fluids Proppants
Fluids Proppants
TotalFluid
FreezeProtect
FreezeProtect
ConocoPhillipsͲ3SͲ617 FluidSystemͲProppantSummary 35
Hydraulic Fracturing Fluid Product Component Information Disclosure
2024-01-20
Alaska
HARRISON BAY
50-103-20864
CONOCOPHILLIPS
3S 617
-150.1934
70.3941
NAD83
none
Oil
5263
2465803
Hydraulic Fracturing Fluid Composition:
Trade Name Supplier Purpose Ingredients
Chemical
Abstract
Service
Number
(CAS #)
Maximum Ingredient
Concentration in
Additive (% by mass)**
Maximum
Ingredient
Concentration in
HF Fluid (% by
mass)**
Ingredient Mass
lbs Comments Company First Name Last Name Email Phone
SEAWATER (SG
8.52) Halliburton Base Fluid Water 7732-18-5 100.00%80.09505%21008642 Density = 8.52 Halliburton
BE-6(TM)
Bactericide Halliburton Microbiocide Listed Below Listed Below 0
CAT-3
ACTIVATOR Halliburton Activator Listed Below Listed Below 0
CL-28M
CROSSLINKER Halliburton Crosslinker Listed Below Listed Below 0
LoSurf-300D Halliburton Non-ionic Surfactant Listed Below Listed Below 0 NA
MO-67 Halliburton pH Control Listed Below Listed Below 0
OPTIFLO-II
DELAYED
RELEASE
BREAKER Halliburton Breaker Listed Below Listed Below 0
OPTIFLO-III
DELAYED
RELEASE
BREAKER Halliburton Breaker Listed Below Listed Below 0
WG-36 GELLING
AGENT Halliburton Gelling Agent Listed Below Listed Below 0
Ceramic
Proppant - Wanli Wanli Proppant Listed Below Listed Below 0 NA
SAND, COMMON
BROWN 100
MESH Halliburton Proppant Listed Below Listed Below 0 NA
Ingredients
Listed
Above Listed Above 0.00%0.00000%0
1,2,4 Trimethylbenzene 95-63-6 1.00%0.00073%193
2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00140%366
2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00002%6
5-Chloro-2-methyl-3(2H)-
Isothaiazolone 26172-55-4 0.01%0.00002%6
Ammonia 7664-41-7 1.00%0.00009%24
Ammonium chloride 12125-02-9 5.00%0.00046%120
Ammonium persulfate 7727-54-0 100.00%0.02284%5990
Borate salts Proprietary 60.00%0.11662%30589
Denise Tuck,
Halliburton, 3000
N. Sam Houston
Pkwy E.,
Houston, TX
77032, 281-871-
6226 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
C.I. pigment Orange 5 3468-63-1 1.00%0.00005%13
Calcium magnesium carbonate 16389-88-1 1.00%0.00194%510
Corundum 1302-74-5 65.00%12.26371%3216726
Crystalline silica, quartz 14808-60-7 100.00%0.42924%112588
EDTA/Copper chelate Proprietary 30.00%0.00274%719 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Ethanol 64-17-5 60.00%0.04400%11542
Gluteraldehyde 111-30-8 1.00%0.00194%510
Guar gum 9000-30-0 100.00%0.27039%70923
Heavy aromatic petroleum
naphtha 64742-94-5 30.00%0.02200%5771
Inorganic mineral 1317-65-3 5.00%0.00972%2550
Inorganic mineral Proprietary 1.00%0.00194%510 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Magensium chloride 7786-30-3 0.01%0.00002%6
Magnesium nitrate 10377-60-3 0.01%0.00002%6
Methanesulfonic acid, 1-hydroxy-,
sodium salt 870-72-4 0.10%0.00019%51
Mullite 1302-93-8 45.00%8.49026%2226965
Naphthalene 91-20-3 5.00%0.00367%962
Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02200%5771 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxyalkylated phenolic resin Proprietary 10.00%0.00733%1924 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Oxylated phenolic resin Proprietary 30.00%0.00685%1797 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Poly(oxy-1,2-ethanediyl), alpha-(4-
nonylphenyl)-omega-hydroxy-,
branched 127087-87-0 5.00%0.00367%962
Polymer Proprietary 1.00%0.00194%510 Halliburton Denise Tuck
Denise.Tuck
@Halliburton.
com 281-871-6226
Potassium chloride 7447-40-7 5.00%0.00972%2550
Sodium bisulfate 7681-38-1 0.10%0.00019%51
Sodium chloride 7647-14-5 5.00%4.00518%1050546
Sodium hydroxide 1310-73-2 30.00%0.01292%3390
Water 7732-18-5 100.00%0.16882%44282
* Total Water Volume sources may include fresh water, produced water, and/or recycled water _
** Information is based on the maximum potential for concentration and thus the total may be over 100%
Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.3
Allcomponentinformationlistedwasobtainedfromthesupplier’sMaterialSafetyDataSheets(MSDS).Assuch,theOperatorisnotresponsibleforinaccurateand/orincompleteinformation.AnyquestionsregardingthecontentoftheMSDSshouldbedirectedtothesupplier
whoprovidedit.TheOccupationalSafetyandHealthAdministration’s(OSHA)regulationsgovernthecriteriaforthedisclosureofthisinformation.PleasenotethatFederalLawprotects"proprietary","tradesecret",and"confidentialbusinessinformation"andthecriteriaforhow
thisinformationisreportedonanMSDSissubjectto29CFR1910.1200(i)andAppendixD.
Production Type:
True Vertical Depth (TVD):
Total Water Volume (gal)*:
MSDS and Non-MSDS Ingredients are listed below the green line
Well Name and Number:
Longitude:
Latitude:
Long/Lat Projection:
Indian/Federal:
Fracture Date
State:
County:
API Number:
Operator Name:
Page 1/2
Procedure Closeout
3S-617
Primary Job Type
INITIAL COMPLETION
Start Date
2/23/2024
End Date Final Job Status
IN PROGRESS
Total Time Log Hours (hr)
545.79
Summary
Network/Order Number Project Desc Estimator
10441026 3S-617 - Frac - Frac
Start Date ZX Code Time Log Hrs (hr)
Cum Time Log
(days)Last 24hr Sum
2/23/2024 ZX02 Fracturing 17.99 0.75 Loaded up CVA, PUBO and iron from around the well. Rigged up treating line across the back of the well row and up to the pipe rack.
Lowered castle 014 and spotted/leveled the besser in its place. Packed up the chem trailer to take back to Deadhorse to reload. Worked on
function testing, preventative maintained and cleaning LA’s.
2/24/2024 ZX02 Fracturing 23.99 1.75 -Finished rigging up the treating line to the well head. Spotted the Acid pump.Loaded the Nofreeze chem trailer with CL28M and CAT 3 and
spotted it on location. Night shift will be loading a soft side with Losurf and MO and spotting the unit on location.
-Lynden loaded 2nd Sand Chief with sand.
-Certek rigged up boiler and heate exchangers to Water tank manifold.
2/25/2024 ZX02 Fracturing 23.99 2.75 Hal - Rigged up the IA and OA transducers and Lotorcs, Rigged up the acid pump to the ball launch line, Ran transducer, wellhead mic, and
DH gauge cables, Fired up equipment and checked communication with the TCC, Fired up the bessers and test the belts.
Lynden - Continued staging sand on location
Certek - Got unit running around 4:00 pm & started heating water & loading tanks through the night.
2/26/2024 ZX02 Fracturing 23.99 3.75 SHEAR ALPHA SLEEVE @ 5880 PSI. PUMP DFIT. BEGIN PUMPING STAGE #1. DURING PAD NOTICE OA PRESSURE STARTING TO
THERMAL UP. RU HOSE TO BLEED DOWN AND SEE PRESSURE RISE QUICKLY TO 1620 PSI & DROP OFF. DECIDE TO FLUSH
WELL WHILE BLEEDING DOWN OA. ATTEMPT TO RE-PUMP STAGE #1 & SEE MORE OA PRESSURE SPIKE & FLUSH WELL.
DETERMINE OA CABLE & TRANSDUCER WERE LIKELY THE ISSUE. IN PROGRESS
2/27/2024 ZX02 Fracturing 23.99 4.75 STIMULATE STAGES 1 & 2 PER DESIGN **STAGE #2 PRIMARY BALL DID NOT SEAT & HAD DROP BACK UP BALL TO OPEN
SLEEVE**. OPENED STAGE #3 SLEEVE & PUMP MINI FRAC. TOTAL PROPPANT PUMPED = 599,559 LBS & TOTAL CLEAN VOLUME
= 11,621 BBLS. IN PROGRESS
2/28/2024 ZX02 Fracturing 23.99 5.75 RELOAD & HEAT WATER THROUGH THE NIGHT. SWAP OUT CERTEK HEATER FOR LYNDEN HEATER. HALLIBURTON CREWS
CHANGED OUT. FUNCTION TEST EQUIPMENT IN PREPERATION TO PUMP IN THE MORNING.
2/29/2024 ZX02 Fracturing 23.99 6.75 DROP STAGE #3 BACKUP BALL TO ISOLATE STAGE #2. STIMULATE STAGE #3 PER DESIGN. DROP STAGE #4 BALL, GOOD SEAT.
STIMULATE STAGE #4 PER DESIGN (HAD TO DROP RATE DURING STAGE DUE 2 PUMPS GOING DOWN). TOTAL PROPPANT
PUMPED = 611,286 LBS & TOTAL CLEAN VOLUME = 8060 BBLS. IN PROGRESS
3/1/2024 ZX02 Fracturing 23.99 7.75 STIMULATE STAGE #5 PER DESIGN w/ TOTAL OF 309,348 LBS OF PROPPANT & CLEAN VOL OF 2574 BBLS. DROPPED BALL FOR
STAGE #6 & PUMPED MINI FRAC & SRT. COME BACK ONLINE & BEGIN PUMPING STAGE #6. HAD TO FLUSH EARLY CUTTING
THE STAGE PROPPANT SHORT DUE TO BLENDER CPU SHUTTING DOWN AND UNABLE TO GET THE REQUIRED CL-28 (X-LINK)
FOR THE STAGE TO FLOW OUT OF THE CHEMICAL TOTE BECAUSE IT WAS TO COLD & THICK. PUMPED 120,113 LBS OF THE
INTENDED DESIGN VOLUME OF 300,000 LBS. IN PROGRESS
3/2/2024 ZX02 Fracturing 23.99 8.75 STIMULATE STAGE #7 PER DESIGN w/ 306,340 LBS OF 16/20 PROPPANT & 2758 BBLS CLEAN VOLUME. LAUNCHED STAGE #8
BALL. DURING 5.5 PPG SAND STAGE A SHARP PRESSURE DECREASE WAS OBSERVED ON SURFACE & DOWNHOLE. GROUND
BOSS CALLED FOR A SHUT DOWN DUE TO A LEAK TREATING LINE JUST AFTER THE MISSILE. THE WELL WAS SHUT IN & THE
WASHED OUT IRON WAS REPLACED & THE WELL WAS FLUSHED WITH LINEAR GEL TO STAGE #8 SLEEVE. PUMPED 168,515
OF 304,000 DESIGN & 2164 BBLS OF CLEAN FLUID. IN PROGRESS
3/3/2024 ZX02 Fracturing 23.99 9.75 INSPECT 4" TREATING LINE FROM THE MISSILE TO THE WELLHEAD. FOUND 15 WASHED CHIX & 6 STRAIGHT JOINTS
PROCEEDING A CHIX WERE ALSO WASHED AND TAKEN OUT OF SERVICE. IN PROGRESS
3/4/2024 ZX02 Fracturing 23.99 10.75 HALLIBURTON - CREW WENT TO DEADHORSE TO GATHER UP 4" IRON TO RIG UP SECOND TREATING LINE FROM MISSILE TO
THE WELL.
LOIL - FINISHED LOADING & HEATING WATER.
3/5/2024 ZX02 Fracturing 23.99 11.75 HALLIBURTON - RIGGED UP TWO 4" TREATING LINES FROM THE MISSILE TO THE WELLHEAD WITH 2 STAND PIPES (TOTAL OF
1300' OF 4" IRON)
LOIL - INSTALL RESTRAINTS ON NIGHT SHIFT
Page 2/2
Procedure Closeout
3S-617
Start Date ZX Code Time Log Hrs (hr)
Cum Time Log
(days)Last 24hr Sum
3/6/2024 ZX02 Fracturing 23.99 12.74 PRESSURE TEST TREATING LINE TO 9000 PSI **PASS**. RIG DOWN BALL LAUNCH EQUIPMENT & STAND BY FOR D142 TO MOVE
TO THEIR NEXT WELL. UNABLE TO PUMP DUE TO RIG MOVE ISSUES. PREP EQUIPMENT FOR AM START. IN PROGRESS
3/7/2024 ZX02 Fracturing 23.99 13.74 DELAYED START DUE RIG MOVE & EQUIPMENT ISSUES IN -30* TEMPS. STIMULATE STAGES 9 -12 PER DESIGN. TOTAL
PROPPANT PUMPED = 822,969 LBS & TOTAL CLEAN VOLUME = 7453 BBLS. IN PROGRESS
3/8/2024 ZX02 Fracturing 23.99 14.74 LAUNCHED STAGE #13 BALL. DURING BALL DISPLACEMENT DISCOVER ENGINE OIL COMING OUT OF THE REAR MAIN SEAL ON
ADP / GEL UNIT. SEAT BALL & SHIFT SLEEVE. FLUSH THE WELL. WORK ON RIGGING OUT ADP IN PREPERATION TO SWAP IT
OUT WITH A BACK UP UNIT IN DEADHORSE. IN PROGRESS
3/9/2024 ZX02 Fracturing 23.99 15.74 STIMULATE STAGES 13 & 14 PER DESIGN w/ TOTAL PROPPANT PUMPED = 410,246 LBS & TOTAL CLEAN VOLUME = 6215 BBLS.
LAUNCH STAGE #15 BALL AND OPEN FRAC SLEEVE. DURING 2 PPG SAND STAGE SAW PUMP RATE SPIKE & DISCOVER LEAK
AT A WELD ON A DISCHARGE PORT ON THE LOW PRESSURE SIDE OF THE MISSILE. SHUT DOWN PUMPS & RIG UP 3 PUMPS
ON OPPOSITE SIDE OF THE MISSILE AND FLUSH THE WELL. IN PROGRESS
3/10/2024 ZX02 Fracturing 23.99 16.74 NIGHT CREWS FINISHED LOADING AND HEATING WATER TANKS. STAND BY FOR -35 DEGREE WEATHER.
3/11/2024 ZX02 Fracturing 23.99 17.74 STAND BY FOR COLD WEATHER IN EXCESS OF -35 DEGREES
3/12/2024 ZX02 Fracturing 26.00 18.83 DELAYED START DUE TO COLD WEATHER IN EXCESS OF -35 DEGREES. REPLACED DAMAGED MISSILE WITH A NEW UNIT.
STIMULATE STAGES #15 - #18. PUMPED 717,097 LBS OF PROPPANT & 7806 BBLS OF CLEAN FLUID. IN PROGRESS
3/13/2024 ZX02 Fracturing 28.00 19.99 STIMULATE FINAL 6 STAGES #19 - #24. TOTAL 16/20 PROPPANT PUMPED = 865,548 & CLEAN FLUID = 8592 BBLS. FRAC
COMPLETE & BEGIN RIGGING DOWN.
3/14/2024 ZX02 Fracturing 17.99 20.74 STAND BY FOR COLD WEATHER IN EXCESS OF -35 DEGREES
3/15/2024 ZX02 Fracturing 23.99 21.74 RESUMED RIG DOWN PROCESS
3/16/2024 ZX02 Fracturing 23.99 22.74 CONTINUED RIGGING DOWN
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1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name:4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?KRU 3S-617
Yes No
9. Property Designation (Lease Number):10. Field:
Kuparuk F Torok Oil Pool
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
Casing Collapse
Structural
Conductor
Surface 2470
Intermediate 4790
Production 7850
Liner 9210
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Baskoro Tejo
Contact Email:Baskoro.Tejo@cop.com
Contact Phone: 907-265-6462
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
11590
Tubing Grade:Tubing MD (ft):
TNT Packer: 8020' MD/ 5027' TVD
SLZXP: 8331' MD/ 5130' TVD
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL380107 / ADL380106 / ADL025528 / ADL393883
223-085
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-103-20864-00-00
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
L-80
TVD Burst
8157/ 5075 TVD (ft)
10860
MD
6890
5210
97
2551
4796
97
2778
51307-5/8"
20"
10-3/4"
97
7-5/8"7489
2778
8331
Perforation Depth MD (ft):
7489
842
4-1/2"
25-Feb-24
2124013092
4-1/2"
5162
Halliburton TNT Production Packer
Baker SLZXP Liner Packer, no SSSV
m
n
P
2
6
5
6
t
_
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Feb 13, 2024
By Grace Christianson at 8:50 am, Feb 13, 2024
324-078
A.Dewhurst 21FEB24
X
VTL 02/21/2024 DSR-2/13/24
X 10-404
CDW 02/21/2024
*&:JLC 2/22/2024
Brett W. Huber, Sr.
Digitally signed by Brett W. Huber,
Sr.
Date: 2024.02.23 08:47:16 -09'00'02/23/24
RBDMS JSB 022324
Section 1 - Affidavit 10 AAC 25.283 (a)(1)
Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators
within one-half mile radius of the current or proposed wellbore trajectory have been provided
notice of operations in compliance with 20 AAC 25.283(a)(1).
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Section 2 – Plat 20 AAC 25.283 (2)(A)
Plat 1: Wells within 1/2 mile
Superseded by updated plat. -A.Dewhurst 21FEB24
Table 1: Wells within 1/2 miles (2)(C)
Table 1: Wells within 1/2 miles (2)(C)
Superseded by updated well list. -A.Dewhurst 21FEB24
SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3)
There are no freshwater aquifers or underground sources of drinking water within a one-half
mile radius of the current or proposed wellbore trajectory.
None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), “That portions of the aquifers on
the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk
River Unit oil and gas producing field”.
SECTION 4 – PLAN FOR BASELINE WATER SAMPLING FOR
WATER WELLS 20 AAC 25.283(a)(4)
There are no water wells located within one-half mile of the current or proposed wellbore
trajectory and fracturing interval.
A water well sampling plan is not applicable.
SECTION 5 – DETAILED CEMENTING AND CASING INFORMATION
20 AAC 25.283(a)(5)
All casing is cemented and tested in accordance with 20 AAC 25.030.
See Wellbore schematic for casing details.
Top Coyote@ 5,909' MD / 4,087' TVD
3S-617 Horizontal Moraine Injector
10-¾" 45.5# L80 H563 2,778’ MD / 2,551' TVD 43° Inc
Conductor: 97'
4-½" 12.6# P110S H563 21,240' MD / 5,162' TVD 90° Inc
Tubing: 4-½”12.6#, L-80, Hydril 5639-и" Intermediate Hole
6-1/2" Production Hole
13-½" Surface Hole
7-з" 29.7# L80 H563 to 7489'
7-з" 33.7# P110S H563 @8331' MD / 5130' TVD 72° Inc
Updated: 12/07/23 by 142 Ops Eng
4-½” x 6-1/8" Swell Packer Frac sleeve (ball drop)
Sp
u
d
M
u
d
3.562", DB Nipple @ 8,086' MD / 5,051' TVD
FlexLock/ZXP, Liner Top Packer, Hanger 8,148' MD / 5,072’ TVD
4-½” x 7-з " TNT Packer @ 8,020' MD / 5,027' TVD
TOC @ 3,841’ MD / 3,155’ TVD (932' TVD above hydrocarbon bearing zone)
Downhole Gauge @ 7,956' MD / 5,002' TVD
Top Torok Oil Pool (Moraine) @ 8,419 MD / 5,168' TVD
Gas Lift Mandrel, 4-½” x 1” @ 1,985' MD / 1922' TVD
Wellbore Isolation Valve / Alpha Sleeve
Gas Lift Mandrel, 4-½” x 1” @ 7,849' MD / 4,958' TVD
6-½” TD 21,276' MD / 5,162' TVD 90° Inc
SECTION 6 – ASSESSMENT OF EACH CASING AND CEMENTING
OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE
WELL 20 AAC 25.283(a)(6)
Casing & Cement Assessments:
10 & 3/4” casing cement pump report on10/29/2023 shows that the original job pumped as
designed. The cement job was pumped with 447 barrels of 10.7 ppg lead cement and 57
barrels 15.8 ppg tail cement, displaced with 9.8 ppg mud. The plug was bumped and the floats
held. Cement returns came to surface.
The 7 & 5/8” casing cement report on 11/5/2023 shows that the job was pumped as designed,
indicating competent cementing operations. The cement job was pumped with 142 barrels of
15.3 ppg. The plug was not bumped. Pressure was being monitored and no pressure built up
indicating that the floats held. A cement bond log indicates competent cement with a cement
top @ 3,841’ MD (3,157’ TVD).
Summary
All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone
penetrated by the well is isolated.
Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has
determined that this well can be successfully fractured within its design limits.
g
3,841’ MD (3,157’TVD).
SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST
CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7)
On 10/30/2023 the 10-3/4” casing was pressure tested to 3,000 psi for 30 minutes
On 11/7/2023 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes.
On 12/7/2023 the 4-1/2” tubing was pressure tested to 4,550 psi. Good Test
On 12/7/2023 the 7-5/8” casing by 4.5 tubing annulus was pressure tested to 3,850 psi. Good
Test
AOGCC Required Pressures [all in psi]
Maximum Predicted Treating Pressure (MPTP) 7,550
Annulus pressure during frac 3,500
Annulus PRV setpoint during frac 3,600
7-5/8" Annulus pressure test 3,850
4-1/2" Tubing pressure Test 4,550
Electronic PRV 8,550
Highest pump trip 8,050
SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE,
WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8)
Size Weight, ppf Grade API Burst, psi API Collapse, psi
10 & 3/4” 45.5 L-80 5,209 2474
7 & 5/8” 29.7 L-80 6,885 4,789
7 & 5/8” 33.7 P-110 10,860 7,870
4.5” 12.6 L-80 8,430 7,500 Table 2: Wellbore pressure ratings
Stimulation Surface Rig-Up
Kuparuk 10K Frac Tree
SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING
ZONES 20 AAC 25.283(a)(9)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that:
The fracturing zone, the Torok Oil Pool, has an average thickness of approximately 255 ft TVD
over the course of the lateral section of well 3S-617, from where it intersects the top formation
at 8,432’ MD to TD of the well. The Torok Oil Pool is comprised of thinly interbedded sandstone,
siltstone, and silty shale layers. The sandstone and siltstone components are litharenites,
moderately to well sorted, and very fine grained. The silty shales are composed of clay-rich,
moderately to poorly sorted silt and clay. The estimated fracture pressure for the Moraine
interval is approximately 12.5-13.5 ppg.
The overlying confining interval of the Torok Formation consists of mudstones and siltstones
with an average thickness of approximately 840’ TVD. The top of the Torok confining intervals
starts at 4,462’ TVDSS (6,865’ MD). The estimated fracture gradient of the overlying Torok
formation is approximately 0.82 psi/ft.
The underlying confining zone below the Base Moraine consists of lower Torok, HRZ, and
Kalubik shales totaling approximately 500’ TVD. The estimated fracture gradient for this section
ranges from 15-18 ppg, with the gradient increasing down section. The Base Moraine is
estimated from seismic to be at 5,285 ft TVDSS at the heel, and 5,250’ ft TVDSS at the toe of
the well.
The estimated formation pressure within the Torok Oil Pool is 2285psi at a depth of 5200’
TVDSS.
SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
ConocoPhillips has formed the opinion, based on following assessments for each well and
seismic, well, and other subsurface information currently available that none of these wells will
interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the
proposed wellbore trajectory.
Casing & Cement assessments for all wells that transect the confining zone:
NDST-02 The well is currently shut in and will be suspended waiting for rig assisted workover
that is scheduled in May 2024. Per the latest intervention status, the wellbore fluid is a mix of
freeze protect fluid, seawater, and formation fluid. The schematic shows 7-5/8” casing top of
cement is at 8,672’ MD/ 4,842’ TVD and top of Torok Oil Pool is at 10,155’ MD/ 5,023’ TVD.
The open interval of NDST-02 is at the toe. It is located outside the ½ mile radius of open ports
at 3S-617.
NDST-02PB1: The wellbore is a pilot hole drilled, plugged, and abandoned prior to drilling
NDST-02 wellbore.
3S-624: The 7-5/8” casing cement report on 12/24/2023 shows that the job was pumped as
designed, indicating competent cementing operations. 123 barrels of 15.3 ppg primary cement
was pumped with LCM. This was then chased with 22 barrels of 15.3 ppg primary cement
without LCM, the top plug was dropped. The plug bumped, pressured up to 1824 psi and held
for 5 min. Floats were checked and they held.
3S-15: This well is targeting Kuparuk formation. The well is completely plugged and abandoned
per state regulations on 9/8/2020. Per Form 10-407 report on the AOGCC website, casing was
cemented with TOC at 297’ MD based on observation from THA (Tubing Head Adapter). Top
cement job was performed to surface on 8/30/2020.
Source: 202-254 - Laserfiche WebLink (state.ak.us)
3S-17: This well is targeting Kuparuk formation. The well is completely plugged back per state
regulations on Jun 13, 2003. Plug was set from the bottom of the hole and an additional 100’
of cement was placed above the Kuparuk C sand to ensure isolation.
Source: 203-015 - Laserfiche WebLink (state.ak.us)
3S-17A: This well is targeting Kuparuk formation. The well is completely plugged and
abandoned per state regulations on 9/25/2023. Top of cement was tagged with wireline at
5513’ MD on 7/9/2023. P&A works were performed to pump cement to surface on 9/18/2023.
Source: 203-080 - Laserfiche WebLink (state.ak.us)
SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON
MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT
CONFINING ZONE 20 AAC 25.283(a)(10)
ConocoPhillips has formed the opinion, based on following assessments for each well and
seismic, well, and other subsurface information currently available that none of these wells will
interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the
proposed wellbore trajectory.
Casing & Cement assessments for all wells that transect the confining zone:
3S-611: The 7-5/8” casing cement report on 10/13/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.4 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-612: The 7-5/8” casing cement report on 11/4/2018 shows that the job was pumped as
designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before
dropping bottom plug, this was then chased with 15.8 ppg Class G cement and the top plug
was dropped. This was chased with 9.5 ppg LSND mud. The plug bumped, pressured up to
1500 psi and held for 5 min. Floats were checked and they held.
3S-06: The well is completely plugged and abandoned per state regulations on 10/16/2023.
Per P&A report, 7” production casing was cemented by Coiled Tubing Unit from 5575’ MD to
surface on 9/30/2023.
3S-15: The well is completely plugged and abandoned per state regulations on 9/8/2020. Per
Form 10-407 report on the AOGCC website, casing was cemented with TOC at 297’ MD based
on observation from THA (Tubing Head Adapter). Top cement job was performed to surface
on 8/30/2020.
Source: 202-254 - Laserfiche WebLink (state.ak.us)
3S-17: The well is completely plugged back per state regulations on Jun 13, 2003. Plug was
set from the bottom of the hole and an additional 100’ of cement was placed above the Kuparuk
C sand to ensure isolation.
Source: 203-015 - Laserfiche WebLink (state.ak.us)
3S-17A: The well is completely plugged and abandoned per state regulations on 9/25/2023.
Top of cement was tagged with wireline at 5513’ MD on 7/9/2023. P&A works were performed
to pump cement to surface on 9/18/2023.
Source: 203-080 - Laserfiche WebLink (state.ak.us)
Superseded by updated report. -A.Dewhurst 21FEB24
SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL
DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE
CONFINING ZONES 20 AAC 25.283(a)(11)
CPAI has formed the opinion, based on seismic, well, and other subsurface information
currently available that a single fault transects the Torok Oil Pool reservoir within one half mile
radius of the 3S-617 wellbore trajectory. While the fault doesn’t intersect the 3S-617 or any
other nearby well trajectories, it is interpreted to have offset the toe section of the 3S-617 well
downwards by about 40ft. The fault trace has been mapped on seismic to run wellbore-parallel
between the 3S-617 and 3S-624 trajectories, as shown in Plat xxx. It is interpreted to not affect
overburden integrity and therefore its presence will not interfere with containment.
If there is any indication that a fracture has intersected the mapped fault (or any other faults
unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate
the stage immediately.
SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM
20 AAC 25.283(a)(12)
3S-617 was completed in 2023 as a horizontal injector in the Torok formation. The well was
completed with a 4.5” tubing upper completion and a 4.5” liner with a ball actuated sliding
sleeve lower completion. The first stage will be pumped through a toe initiator valve in the toe
of the lateral. After the 1st stage frac balls will be dropped to shift open the 2nd stage sleeve and
isolate the first stage. The 2nd stage will then be pumped and a third ball drop (progressively
getting larger) after each remaining stage, these balls will provide isolation from the previous
stage and allow fracturing from the toe of the well towards the heel.
Proposed Procedure:
Halliburton Pumping Services:
1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition
to identify any pre existing conditions.
2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus
are filled with a freeze protect fluid to 2,000’ TVD.
3. Pressure test the rig installed frac tree to 10,000 psi.
4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC.
5. MIRU 30 clean insulated Frac tanks, with a berm surrounding the tanks that can hold
a single tank volume plus 10%. Load tanks with 100º F seawater (approx. 2,200
barrels are required for each stage with breakdown, maximum pad and pumping
down the next ball. (450 bbls usable volume per tank).
6. MIRU HES Frac Equipment.
7. PT Surface lines to 10,000 psi using a Pressure test fluid.
8. Test IA Pop off system to ensure lines are clear and all components are functioning
properly.
9. Bring up pumps and increase annulus pressure to 3,500 psi as the tubing pressures
up.
10. Pump the 300 bbl breakdown stage (30# Hybor G) according to the attached excel
HES pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as
possible, pressure permitting. Ensure sufficient volume is pumped to load the well
with Frac fluid, prior to shut down.
11. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates.
12. Pump the 24 stage Frac job by following attached HES schedule @ ~37bpm with a
maximum expected treating pressure of 7,550 psi.
13. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to
complete following the flush.
14. Well is ready for Post Frac well prep/production tree installation and flowback
(Slickline and CTU clean out).
SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID
RECOVERY PLAN 20 AAC 25.283(a)(13)
Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will
be turned over to production for initial clean up production.
20
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1
Dewhurst, Andrew D (OGC)
From:Tejo, Baskoro <Baskoro.Tejo@conocophillips.com>
Sent:Tuesday, February 20, 2024 16:51
To:Dewhurst, Andrew D (OGC)
Cc:Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Wallace, Chris D (OGC); Roby, David S
(OGC); Hobbs, Greg S; Simek, Jill; Metzgar, Kyle N
Subject:RE: [EXTERNAL]KRU 3S-617 Frac Sundry (PTD 223-085; Sundry 324-078): Questions
Attachments:Section 10 - Page 18.pdf; Section 2 - Page 7-8.pdf
Good afternoon Andy,
Please Ʊnd attached the revised Section 2 and Section 10 of the sundry application.
For quesƟon #3, we re-evaluated the 7” CBL log data. The log was run from 7650 ŌMD to 8202 ŌMD. The eīecƟve top of
the CBL was 7807 ŌMD where the WLEG was entered. Top of quality cement is conĮrmed at 8130 ŌMD, above this poor
cement distribuƟon seen to the WLEG. We have no data to evaluate cement coverage across the Moraine and Coyote
intervals. However, given the verƟcal and longitudinal orienta Ɵon of our planned sƟmulaƟon operaƟons in both zones,
the hydraulic fractures will not intersect the 3S-15 well in either the Moraine or Coyote sands.
Thank you,
Baskoro Tejo
Staff Completion Engineer | Wells Department | ConocoPhillips Alaska
ATO 1580 - 700 G Street, Anchorage, AK, 99501
Ofϐice : +1 907 265 6462
Mobile : +1 907 250 9724
Email : Baskoro.Tejo@conocophillips.com
From: Tejo, Baskoro <Baskoro.Tejo@conocophillips.com>
Sent: Monday, February 19, 2024 18:30
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S
(OGC) <dave.roby@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Simek, Jill
<Jill.Simek@conocophillips.com >
Subject: RE: [EXTERNAL]KRU 3S-617 Frac Sundry (PTD 223-085; Sundry 324-078): Questions
Good evening Andy,
With the updated Lease Plat map and the summary table of wells within ½ mile buƯer, it appears that:
1. 3S-611, 3S-612, and 3S-06 are not within the ½ mile radius of the completed interval of 3S-617.
2. NDST-02, NDST-02PB1, and the recently drilled 3S-624 are within the half-mile radius and will be included
in Section 10 of the application.
3. 3S-15 will be updated on Section 10 to address your note.
You don't often get email from baskoro.tejo@conocophillips.com. Learn why this is important
You don't often get email from baskoro.tejo@conocophillips.com. Learn why this is important
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
2
My plan is to revise the frac sundry document reƲecting the updates of wells on Section 10 and to resubmit it
through the aogcc.permitting@alaska.gov. Please advise if you think of another way to address this.
Thank you,
Baskoro Tejo
Staff Completion Engineer | Wells Department | ConocoPhillips Alaska
ATO 1580 - 700 G Street, Anchorage, AK, 99501
Ofϐice : +1 907 265 6462
Mobile : +1 907 250 9724
Email : Baskoro.Tejo@conocophillips.com
From: Tejo, Baskoro
Sent: Friday, February 16, 2024 3:49 PM
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S
(OGC) <dave.roby@alaska.gov>
Subject: RE: [EXTERNAL]KRU 3S-617 Frac Sundry (PTD 223-085; Sundry 324-078): Questions
Andy,
Thank you for your questions. Let me reconƱrm your notes to the respective functions who can provide me
accurate answers. I will get back to you on Monday at the latest.
Have a great weekend,
Baskoro
Baskoro Tejo
Staff Completion Engineer | Wells Department | ConocoPhillips Alaska
ATO 1580 - 700 G Street, Anchorage, AK, 99501
Ofϐice : +1 907 265 6462
Mobile : +1 907 250 9724
Email : Baskoro.Tejo@conocophillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Friday, February 16, 2024 3:40 PM
To: Tejo, Baskoro <Baskoro.Tejo@conocophillips.com >
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S
(OGC) <dave.roby@alaska.gov>
Subject: [EXTERNAL]KRU 3S-617 Frac Sundry (PTD 223-085; Sundry 324-078): Questions
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Baskoro,
I am compleƟng the review of the KRU 3S-617 frac sundry and have a few quesƟons regarding the AOR:
x Would you conĮrm that 3S-611, 3S-612, and 3S-06 are not within a half-mile radius of the completed interval at
3S-617?
3
x It appears that NDST-02, NDST-02PB1, and the recently-drilled 3S-624 are within the half-mile radius and should
be included in SecƟon 10 of the applicaƟon.
x Would you please look at the 3S-15 well (50-103-20444-00-00; PTD 202-254) and evaluate the mechanical
condiƟon of the cement outside of the 7” casing. I noted a CBL interpreta Ɵon that shows TOC at ~8,130’ MD,
with poor to no cement across the Kuparuk, Moraine, and Coyote intervals.
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Rig 142
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Subject:3S-617 BOP test 11-27-23.xlsx
Date:Wednesday, November 29, 2023 2:56:51 AM
Attachments:image001.png
3S-617 BOP test 11-27-23.xlsx
Doyon 142 BOP test 11/27/23 results
Thank you
Harley Huntington
Rig 142 Tourpusher
Rig142@doyondrilling.com
Doyon Rig 142 Office 907-670-6002
Cell, 907-602-2105
.586
37'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 24.3 BF:
Total Depth: 1917' FNL, 2160 FEL, Sec 35, T13N, R7E, UM 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" H-40 155'
10 3/4" L-80 2553'
7 5/8" L-80 5,130'
4 1/2" P110S 5164'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
12/10/2023 223-085
50-103-20864-00-00
KRU 3S-617
ADL 380107, ADL 380106, ADL
025528,
LONS 01-013
10/25/2023
21276' MD/5,163'TVD
N/A
63.3
P.O. Box 100360 Anchorage, AK 99510-0360
476135 5993884
1561' FSL, 481' FEL, Sec. 12, T12N, R7E, UM
11/18/20232532' FNL, 1124' FEL, Sec 18, T12N, R8E, UM
5997990
1737'MD/1702'TVD
SETTING DEPTH TVD
6010365
TOP HOLE SIZE AMOUNT
PULLED
471988
468773
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
Kuparuk River Field/ Torok Oil Pool
N/A
BOTTOM
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
CASING WT. PER
FT.GRADE CEMENTING RECORD
13.5"
10 yards
40'Lead: 448 bbls of 10.7 ppg
Class G
Tail: 56 bbls of 15.8ppg Class G
12.6
40'
8148'
2779'
6.5"
162 bbls of 15.3 ppg Class G9.875"
40'
40'
29.7
21240'
37'
5073'
94
45.5
155'
37' 8331'
SIZE
42"
Flow Tubing
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
DEPTH SET (MD) PACKER SET (MD/TVD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
TUBING RECORD
8157'4.5"
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
8,020'MD/5,029' TVD
GR, RES, PWD, DIR, AZI, DEN, NEU, POR, SONIC
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
Liner ran 12/3/2023 @ 8,148'MD/ 5073' TVD to 21,241'MD/5,164'TVD
By Grace Christianson at 9:51 am, Jan 09, 2024
Completed
12/10/2023
JSB
RBDMS JSB 012224
DSR-2/13/24 G
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1373 1362
Ugnu B 1662 1633
1737 1702
Top Ugnu A 1779 1740
2099 2020
2615 2432
2853 2603
4421 3420
C-35 5470 3896
Top Coyote 5911 4095
Base Coyote 6865 4525
8432 5171
21276 5162
(Torok)
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Matt Smith
Digital Signature with Date:Contact Email:matt.smith@conocophillips.com
Contact Phone:907-265-6824
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
Top of Productive Interval
(Torok)
Authorized Title: Drilling Engineer
Direction Survey, Operations Summary, Cementing Summary, Well Schematic
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
C-80
Permafrost - Base
C-50
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Top West Sak
Base West Sak
Formation Name at TD:
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Ugnu C
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Top Coyote@ 5,909' MD / 4,087' TVD
3S-617 Horizontal Moraine Injector
10-¾" 45.5# L80 H563 2,778’ MD / 2,551' TVD 43° Inc
Conductor: 97'
4-½" 12.6# P110S H563 21,240' MD / 5,162' TVD 90° Inc
Tubing: 4-½”12.6#, L-80, Hydril 5639-и" Intermediate Hole
6-1/2" Production Hole
13-½" Surface Hole
7-з" 29.7# L80 H563 to 7489'
7-з" 33.7# P110S H563 @8331' MD / 5130' TVD 72° Inc
Updated: 12/07/23 by 142 Ops Eng
4-½” x 6-1/8" Swell Packer Frac sleeve (ball drop)
Sp
u
d
M
u
d
3.562", DB Nipple @ 8,086' MD / 5,051' TVD
FlexLock/ZXP, Liner Top Packer, Hanger 8,148' MD / 5,072’ TVD
4-½” x 7-з " TNT Packer @ 8,020' MD / 5,027' TVD
TOC @ 3,841’ MD / 3,155’ TVD (932' TVD above hydrocarbon bearing zone)
Downhole Gauge @ 7,956' MD / 5,002' TVD
Top Torok Oil Pool (Moraine) @ 8,419 MD / 5,168' TVD
Gas Lift Mandrel, 4-½” x 1” @ 1,985' MD / 1922' TVD
Wellbore Isolation Valve / Alpha Sleeve
Gas Lift Mandrel, 4-½” x 1” @ 7,849' MD / 4,958' TVD
6-½” TD 21,276' MD / 5,162' TVD 90° Inc
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
Conductor2019.00 39.0 155.0 155.094.00 H-4058
Surface 10 3/4 9.95 39.7 2,778.8 2,551.7 45.50 L-80 Hyd563
Intermediate 7 5/8 6.88 37.2 8,330.6 5,129.0 29.70 L80 Hyd563
Liner 4 1/2 3.96 8,148.0 21,240.0 5,162.4 12.60 P110S Hyd563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
36.3
Set Depth …
8,157.4
Set Depth …
5,075.6
String Max No…
4 1/2
Tubing Description
Tubing – Production
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
Hyd563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
36.3 36.3 0.00 Hanger 4.500 Cameron 4-1/2" Tubing Hanger Camero
n
SN -
1218071
05-3
3.960
1,985.0 1,921.5 30.16 Mandrel - SOV 4.500 KBMG 4-1/2" w/ 1" SOV @ 2000
PSI, SN# 23685-10
SLB PN# -
11141-
01_VCS
3.865
7,848.8 4,958.5 64.29 Mandrel – GAS
LIFT
4.500 KBMG 4-1/2" w/ 1" Inconel Dummy,
SN# 24190-01
SLB PN# -
11141-
01_VCS
3.865
7,956.2 5,002.9 66.75 Mandrel –
PROD
4.500 HAL Opsis Mandrel 4-1/2" HES SN -
OPS-
00245
ADD:14
7
3.926
8,020.2 5,027.4 68.12 PACKER 4.500 HAL TNT Packer 4-1/2" x 7-5/8"HES 1030327
39
3.856
8,086.1 5,051.369.45 Nipple - DB 4.500 Landing Nipple OSDB-6 w/Double
Check Valve, SN# 4792184669-01-
001
SLB PN#
1047535
04
3.562
8,148.0 5,072.5 70.41 Locator 4.500 Baker Mechanical Locator (1.06'
from fully located)
Baker SN -
ATM-23-
134331-
4
3.880
8,154.1 5,074.5 70.50 Shoe - Mule 4.500 HES Self-Aligning Muleshoe Baker SN -
1074671
67
3.910
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
36.336.30.00 BPV "H" BPV Not tested 12/9/20230.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi)Run Date Com Make Model
Port
Size (in)
1,985.0 1,921.5 30.16 1 GLM BEK 1 12/7/2023CAMCOKBMG
7,956.2 5,002.9 66.75 2 GLM BK 1 12/7/2023CAMCOKBMG
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
8,170.4 5,079.9 70.74 Nipple - RS6.500 RS Packoff Seal Nipple Baker mm-
13760865
5.750
8,172.7 5,080.7 70.77 XO Reducing 5.500 5.5" Hyd 563 box X pin 4.5" Hyd
563 cross over
Bakermm-
13924402
4.250
8,635.2 5,207.8 77.00 Packer - Swell 4.500 Baker 5.6" Swell Packer #24, SN#
4512088202-015
Baker SERP 3.930
8,904.2 5,254.2 83.73 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.373" ball) #23, SN#
H809340006
FracPoin
t
MX CMB 3.310
9,156.5 5,264.990.78 Packer - Swell 4.500 Baker 5.6" Swell Packer #23, SN#
4512088202-010
Baker SERP 3.930
9,507.2 5,264.989.54 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.329" ball) #22, SN#
H809340007
FracPoin
t
MX CMB 3.290
9,798.1 5,266.1 90.09 Packer - Swell 4.500 Baker 5.6" Swell Packer #22, SN#
4512088202-006
Baker SERP 3.930
10,108.6 5,265.2 90.10 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.284" ball) #21, SN#
H809340008
FracPoin
t
MX CMB 3.250
10,402.3 5,265.2 89.76 Packer - Swell 4.500 Baker 5.6" Swell Packer #21, SN#
4512088202-008
Baker SERP 3.930
10,712.5 5,265.690.07 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.241" ball) #20, SN#
H809340009
FracPoin
t
MX CMB 3.220
11,006.6 5,260.291.93 Packer - Swell 4.500 Baker 5.6" Swell Packer #20, SN#
4512088202-04
Baker SERP 3.930
11,316.8 5,249.0 92.16 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.197" ball) #19, SN#
H809340010
FracPoin
t
MX CMB 3.170
11,611.2 5,239.7 91.64 Packer - Swell 4.500 Baker 5.6" Swell Packer #19, SN#
4512088202-03
Baker SERP 3.930
11,921.0 5,231.5 91.59Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.154" ball) #18, SN#
H809340011
FracPoin
t
MX CMB 3.130
12,215.1 5,223.391.64 Packer - Swell 4.500 Baker 5.6" Swell Packer #18, SN#
4512088202-01
Baker SERP 3.930
12,525.6 5,215.990.75 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.112" ball) #17, SN#
H809340012
FracPoin
t
MX CMB 3.090
12,819.8 5,214.9 90.14 Packer - Swell 4.500 Baker 5.6" Swell Packer #17, SN#
4512088202-09
Baker SERP 3.930
13,130.1 5,210.7 90.78 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.070" ball) #16, SN#
H809340013
FracPoin
t
MX CMB 3.050
HORIZONTAL, 3S-617, 1/4/2024 12:30:26 PM
Vertical schematic (actual)
Liner; 8,148.0-21,240.0
Intermediate; 37.2-8,330.6
Nipple - DB; 8,086.1
PACKER; 8,020.2
Mandrel – PROD; 7,956.1
Mandrel – GAS LIFT; 7,848.8
Intermediate String 1 Cement;
3,015.0 ftKB
Surface; 39.7-2,778.8
Mandrel - SOV; 1,984.9
Surface String Cement; 39.7
ftKB
Conductor; 39.0-155.0
Hanger; 36.3
BPV; 36.3
KUP SVC
KB-Grd (ft)
39.00
RR Date
12/10/202
3
Other Elev…
3S-617
...
TD
Act Btm (ftKB)
21,276.0
Well Attributes
Field Name
TRACT OPERATION MORTR05
Wellbore API/UWI
501032086400
Wellbore Status
SVC
Max Angle & MD
Incl (°)
92.16
MD (ftKB)
11,315.31
WELLNAME WELLBORE
Annotation End DateH2S (ppm)DateComment
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
13,423.6 5,205.7 91.02 Packer - Swell 4.500 Baker 5.6" Swell Packer #16, SN#
4512088202-02
Baker SERP 3.930
13,692.7 5,199.3 91.60 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (3.028" ball) #15, SN#
H809340014
FracPoin
t
MX CMB 3.000
13,983.5 5,193.291.32 Packer - Swell 4.500 Baker 5.6" Swell Packer #15, SN#
4512088202-014
Baker SERP 3.930
14,292.3 5,185.291.35 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.987" ball) #14, SN#
H809340015
FracPoin
t
MX CMB 2.960
14,583.5 5,180.2 90.57 Packer - Swell 4.500 Baker 5.6" Swell Packer #14, SN#
4512088202-07
Baker SERP 3.930
14,890.4 5,179.4 90.63 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.946" ball) #13, SN#
H809340016
FracPoin
t
MX CMB 2.920
15,142.8 5,174.891.15 Packer - Swell 4.500 Baker 5.6" Swell Packer #13, SN#
4512088202-013
Baker SERP 3.930
15,453.3 5,169.290.77 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.906" ball) #12, SN#
H809340017
FracPoin
t
MX CMB 2.880
15,706.0 5,164.9 90.85 Packer - Swell 4.500 Baker 5.6" Swell Packer #12, SN#
4512088202-05
Baker SERP 3.930
16,016.4 5,161.9 90.54 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.866" ball) #11, SN#
H809340018
FracPoin
t
MX CMB 2.840
16,269.1 5,160.1 90.08 Packer - Swell 4.500 Baker 5.6" Swell Packer #11, SN#
6800-3028-11
Baker SERP 3.930
16,494.7 5,160.289.72Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.826" ball) #10, SN#
H809340019
FracPoin
t
MX CMB 2.800
16,746.9 5,162.689.38 Packer - Swell 4.500 Baker 5.6" Swell Packer #10, SN#
4512088202-02
Baker SERP 3.930
17,015.0 5,163.9 90.10 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.787" ball) #9, SN#
H809340020
FracPoin
t
MX CMB 2.760
17,267.4 5,164.1 89.86 Packer - Swell 4.500 Baker 5.6" Swell Packer #9, SN#
4512088202-07
Baker SERP 3.930
17,492.9 5,164.1 90.05 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.749" ball) #8, SN#
H809340021
FracPoin
t
MX CMB 2.730
17,743.8 5,165.089.64 Packer - Swell 4.500 Baker 5.6" Swell Packer #8, SN#
4512088202-05
Baker SERP 3.930
17,930.2 5,166.7 89.46Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.710" ball) #7, SN#
H809340022
FracPoin
t
MX CMB 2.690
18,099.9 5,168.9 89.37 Packer - Swell 4.500 Baker 5.6" Swell Packer #7, SN#
4512088202-01
Baker SERP 3.930
18,327.4 5,170.2 90.00 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.672" ball) #6, SN#
H809340023
FracPoin
t
MX CMB 2.650
18,538.3 5,169.7 90.44 Packer - Swell 4.500 Baker 5.6" Swell Packer #6, SN#
4512088202-03
Baker SERP 3.930
18,723.7 5,168.190.47 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.635" ball) #5, SN#
H809340024
FracPoin
t
MX CMB 2.610
18,850.8 5,167.2 90.27 Packer - Swell 4.500 Baker 5.6" Swell Packer #5, SN#
4512088202-04
Baker SERP 3.930
19,076.7 5,167.1 89.98 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.598" ball) #4, SN#
H809340025
FracPoin
t
MX CMB 2.580
19,328.6 5,167.0 89.98 Packer - Swell 4.500 Baker 5.6" Swell Packer #4, SN#
4512088202-10
Baker SERP 3.930
19,593.7 5,165.990.55 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.561" ball) #3, SN#
H809340051
FracPoin
t
MX CMB 2.540
19,801.6 5,164.8 89.97 Packer - Swell 4.500 Baker 5.6" Swell Packer #3, SN#
4512088202-09
Baker SERP 3.930
20,070.6 5,164.6 90.10 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.525" ball) #2, SN#
H809340052
FracPoin
t
MX CMB 2.500
20,280.6 5,164.8 89.62 Packer - Swell 4.500 Baker 5.6" Swell Packer #2, SN#
4512088202-08
Baker SERP 3.930
20,548.5 5,166.8 89.92 Sleeve - Frac 4.500 BAKER CMB 2.0, C110 Frac
Sleeve (2.489" ball) #1, SN#
H809340053
FracPoin
t
MX CMB 2.460
20,757.9 5,166.7 90.00 Packer - Swell 4.500 Baker 5.6" Swell Packer #1, SN#
4512088202-06
Baker SERP 3.930
21,034.4 5,164.390.69 Sleeve - Setting 5.000 Alpha Pressure Sleeve, 4 1/2",
13.5#, P110
Baker451255711
SN-02
3.000
21,038.1 5,164.2 90.68 Valve 5.000 Wellbore Isolation Valve, 4 1/2",
12.6#, P110
Baker451235529
1 SN-01
1.000
HORIZONTAL, 3S-617, 1/4/2024 12:30:30 PM
Vertical schematic (actual)
Liner; 8,148.0-21,240.0
Intermediate; 37.2-8,330.6
Nipple - DB; 8,086.1
PACKER; 8,020.2
Mandrel – PROD; 7,956.1
Mandrel – GAS LIFT; 7,848.8
Intermediate String 1 Cement;
3,015.0 ftKB
Surface; 39.7-2,778.8
Mandrel - SOV; 1,984.9
Surface String Cement; 39.7
ftKB
Conductor; 39.0-155.0
Hanger; 36.3
BPV; 36.3
KUP SVC 3S-617
...
WELLNAME WELLBORE
Page 1/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/21/2023
06:00
10/21/2023
09:30
3.50 MIRU, MOVE MOB P Raise rear cellar door. Continue to
disconnect interconnects. Verify rig
move checklist completion. Fuel
coldstarts.
0.0 0.0
10/21/2023
09:30
10/21/2023
10:00
0.50 MIRU, MOVE SFTY P PJSM with NES and DDI on moving the
rig.
0.0 0.0
10/21/2023
10:00
10/21/2023
10:30
0.50 MIRU, MOVE MOB P Set pipeshed on suspension. 0.0 0.0
10/21/2023
10:30
10/21/2023
10:45
0.25 MIRU, MOVE MOB P Set Power module on suspension and
stage for transport to 3S.
0.0 0.0
10/21/2023
10:45
10/21/2023
11:30
0.75 MIRU, MOVE MOB P Set pump module on suspension and
stage for transport to 3S.
0.0 0.0
10/21/2023
11:30
10/21/2023
12:00
0.50 MIRU, MOVE MOB P Move and stage rockwasher for
transport to 3S.
SIMOPS - Load trucks with rig mats to
get ahead of rig move.
11:45 - Pump, Pits, Power depart to 3S.
0.0 0.0
10/21/2023
12:00
10/21/2023
14:00
2.00 MIRU, MOVE MOB P Install sub tow tongue, skid rig floor, and
raise & secure stompers.
0.0 0.0
10/21/2023
14:00
10/21/2023
16:00
2.00 MIRU, MOVE MOB P Continue to load trucks with rig mats.
Clean and organize 1C.
0.0 0.0
10/21/2023
16:00
10/21/2023
18:00
2.00 MIRU, MOVE MOB P Ready pipeshed and Sub for hooking
onto sows. Continue clean up around
1C-158.
Pump, Pits, & Power arrive at 3S @
1400 hrs (4.25 total travel time)
0.0 0.0
10/21/2023
18:00
10/21/2023
18:30
0.50 MIRU, MOVE MOB P Hook sow to pipeshed, pull away from
sub and stage for transport to 3S.
0.0 0.0
10/21/2023
18:30
10/21/2023
18:45
0.25 MIRU, MOVE MOB P Hook sow to sub and pull off of 1C-158.
Pad operator witness moving off well.
Stage sub for transport to 3S.
0.0 0.0
10/21/2023
18:45
10/21/2023
21:00
2.25 MIRU, MOVE MOB P Wait on fuel truck. Was stuck behind
Nordic 3.
0.0 0.0
10/21/2023
21:00
10/21/2023
22:30
1.50 MIRU, MOVE MOB P Fuel NES and Doyon 142 coldstarts. 0.0 0.0
10/21/2023
22:30
10/22/2023
00:00
1.50 MIRU, MOVE MOB P Transport Sub, Pipeshed, and
Rockwasher from 1C to KOC.
0.0 0.0
10/22/2023
00:00
10/22/2023
04:00
4.00 MIRU, MOVE MOB P Transport Sub, Pipeshed, and
Rockwasher from KOC to 3B
0.0 0.0
10/22/2023
04:00
10/22/2023
06:00
2.00 MIRU, MOVE MOB P Place mats on roadway from 3G to 3S
to lift rig to clear transformers at the
edge of the road.
SIMOPS - Prep 3S-617 w/ dirt work.
0.0 0.0
10/22/2023
06:00
10/22/2023
14:15
8.25 MIRU, MOVE MOB P Transport Sub, Pipeshed, and
Rockwasher from 3B to 3S.
SIMOPS - Continue with dirt work. Lay
herculite needed for cellar.
0.0 0.0
10/22/2023
14:15
10/22/2023
15:00
0.75 MIRU, MOVE MOB P Align sub for spotting. Spot rig mats for
sub.
SIMOPS - Install Cameron speed head
on 3S-617.
0.0 0.0
10/22/2023
15:00
10/22/2023
18:00
3.00 MIRU, MOVE MOB T Wait on rig mats - transitions. 0.0 0.0
10/22/2023
18:00
10/22/2023
19:15
1.25 MIRU, MOVE MOB P Spot rig mats and transitions. 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 2/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/22/2023
19:15
10/22/2023
20:45
1.50 MIRU, MOVE MOB P Spot sub. Observe stomper directly
over well 18 process line. Decision
made to move stomper mat and
stomper to clear line.
0.0 0.0
10/22/2023
20:45
10/22/2023
23:45
3.00 MIRU, MOVE MOB T Pull sub off 3S-617. Prep area for new
stomper mat location via NES. Spot
stomper mat via NES.
SIMOPS - used this time to spot surface
riser and wellhead equipment into the
cellar.
0.0 0.0
10/22/2023
23:45
10/23/2023
00:00
0.25 MIRU, MOVE MOB P Spot sub onto well 3S-617. 0.0 0.0
10/23/2023
00:00
10/23/2023
03:45
3.75 MIRU, MOVE MOB T Attempt to spot sub over well. Was
unsuccessfull on getting sub onto rig
mats due to mechanical issue with NES
cat. Removed cat and attempt with
additional weighted sow and again was
unsuccessful.
SIMOPS - Continue to offload shrapnel
from 1C.
0.0 0.0
10/23/2023
03:45
10/23/2023
06:00
2.25 MIRU, MOVE MOB P NES cat on location and spot sub. 0.0 0.0
10/23/2023
06:00
10/23/2023
08:30
2.50 MIRU, MOVE MOB P Lower stompers and add shims to DS,
skid floor, and remove sub tow tongue.
0.0 0.0
10/23/2023
08:30
10/23/2023
09:00
0.50 MIRU, MOVE MOB P Shuffle rig mats/transitions.
SIMOPS - Begin to hook up choke/kill
lines.
0.0 0.0
10/23/2023
09:00
10/23/2023
09:45
0.75 MIRU, MOVE MOB P Spot pits and pump modules.
SIMOPS - Verify electrical
interconnects. Stage mats for
Pipeshed.
0.0 0.0
10/23/2023
09:45
10/23/2023
11:00
1.25 MIRU, MOVE MOB P Spot motor module.
SIMOPS - Continue to connect
plumbing and electrical interconnects
0.0 0.0
10/23/2023
11:00
10/23/2023
12:00
1.00 MIRU, MOVE MOB P Spot Rockwasher.
SIMOPS - Continue to connect
plumbing and electrical interconnects,
and offloading shrapnel from 1C.
0.0 0.0
10/23/2023
12:00
10/23/2023
13:00
1.00 MIRU, MOVE MOB P Spot Pipeshed module. 0.0 0.0
10/23/2023
13:00
10/23/2023
18:00
5.00 MIRU, MOVE MOB P Continue with plumbing and electrical
interconnects. Bring on air and steam to
the rig. Lower mezzanine catwalk.
Swap to gens @ 17:30 hrs.
0.0 0.0
10/23/2023
18:00
10/23/2023
19:30
1.50 MIRU, MOVE MOB P Install skate rail. 0.0 0.0
10/23/2023
19:30
10/23/2023
21:30
2.00 MIRU, MOVE MOB P Install beaverslide. 0.0 0.0
10/23/2023
21:30
10/24/2023
00:00
2.50 MIRU, MOVE MOB P Complete rig acceptance checklist.
Accept the rig @ 00:00 hrs 10/24/2023
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 3/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/24/2023
00:00
10/24/2023
06:00
6.00 MIRU, MOVE MOB P Install surface riser to starting head,
take needed measurements and make
modifications to riser. Change saver sub
to NC 50 connection, Take on 1st load
of spud mud to pits, load 15 joints heavy
weight drill pipe to pipe shed. strap and
talley heavy weight drill pipe and drill
pipe. Load surface BHA to short side
pipe shed, strap and talley same.
Continue offloading tools and equip from
trucks coming from 1C pad. Offloading
mud products, ready rockwasher and
cuttings tanksfor service.
0.0 0.0
10/24/2023
06:00
10/24/2023
12:00
6.00 MIRU, MOVE RURD P Conduct pre-spud derrick inspection,
inspect crown lighting, service blocks,
install mouse hole, energize slips on
speed head as per Cameron Rep. Test
gas alarms on rig (Good Test), slip and
cut Drill line 7 wraps, Continue working
BHA in pipe shed and bring handling
tools to rig floor.
0.0 0.0
10/24/2023
12:00
10/24/2023
14:30
2.50 MIRU, MOVE RURD P M/U bolts and starting head, take
measurement from load shoulder, Install
extended piece to riser and center over
well bore Recalibrate block position ,
Continue bringing in BHA and handling
equip to rig floor. continue receiving
tools and equipment from 1C pad.
0.0 0.0
10/24/2023
14:30
10/24/2023
17:30
3.00 MIRU, MOVE RURD P Stock pits with product, verify pit
sensors were working properly. Adjust
all surface tools for handling surface
BHA. Run and install MWD hook load
sensor, Make Jar stand and 1 stand
heavy weight drill pipe rack in derrick.
0.0 0.0
10/24/2023
17:30
10/24/2023
18:00
0.50 MIRU, MOVE SVRG P Service Top-Drive, Blocks and ST-100 0.0 0.0
10/24/2023
18:00
10/24/2023
20:30
2.50 MIRU, MOVE RURD P Dumb iron arrived at rig, Offload trucks,
Dumb iron, mud product, 5" heavy
weight drill pipe 5" drill pipe.Continue
loading up pits with mud product, MP'2
on rig equip.ment. Rig up Magtec
equipment for surface drilling ops.
0.0 0.0
10/24/2023
20:30
10/24/2023
22:30
2.00 MIRU, MOVE RUNL P PJSM, Load and organize surface BHA
into pipe shed, followed by 3-5" heavy
weight drill pipe for surface drilling.
Strap and tally heavy weight drill pipe.
0.0 0.0
10/24/2023
22:30
10/25/2023
00:00
1.50 MIRU, MOVE BHAH P PJSM, M/U cleanout BHA as per SLB,
DD and MWD to 42' P/U 52k S/O 52K
0.0 42.0
10/25/2023
00:00
10/25/2023
00:30
0.50 MIRU, MOVE SFTY P Pre-spud meeting and PJSM for drilling
surface.
42.0 42.0
10/25/2023
00:30
10/25/2023
02:30
2.00 MIRU, MOVE SEQP P M/U 1x std 5"Hwdp in mouse hole for
cleanout run, flood lines with spud mud,
pressure test lines to 4000psi(good),
check all associated
lines/riser/conductor valves for leaks
(good), test flow line jets(good), prep
cutting tank with spud mud for drilling
42.0 42.0
10/25/2023
02:30
10/25/2023
03:00
0.50 SURFAC, DRILL REAM P Wash down and tag with RPM 25, GPM
400, F/O 30% PSI 330 from 42' MD lost
slack off weight @ 75' Continue washing
down from 75' to bottom of conductor
97' with RPM, GPM 400, F/O 40% (jets
on) PSI 440.
42.0 97.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 4/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/25/2023
03:00
10/25/2023
04:15
1.25 SURFAC, DRILL DDRL P Spud well, Begin drilling 13 1/2" surface
section from 97' to 200’ GPM 450, PSI
460, F/O 40% (jets on) H2O on @ 15
BPM, WOB 3.5K, ADT 1.05, Total Bit
Hrs = 1.05,
200.0 200.0
10/25/2023
04:15
10/25/2023
05:15
1.00 SURFAC, DRILL TRIP P POOH to 75’ with pumps off filling hole
via jet line, P/U weight = 55k
200.0 75.0
10/25/2023
05:15
10/25/2023
06:15
1.00 SURFAC, DRILL BHAH P L/D bottleneck, pick up Gyro and 8 1/4''
Arc-vision scribe via Schlumberger
directional driller. Attempt to run in hole,
lost hook load @ 75' decision to wash
down.
75.0 120.0
10/25/2023
06:15
10/25/2023
06:45
0.50 SURFAC, DRILL BHAH T Lay down Gyro and Arc-Vision tools to
shed, M/U bottleneck XO
120.0 75.0
10/25/2023
06:45
10/25/2023
09:15
2.50 SURFAC, DRILL REAM T Pick up stand and begin washing down
from 42' to 200' MD with 400 GPM, 40
RPM, 330 PSI, S/O 55K working
through obstruction @ 75'
42.0 200.0
10/25/2023
09:15
10/25/2023
09:45
0.50 SURFAC, DRILL TRIP T POOH on elevators, racking drill pipe
back in derrick.from 200' to 75' MD
200.0 75.0
10/25/2023
09:45
10/25/2023
12:00
2.25 SURFAC, DRILL BHAH P PJSM for picking up remaining 13.5"
surface BHA, make up BHA as per SLB.
from 75' to154' MD
75.0 154.0
10/25/2023
12:00
10/25/2023
12:15
0.25 SURFAC, DRILL BHAH P M/U single 5"Hwdp to collars and
perform conductor deviation survey @
154'MD.
154.0 154.0
10/25/2023
12:15
10/25/2023
13:15
1.00 SURFAC, DRILL SVRG P Continue to perform conductor deviation
survey @ 154', 450-500 GPM, 515-620
PSI, P/U, S/O 64K from 154' to 187'
RIH, breakout and lay down 5"Hwdp to
Blowdown top-drive.
154.0 187.0
10/25/2023
13:15
10/25/2023
13:45
0.50 SURFAC, DRILL SVRG T Trouble shoot SLB, surface computer
system
187.0 187.0
10/25/2023
13:45
10/25/2023
14:15
0.50 SURFAC, DRILL SVRG P Rig service, Service top-drive and St-
100
187.0 187.0
10/25/2023
14:15
10/25/2023
18:15
4.00 SURFAC, DRILL DDRL P Drill 13 ½” Surface hole from 200‘MD to
458‘MD 460‘TVD, WOB 1K, GPM 500,
PSI ON 678, PSI OFF 667, RPM 40, TQ
1, 0.5, FLOW OUT 32%, ECD
=10.24PPG, AST 0, ART 2.74, ADT
2.74, Total Bit Hrs 3.79, Total Jar Hrs
2.74
200.0 458.0
10/25/2023
18:15
10/26/2023
00:00
5.75 SURFAC, DRILL DDRL P DRILL 13 ½” Surface hole from 458‘MD
to 850‘MD, 777‘TVD, WOB 6K, GPM
450, PSI 820, RPM = 40, TQ 4K, 1K,
FLOW OUT 30%, ECD 9.92 PPG, P/U
87K, S/O 90K, RT 90K, AST 1.27, ART
1.46, ADT 2.73, Total Bit Hrs 6.52, Total
Jar Hrs 6.52
458.0 850.0
10/26/2023
00:00
10/26/2023
06:00
6.00 SURFAC, DRILL DDRL P DRILL 13 ½” Surface hole from 850‘MD
to 1309‘MD, 1150‘TVD, WOB 8K, GPM
450, PSI 945, RPM = 40, TQ 4K, 1K,
FLOW OUT 30%, ECD 9.92 PPG, P/U
87K, S/O 90K, RT 90K, AST 3.05, ART
1.06, ADT 4.11, Total Bit Hrs 10.63, Total
Jar Hrs 10.63
850.0 1,309.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 5/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/26/2023
06:00
10/26/2023
12:00
6.00 SURFAC, DRILL DDRL P DRILL 13 ½” Surface hole from
1309‘MD to 1779‘MD, 1735‘TVD, WOB
8K, GPM 450, PSI 945, RPM = 40, TQ
4K, 1K, FLOW OUT 30%, ECD 9.92
PPG, P/U 107K, S/O 103K, RT 101K,
AST 2.51, ART 1.50, ADT 4.01, Total Bit
Hrs 14.64, Total Jar Hrs 14.64
1,309.0 1,779.0
10/26/2023
12:00
10/26/2023
18:00
6.00 SURFAC, DRILL DDRL P DRILL 13 ½” Surface hole from
1779‘MD to 2190‘MD, 2099‘TVD, WOB
5K, GPM 500, PSI 1298, RPM = 40, TQ
5K, 3K, FLOW OUT 39%, ECD 10.81
PPG, P/U 107K, S/O 103K, RT 104K,
AST 1.74, ART 1.82, ADT 3.56, Total Bit
Hrs 18.20, Total Jar Hrs 18.20
1,779.0 2,190.0
10/26/2023
18:00
10/27/2023
00:00
6.00 SURFAC, DRILL DDRL P DRILL 13 ½” Surface hole from
2190‘MD to 2605‘MD, 2399‘TVD, WOB
8K, GPM 525, PSI 1550, RPM = 40, TQ
5K, 3K, FLOW OUT 37%, ECD 10.81
PPG, P/U 114K, S/O 109K, RT 109K,
AST 1.69, ART 3.21, ADT 4.90, Total Bit
Hrs 23.10, Total Jar Hrs 23.10
2,190.0 2,605.0
10/27/2023
00:00
10/27/2023
02:15
2.25 SURFAC, DRILL DDRL P DRILL 13 ½” Surface hole from
2605‘MD to 2784‘MD, 2480‘TVD, WOB
10K, GPM 525, PSI 1565, RPM = 40,
TQ 6K, 3K, FLOW OUT 37%, ECD
11.24 PPG, P/U 117K, S/O 112K, RT
114K, AST .18, ART 1.24, ADT 1.24,
Total Bit Hrs 24.52, Total Jar Hrs 24.52
2,605.0 2,784.0
10/27/2023
02:15
10/27/2023
04:00
1.75 SURFAC, TRIPCAS CIRC P Circulate, Rotate & Reciprocate from
2784‘MD to 2720‘MD, GPM, PSI 1390,
F/O 36%, RPM 40, TQ 3k, ECD 10.50
PPG, P/U 117k, S/O 112k, RT 114k,
Total strokes pumped 10,190. @ TD
shoot final survey, pump 40bbls nut plug
sweep. (OWFF static)
2,784.0 2,720.0
10/27/2023
04:00
10/27/2023
08:00
4.00 SURFAC, TRIPCAS BKRM P BROOH F/ 2720‘MD to 2160‘MD, with
GPM 550, PSI 1500, RPM 40, TQ 3K.
F/O 26%, ECD 10.41PPG, P/U and RT
108K.
2,720.0 2,160.0
10/27/2023
08:00
10/27/2023
08:30
0.50 SURFAC, TRIPCAS TRIP P POOH with elevators through
permafrost from 2160' to 1883', P/U
120k S/O 98k, observed 35k overpull @
1885', tried to work through 3x.
2,160.0 1,883.0
10/27/2023
08:30
10/27/2023
09:00
0.50 SURFAC, TRIPCAS TRIP P RIH from 1883' to 2160' with 5"DP from
Derrick, S/O 104K
1,883.0 2,160.0
10/27/2023
09:00
10/27/2023
12:00
3.00 SURFAC, TRIPCAS PMPO P PUMP OOH from 2160' MD, to 1396'
MD, with 600-550 GPM, 1536-1267 PSI,
P/U.- 97K, F/O- 22%, ECD 10.89,
2,160.0 1,396.0
10/27/2023
12:00
10/27/2023
15:00
3.00 SURFAC, TRIPCAS PMPO P Pump out of hole from 1396‘MD to
737‘MD, GPM 550, PSI 1192, FLOW
OUT 23 %, P/U WT 81K, S/O WT 77K
1,396.0 737.0
10/27/2023
15:00
10/27/2023
16:45
1.75 SURFAC, TRIPCAS TRIP P POOH with elevators from 737' T/
187'MD racking pipe in derrick. P/U and
S/O 62K @279', Kelly up to top drive
pump out hole, GPM 550, PSI 1059,
F/O 12%, ECD 11.27
737.0 187.0
10/27/2023
16:45
10/27/2023
17:15
0.50 SURFAC, TRIPCAS OWFF P OWFF(Static) 187.0 187.0
10/27/2023
17:15
10/27/2023
18:00
0.75 SURFAC, TRIPCAS SFTY P PJSM, laydown 13.5" surface BHA as
per SLB DD, P/U and S/O wt.- 52k
187.0 187.0
10/27/2023
18:00
10/27/2023
20:15
2.25 SURFAC, TRIPCAS BHAH P L/D BHA as per SLB DD/MWD Reps
from 187’ to surface
187.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 6/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/27/2023
20:15
10/27/2023
21:15
1.00 SURFAC, TRIPCAS CLEN P Clean/clear rig floor, L/D BHA
components Via beaver slide
0.0 0.0
10/27/2023
21:15
10/27/2023
23:15
2.00 SURFAC, TRIPCAS RURD P PJSM, mobilize casing equipment to rig
floor, rig up same, M/U Volant CRT tool
0.0 0.0
10/27/2023
23:15
10/27/2023
23:45
0.50 SURFAC, CASING SVRG P Service drawworks-top drive 0.0 0.0
10/27/2023
23:45
10/28/2023
00:00
0.25 SURFAC, CASING RGRP T Change out hydraulic return line on pipe
skate system
0.0 0.0
10/28/2023
00:00
10/28/2023
00:15
0.25 SURFAC, CASING RGRP T Change out hydrauylic return line on
skate.
0.0 0.0
10/28/2023
00:15
10/28/2023
01:30
1.25 SURFAC, CASING THGR P M/U 10-3/4" surface casing hanger,
perform dummy run as per Cameron
wellhead Reps
0.0 39.1
10/28/2023
01:30
10/28/2023
06:00
4.50 SURFAC, CASING PUTB P PJSM, RIH with 10-3/4" surface casing
45.5# L-80 Hyd563, Double bump
connections make up torque 16200 ft-
lbs. P/U shoe float assy Baker Loc each
connection, fill pipe check floats(Good)
RIH from surface to 820' MD with Volant
CRT. Filling pipe on the fly, Check pipe
is full every 10 joints ran. Monitor
displacement on pit #1 and #2. S/O 50K
0.0 820.0
10/28/2023
06:00
10/28/2023
09:45
3.75 SURFAC, CASING PUTB P PJSM, RIH with 10-3/4" surface casing
45.5# L-80 Hyd563, Double bump
connections make up torque 16200 ft-
lbs. RIH from 820' MD to 1277' MD with
Volant CRT. Filling pipe on the fly,
Check pipe is full every 10 joints ran.
Monitor displacement on pit #1 and #2.
S/O 50K @ 1154'MD observe
discrepancy in displacement, broke
circulation @ 1BPM 117 PSI, At 1277'
MD lost 25k S/O weight, attempt to work
through, no progress, establish
circulation on stroke up @ 1-4 BPM, 127
-173 PSI, attempted to work through no
success. POOH with 1 jt 10-3/4" casing
from 1277' to 1266' MD
820.0 1,277.0
10/28/2023
09:45
10/28/2023
11:00
1.25 SURFAC, CASING CIRC P Make Volant tool circulate and condition
while reciprocating pipe from 1266'
to1225'MD @ 2 BPM, 135 PSI. P/U 89k
S/O 77K. Achieved full circulation.
1,277.0 1,266.0
10/28/2023
11:00
10/28/2023
14:45
3.75 SURFAC, CASING PUTB P RIH with 10-3/4" 45.5# L-80 Hyd563
casing from 1266' to 1277' MD Attempt
to work through obstruction @ 1277'MD
while pumping at 4-6 BPM, 132-138
PSI, RPM 5-10 TQ 7-13k, ROT 92K to
1398' MD. Mix and pumped 20 BBLS
low vis H2O pill (5PPB SAPP, 10vis
cups rig soap, 1 Drum drill zone).
1,266.0 1,398.0
10/28/2023
14:45
10/28/2023
16:45
2.00 SURFAC, CASING PUTB P RIH with 10-3/4" surface casing 45.5# L-
80 Hyd563, Double bump connections
make up torque 16200 ft-lbs. RIH from
1398' MD to 1839' MD with Volant CRT.
Filling pipe on the fly, Check pipe is full
every 10 joints ran. Monitor
displacement on pit #1 and #2. S/O 85K
1,398.0 1,839.0
10/28/2023
16:45
10/28/2023
17:45
1.00 SURFAC, CASING CIRC P Circulate and condition mud while
reciprocating pipe from 1839' MD to
1881' MD, Staging up pumps 1-7 BPM,
127-195' PSI, F/O 12%, P/U 122k S/O
93k
1,839.0 1,881.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 7/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/28/2023
17:45
10/28/2023
23:00
5.25 SURFAC, CASING PUTB P RIH with 10-3/4" surface casing 45.5# L-
80 Hyd563, Double bump connections
make up torque 16200 ft-lbs. RIH from
1839' MD to 2735' MD with Volant CRT.
Filling pipe on the fly, Check pipe is full
every 10 joints ran. Monitor
displacement on pit #1 and #2. S/O 85K
@ 2180' MD encountered obstruction
worked thru obstruction from 2180'MD
to 2196', put 1/4 turn in casing several
times while attempting to work thru
Obstruction with no pumps, @ 2196'
worked through obstruction S/O weight
back @ 108K
1,881.0 2,735.0
10/28/2023
23:00
10/29/2023
00:00
1.00 SURFAC, CASING THGR P M/U 10-3/4" land joint and 10-3/4"
hanger assy as per Cameron Rep, Drain
riser and land out on load shoulder.
2,735.0 2,778.8
10/29/2023
00:00
10/29/2023
02:45
2.75 SURFAC, CEMENT CIRC P Circulate and condition mud for cement
job, Reciprocate from 2778' to 2770'MD
ICP 1.5 bpm 202 psi, FCP 6.5 bpm, 172
psi. Land hanger periodically S/O 42k
Total strokes pumped 8290.
2,778.8 2,778.0
10/29/2023
02:45
10/29/2023
03:00
0.25 SURFAC, CEMENT RURD P Blow down top drive, Rig up cement
swivel and lines.
2,778.0 2,778.0
10/29/2023
03:00
10/29/2023
04:00
1.00 SURFAC, CEMENT CIRC T PJSM, with crews on surface cement
job. Circulate and reciprocate 10-3/4"
casing @ 5 bpm 190 psi, P/U 160k S/O
144k, Fresh water manifold frozen up on
Halliburton side, Halliburton pump
engine stalled and lost transmission,
refired engine and gain transmission
power.
2,778.0 2,778.0
10/29/2023
04:00
10/29/2023
05:00
1.00 SURFAC, CEMENT SEQP P Stop pumping with rig pumps, flood
Halliburton lines with 5bbls H2O,
Attempt to pressure test lines 3500 psi
serval times pressure bleed off, check
Halliburton truck and rig surface
equipment. found demco valve on stand
pipe leaking.
2,778.0 2,778.0
10/29/2023
05:00
10/29/2023
05:15
0.25 SURFAC, CEMENT RGRP T Blow down lines changed out Demco
valve
2,778.0 2,778.0
10/29/2023
05:15
10/29/2023
05:30
0.25 SURFAC, CEMENT SEQP P Flood Halliburton lines with 5bbls H2O,
pressure test lines 1138 psi low and
3414 psi high. (Good Test). Bleed
pressure off
2,778.0 2,778.0
10/29/2023
05:30
10/29/2023
09:00
3.50 SURFAC, CEMENT CMNT P Pump 5 bbls fresh water. Test lines to
3414 psi. Pump 60 bbls of spacer w/
poly flake and red dye @ 3 BPM, PSI =
305. F/O - 15%. Load bottom plug.
(Cmt Wet @ 6:09hrs) Batch up and
pump 447 BBLS 10.7 PPG cement -
pump rate 6 BPM, 575 PSI, 16% F/O.
Pump 56.72 BBLS of 15.8 tail cement @
3.88 BPM, 96 PSI, 16% F/O. Drop top
plug. Chase plug with 20 bbls of water
from HES. Line up rig pumps. Displace
cement at 5 BPM, ICP - 552, FCP -
1051. Reduce rate @ 1600 stks T/ 3
BPM, FCP - 500. Bump plug @ 2394
strokes (240 bbls). CIP @ 08:48 hrs.
Pressure up to 1051 psi and hold for 5
min. Bleed off and check floats (good).
Observe 201 bbls of 10.7 cement
returned to surface. 0 losses during
cement job.
2,778.0 2,778.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 8/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/29/2023
09:00
10/29/2023
11:00
2.00 SURFAC, CEMENT RURD P R/D Halliburton cmt line/valves, L/D
Volant 10 3/4" CRT, 6' bale exts,
elevators, slips, ect. Clean and clear rig
floor of excess tools and equip., flush
riser, drain and L/D landing jt. to shed,
ready upper riser to be pulled to rig floor,
2,778.0 2,778.0
10/29/2023
11:00
10/29/2023
13:15
2.25 SURFAC, WHDBOP NUND P Nipple down upper riser section, L/D via
beaverslide, Break flange and R/D lower
riser, Ready starting head to nipple up
Cameron wellhead.
2,778.0 2,778.0
10/29/2023
13:15
10/29/2023
17:15
4.00 SURFAC, WHDBOP NUND P Nipple up wellhead as per Cameron
Rep and orient as per lead pad ops,
Test metal seal assy. to 5000 psi(failed
first attempt, changed out top/bottom o-
rings, test again pass)
2,778.0 2,778.0
10/29/2023
17:15
10/29/2023
18:00
0.75 SURFAC, WHDBOP NUND P Nipple up BOPE with DSA, 11" x 13 5/8"
spool to wellhead and torque to spec,
remove surface riser assy. from cellar
area, mobilize MPD equipment to BOPE
deck and ready to nipple up.
2,778.0 2,778.0
10/29/2023
18:00
10/30/2023
00:00
6.00 SURFAC, WHDBOP NUND P Continue nipple up BOPE to dsa, 11" x
13 5/8" spool to wellhead and torque to
spec, remove surface riser assy from
cellar area, mobilize mpd equipment to
BOPE deck and ready to nipple up,
Nipple up choke/kill lines, mpd RCDand
Orbit valve assy.
2,778.0 2,778.0
10/30/2023
00:00
10/30/2023
03:00
3.00 SURFAC, WHDBOP NUND P Continue nipple up BOPE with DSA, 11"
x 13 5/8" spool to wellhead and torque
to spec, mobilize MPD equipment to
BOPE deck and ready for install, M/U
choke/kill lines, M/U MPD RCD/orbit
valve assy, M/U riser assy, obtain
RKB's, install Cameron test plug as per
Cameron Reps (OD=10.83), L/D test
joint, M/U 5" dart/TIW valve assy,
remove 4" conductor valves, install riser
assy.
0.0 0.0
10/30/2023
03:00
10/30/2023
04:00
1.00 SURFAC, WHDBOP NUND P Rig up BOPE test equipment, install 5"
test joint, flood BOP/choke/kill with H2O,
purge air from system.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 9/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/30/2023
04:00
10/30/2023
09:00
5.00 SURFAC, WHDBOP BOPE P Test bope all tests to 250 low 5,000 high
for 5 charted min. with exception of
manual operated & super choke tested
to 250 low & 2,000 psi for 5 charted min,
with 5" test jt test annular to 250 low
3500 high, 3 1/2" x 6" upper ram, 3 1/2"
x 6" lower ram, with 5" test jt test 3 1/2"
x 6" upper ram & 3 1/2" x 6" lower ram,
test choke valves 1-15, manual
operated & super choke, choke & kill
manuals & Hcr's, 4" valve on kill line, 5"
FOSV, 5" dart valve, upper & lower
IBOP; blind/ shear rams; perform
Koomey drawdown, accumulator = 3000
psi. manifold. = 1500 psi. accumulator =
1900 psi after all functions on bottles, 9
sec for 200 psi. build w/ 2 electric.
pumps, 50 seconds to build full systems.
pressure with 2 electric. & 2 air pumps,
closing times annular = 23 seconds.
upper ram = 18 sec. blind ram , shears
ram = 16 seconds. lower ram = 16
seconds. choke Hcr = 2 seconds. kill
Hcr = 2 second; test PVT gain/loss and
flow out alarms, test LEL and H2S
alarms; witnessed by AOGCC Rep Brian
Bixby
0.0 0.0
10/30/2023
09:00
10/30/2023
11:00
2.00 SURFAC, WHDBOP MPDA P R/D 5" test jt., blow down choke
manifold and kill line, R/D test
equipment and lines, lower H2O level in
stack, pull trip nipple assy. to install
MPD test equipment fill Stack w/ h20
and install MPD test cap, R/U test lines
and ready for MPD test to 1250psi
0.0 0.0
10/30/2023
11:00
10/30/2023
11:30
0.50 SURFAC, WHDBOP MPDA P Test MPD, RCD with test cap to
250Low/1250high psi for 10 minutes
each. (charted)
0.0 0.0
10/30/2023
11:30
10/30/2023
12:00
0.50 SURFAC, WHDBOP MPDA P R/D MPD test equipment. with test cap,
install m/h, ready to pull test plug
0.0 0.0
10/30/2023
12:00
10/30/2023
12:45
0.75 SURFAC, WHDBOP WWSP P Pull test plug and install wear ring as per
Cameron rep, wear ring measurements
ID 10" OD 10.80" length= 2.57'
0.0 0.0
10/30/2023
12:45
10/30/2023
14:30
1.75 SURFAC, WHDBOP MPDA P Log annular element documentation,
install MPD trip nipple, install split
bushing, clean and clear rig floor excess
tools and equip., troubleshoot/replace
MWD/LWD pulse sensor for standpipe,
mobilize BHA tools and equipment to rig
floor.
0.0 0.0
10/30/2023
14:30
10/30/2023
16:30
2.00 SURFAC, DRILLOUT BHAH P PJSM, from surface to 144' M/U 9 7/8"
intermediate BHA as per SLB DD, P/U
S/O wt.- 63k
0.0 144.0
10/30/2023
16:30
10/30/2023
17:15
0.75 SURFAC, DRILLOUT TRIP P RIH from 144' to 849', with 5" Hwdp/jar
stands from derrick, P/U S/O 92k
144.0 849.0
10/30/2023
17:15
10/30/2023
20:00
2.75 SURFAC, DRILLOUT TRIP P RIH from 849' to 2590', single in from
shed with 5"drill pipe, S/O- 104k, P/U
120k
849.0 2,590.0
10/30/2023
20:00
10/30/2023
20:15
0.25 SURFAC, DRILLOUT CIRC P Break circ with 500 GPM 1090 PSI,
F/O=19% shallow pulse test MWD
(good)
2,590.0 2,590.0
10/30/2023
20:15
10/30/2023
22:00
1.75 SURFAC, DRILLOUT CIRC P Circ and condition mud for casing test
with 600 GPM 1380 PSI 40 RPM 5k TQ,
F/O 22% P/U 120k, S/O 104k
2,590.0 2,590.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 10/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/30/2023
22:00
10/30/2023
22:45
0.75 SURFAC, DRILLOUT PRTS P Shut down pumps, blow down top drive,
rig up test equipment, test 10.75" 45.5#
L-80 casing to 3000psi for 30mins
charted with 3.6bbls (36 strokes) mud
wt=9.7ppg, bleed off 3bbls to trip tank.
2,590.0 2,590.0
10/30/2023
22:45
10/30/2023
23:00
0.25 SURFAC, DRILLOUT WASH P Break circ with 500 GPM, 1020 PSI, P/U
120k , S/O 108k, F/O 16%, wash down
from 2590', tag top of cement @ 2668'
with 10k.
2,590.0 2,668.0
10/30/2023
23:00
10/31/2023
00:00
1.00 SURFAC, DRILLOUT DRLG P Drill cement from 2668' to 2688'. With
550 GPM, 1200 PSI, 60 RPM, 5k TQ,
F/O 16%, P/U 120k S/O 108k ROT
109k.
2,668.0 2,688.0
10/31/2023
00:00
10/31/2023
06:00
6.00 SURFAC, DRILLOUT DRLG P Drill cement from 2688' to 2784'. With
550 GPM, 1200 PSI, 60 RPM, 5k TQ,
F/O 16%, P/U 120k S/O 108k ROT
109k. Work through shoe 3x times
observe no over pull. (SIMOPS picking
up 4" dril pipe racking in derrick)
2,688.0 2,784.0
10/31/2023
06:00
10/31/2023
06:45
0.75 SURFAC, DRILLOUT DRLG P Drill 20" new formation from 2784' to
2804'MD GPM 500, PSI 1100, F/O
18%, RPM 100, TQ 6k, WOB 13.5k
POOH to 2742' L/D single
2,784.0 2,804.0
10/31/2023
06:45
10/31/2023
08:15
1.50 SURFAC, DRILLOUT CIRC P Circulate and Condition from FIT /LOT
P/U 11k S/O 116k Mud in and out 9.7
ppg
2,742.0 2,742.0
10/31/2023
08:15
10/31/2023
08:45
0.50 SURFAC, DRILLOUT RURD P R/U for LOT/FIT flood lines space out
and close upper pipe rams.
2,742.0 2,742.0
10/31/2023
08:45
10/31/2023
09:45
1.00 SURFAC, DRILLOUT LOT P LOT. Pump 9.7 ppg spud mud at 5 spm,
21 stks (2.1 bbls) to 845 psi. Shut in
and observe psi drop to 300 psi in 10
min. Open up wellbore and record 2.0
bbls bled back to the trip tank.
Determine breakover at 795 psi - 15.7
EMW.
2,742.0 2,742.0
10/31/2023
09:45
10/31/2023
10:00
0.25 SURFAC, DRILLOUT TRIP P RIH from 2742' MD to 2775' MD on
elevators.
2,742.0 2,775.0
10/31/2023
10:00
10/31/2023
11:00
1.00 SURFAC, DRILLOUT REAM P Wash and Ream from 2775' MD to
2804' MD GPM 550, PSI 1120, RPM 50,
TQ 6k, F/O 20%, ECD 11.32, ROT 113k
2,775.0 2,804.0
10/31/2023
11:00
10/31/2023
12:00
1.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 2804' to 2857'
MD, 2618' TVD, WOB=5k, GPM=600,
PSI=805, RPM=80, TQ=4k, F/O 18%,
ECD=9.44, P/U=126k, S/O=122k,
RT=117k. ADT 1, BIT HRS 1, JARS,
MAX GAS 15. Displace to 9.0 ppg FWP
on the fly.
2,804.0 2,857.0
10/31/2023
12:00
10/31/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 2857' to 3339'
MD, 2905' TVD, WOB=7k, GPM=650,
PSI=1085, RPM=120, TQ=5k, F/O 20%,
ECD=19.09, P/U=125k, S/O=114k,
RT=115k. ADT 4.01, BIT HRS 5.50,
JARS 24.05, MAX GAS 39
2,857.0 3,339.0
10/31/2023
18:00
11/1/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 3339' to 3935'
MD, 3188' TVD, WOB=8k, GPM=650,
PSI=1085, RPM=120, TQ=5k, F/O 20%,
ECD=10.09, P/U=129k, S/O=114k,
RT=116k. ADT 4.23, BIT HRS 9.73,
JARS 28.25, MAX GAS 39
3,339.0 3,935.0
11/1/2023
00:00
11/1/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 3935' MD to
4472' MD, 3441' TVD, WOB=8k,
GPM=650, PSI=1507, RPM=120,
TQ=6k, F/O 20%, ECD=11.23,
P/U=130k, S/O=113k, RT=115k. ADT
4.34, BIT HRS 14.07, JARS 32.59, MAX
GAS 17
3,935.0 4,472.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 11/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/1/2023
06:00
11/1/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 4472' MD ' to
4972' MD, 3659' TVD, WOB=8k,
GPM=700, PSI=1814, RPM=150,
TQ=5k, F/O 22%, ECD=11.59,
P/U=131k, S/O=116k, RT=121k. ADT
4.41, BIT HRS 18.48, JARS 37.00, MAX
GAS 134
4,472.0 4,972.0
11/1/2023
12:00
11/1/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 4492' MD ' to
5559' MD, 3931' TVD, WOB=10k,
GPM=700, PSI=1837, RPM=150,
TQ=6k, F/O 22%, ECD=11.43,
P/U=136k, S/O=122k, RT=122k. ADT
4.39, BIT HRS 22.87, JARS 41.39, MAX
GAS 230
4,972.0 5,559.0
11/1/2023
18:00
11/2/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 5559' MD ' to
5992' MD, 4125' TVD, WOB=5k,
GPM=700, PSI=1913, RPM=150,
TQ=11k, F/O 22%, ECD=11.15,
P/U=143k, S/O=123k, RT=118k. ADT
4.10, BIT HRS 26.87, JARS 45.49, MAX
GAS 656
Top Coyote Formation - 5911' MD /
4088' TVD
5,559.0 5,992.0
11/2/2023
00:00
11/2/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 5992' MD ' to
6270' MD, 4243' TVD, WOB=12k,
GPM=700, PSI=1795, RPM=150,
TQ=8k, F/O 22%, ECD=10.78,
P/U=144k, S/O=128k, RT=132k. ADT
5.22, BIT HRS 32.19, JARS 50.71, MAX
GAS 384
5,992.0 6,270.0
11/2/2023
06:00
11/2/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 6270' MD ' to
6975' MD, 4560' TVD, WOB=12.5k,
GPM=700, PSI=2203, RPM=150,
TQ=8.5k, F/O 22%, ECD=11.49,
P/U=150k, S/O=122k, RT=136k. ADT
4.54, BIT HRS 36.73, JARS 55.26, MAX
GAS 173
6,270.0 6,975.0
11/2/2023
12:00
11/2/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 6975' MD ' to
7491' MD, 4799 TVD, WOB=4k,
GPM=710, PSI=1940, RPM=150,
TQ=6k, F/O 22%, ECD=11.07,
P/U=151k, S/O=132k, RT=134k. ADT
4.00, BIT HRS 40.73, JARS 59.25, MAX
GAS 173
6,975.0 7,491.0
11/2/2023
18:00
11/3/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 7491' MD ' to
8116' MD, 5055' TVD, WOB=12k,
GPM=720, PSI=2141, RPM=150,
TQ=8k, F/O 22%, ECD=11.15,
P/U=162k, S/O=145k, RT=143k. ADT
4.51 , BIT HRS 45.24, JARS 63.76 ,
MAX GAS 268
7,491.0 8,116.0
11/3/2023
00:00
11/3/2023
02:30
2.50 INTRM1, DRILL DDRL P Drill 9Ǭ" Interm hole from 8116' MD ' to
8335' MD, 5130' TVD, WOB=12k,
GPM=720, PSI=2215, RPM=150,
TQ=8k, F/O 21%, ECD=11.07,
P/U=161k, S/O=147k, RT=146k. ADT
1.66, BIT HRS 46.90, JARS 65.42, MAX
GAS 211
8,116.0 8,335.0
11/3/2023
02:30
11/3/2023
03:00
0.50 INTRM1, TRIPCAS SRVY P Obtain final survey's and SPR's as per
DD
8,335.0 8,335.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 12/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/3/2023
03:00
11/3/2023
06:00
3.00 INTRM1, TRIPCAS BKRM P BROOH from 8335'MD to 7770'MD,
with GPM=720, PSI=2215, RPM=150,
TQ=8k, F/O 21%, ECD=10.48,
P/U=161k, S/O=147k, RT=146k. Rack 1
stand back after each bottoms up for 3
stands
8,335.0 7,770.0
11/3/2023
06:00
11/3/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 7770'MD to 6000'MD,
with GPM=720, PSI=1640, RPM=150,
TQ=8k, F/O 22%, ECD=10.84,
P/U=136k. L/D 5" Drill pipe to pipe shed
Monitoring displacement at #1-5 Pits
7,770.0 6,000.0
11/3/2023
12:00
11/3/2023
18:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 6000'MD to 4450'MD,
with GPM=720, PSI=1640, RPM=150,
TQ=8k, F/O 22%, ECD=10.73,
P/U=126k. L/D 5" Drill pipe to pipe shed
Monitoring displacement at #1-5 Pits
6,000.0 4,450.0
11/3/2023
18:00
11/3/2023
22:30
4.50 INTRM1, TRIPCAS BKRM P BROOH from 4450'MD to 2865'MD,
with GPM=720, PSI=1530, RPM=150,
TQ=8k, F/O 22%, ECD=10.73,
P/U=107k. L/D 5" Drill pipe to pipe shed
Monitoring displacement at #1-5 Pits
4,450.0 2,865.0
11/3/2023
22:30
11/3/2023
22:45
0.25 INTRM1, TRIPCAS OWFF P OWFF (static) 2,865.0 2,865.0
11/3/2023
22:45
11/4/2023
00:00
1.25 INTRM1, TRIPCAS BKRM P BROOH from 2865'MD to 2584'MD,
with GPM=710, PSI=1250, RPM=150,
TQ=8k, F/O 22%, ECD=10.73,
P/U=107k. L/D 5" Drill pipe to pipe shed
Monitoring displacement at #1-5 Pits.
Note through out the BROOH hole did
not unload. We had steady flow of
cutting coming over shaker at all times.
Once in casing, circulated bottoms up
with no increase of cutting load. ECD's
did change from 10.48ppg to 11.6ppg
and dropped back to 10.55ppg.
2,865.0 2,584.0
11/4/2023
00:00
11/4/2023
02:15
2.25 INTRM1, TRIPCAS BKRM P Continue BROOH from 2584‘MD to
2017‘MD, GPM 710, PSI 1248, RPM 60,
TQ 1k. F/O 22%, ECD 10.23 ppg, P/U
98k. Monitor displacement via pit #1-5.
L/D stands with 90ft mousehole.
2,584.0 2,017.0
11/4/2023
02:15
11/4/2023
03:00
0.75 INTRM1, TRIPCAS BKRM P Continue BROOH from 2017‘MD to
1921‘MD, GPM 710, PSI 1998, RPM 60,
TQ 1k. F/O 22%, ECD 10.46 ppg, P/U
98k. Monitor displacement via pit #1-5.
Pump 60 bbls 35 ppb hi-vis sweep,
Circulate 2x bottoms up while BROOH.
2,017.0 1,921.0
11/4/2023
03:00
11/4/2023
03:45
0.75 INTRM1, TRIPCAS BKRM P Continue BROOH from 1921‘MD to
1890‘MD, GPM 710, PSI 1176, RPM 60,
TQ 1k. F/O 22%, ECD 10.15 ppg, P/U
98k. Monitor displacement via pit #1-5.
L/D stands with 90ft mousehole. Pump
30bbls 35 ppb hi-vis sweep with nut plug
while BROOH.
1,921.0 1,890.0
11/4/2023
03:45
11/4/2023
04:00
0.25 INTRM1, TRIPCAS OWFF P OWFF (static). 1,890.0 1,890.0
11/4/2023
04:00
11/4/2023
05:45
1.75 INTRM1, TRIPCAS TRIP P POOH from 1890‘MD to 890‘MD, laying
down 5" drill pipe, P/U 87K, Monitor
displacement on trip tank.
1,890.0 890.0
11/4/2023
05:45
11/4/2023
06:15
0.50 INTRM1, TRIPCAS OWFF P OWFF prior to L/D BHA (static). 890.0 890.0
11/4/2023
06:15
11/4/2023
10:00
3.75 INTRM1, TRIPCAS BHAH P POOH from 890'MD laying down 8
stands 5'' HWDP and BHA per SLB
Rep.
890.0 0.0
11/4/2023
10:00
11/4/2023
11:00
1.00 INTRM1, TRIPCAS CLEN P Clean and clear rig floor. L/D BHA via
beaverslide.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 13/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/4/2023
11:00
11/4/2023
11:30
0.50 INTRM1, TRIPCAS BOPE P Flush BOP stack with 750 GPM, 50 PSI,
B/D top drive.
0.0 0.0
11/4/2023
11:30
11/4/2023
12:00
0.50 INTRM1, CASING BOPE P Pull wear bushing as per Cameron Rep. 0.0 0.0
11/4/2023
12:00
11/4/2023
12:30
0.50 INTRM1, CASING BOPE P Set test plug as per Cameron Rep. 0.0 0.0
11/4/2023
12:30
11/4/2023
14:30
2.00 INTRM1, CASING BOPE P Close blind rams change out upper
rams to 7-5/8'' solid body. R/U test
equipment.
0.0 0.0
11/4/2023
14:30
11/4/2023
15:45
1.25 INTRM1, CASING BOPE P Test upper pipe rams: 7-5/8'' solid to 250
low/4000 high, annular 250 low/3500
high for 5 minutes low/high, charted.
R/D test equipment and blow down
lines.
0.0 0.0
11/4/2023
15:45
11/4/2023
16:45
1.00 INTRM1, CASING WWWH P Dummy run 7-5/8'' hanger as per
Cameron Rep. Load shoulder to rig floor
~ 38.10'.
0.0 0.0
11/4/2023
16:45
11/4/2023
19:00
2.25 INTRM1, CASING RURD P Rig up to run 7-5/8'' casing as per
Doyon casing, double check running
order. Hold PJSM on running 7-5/8"
intermediate casing.
0.0 0.0
11/4/2023
19:00
11/5/2023
00:00
5.00 INTRM1, CASING PUTB P Run 7-5/8" 29.7# & 33.7# L80 Hyd563
casing as per detail from surface to
1816'MD. M/U torque on 29.7# ~ 10,300
ft/lbs, M/U torque on 33,7# ~ 12,100
ft/lbs, S/O 95k, filling pipe on the fly via
Volant tool and topping off every 10 jts,
monitoring displacement on pit #1 & pill
pit #2. Baker loc first 3 jts. Check float,
Float held.
0.0 1,816.0
11/5/2023
00:00
11/5/2023
01:00
1.00 INTRM1, CASING PUTB P Run 7 5/8" 29.7# & 33.7# L80 HYD563
casing as per detail, M/U torque on
29.7# 10,300 FT/LBS, M/U torque on
33,7# 12,100 FT/LBS, from 1816' MD to
2762' MD, S/O 107K. Filling pipe on the
fly via Volant tool topping off every 10
jts, monitoring displacement on pit #1 &
pill pit #2.
1,816.0 2,762.0
11/5/2023
01:00
11/5/2023
01:30
0.50 INTRM1, CASING CIRC P Circulate & reciprocate from 2762‘MD to
2722‘MD, GPM = 250, PSI = 200, F/O =
8%, P/U 108K, S/O 109K, Total pumped
strokes 1265, Staging up pump rate
in .5 bbl increments to 6 bpm.
2,762.0 2,722.0
11/5/2023
01:30
11/5/2023
07:00
5.50 INTRM1, CASING PUTB P Continue to run 7 5/8" 29.7# & 33.7#
L80 HYD563 casing as per detail, M/U
torque on 29.7# 10,300 FT/LBS, M/U
torque on 33,7# 12,100 FT/LBS, from
2762' MD to 5530' MD, S/O 130K. Filling
pipe on the fly via Volant tool topping off
every 10 jts, monitoring displacement on
pit #1 & pill pit #2.
Daylight savings at 02:00 AM - Rolled
clocks back 1 hour.
2,762.0 5,530.0
11/5/2023
07:00
11/5/2023
08:00
1.00 INTRM1, CASING CIRC P Circulate & reciprocate from 5530‘MD to
5500‘MD, ICP= 2BPM, 178PSI, 3% F/O.
FCP=6BPM, 305PSI. 7%F/O.
PUW=140K, SOW=128K. total strokes
pumped 2360/236BBLS. Stage up
pumps in .5bbls increments.
5,530.0 5,500.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 14/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/5/2023
08:00
11/5/2023
11:00
3.00 INTRM1, CASING PUTB P Continue to run 7 5/8" 29.7# & 33.7#
L80 HYD563 casing as per detail, M/U
torque on 29.7# 10,300 FT/LBS, M/U
torque on 33,7# 12,100 FT/LBS, F/
5530' MD to 7000' MD, S/O WT=139K,
Filling pipe on the fly via Volant tool
topping off every 10 jts, monitoring
displacement on pit #1 & pill pit #2.
5,530.0 7,000.0
11/5/2023
11:00
11/5/2023
12:00
1.00 INTRM1, CASING CIRC P Circulate & reciprocate from 7000‘MD to
6970‘MD, ICP= 1.5BPM, 220PSI, 3%
F/O. FCP=6BPM, 375PSI. 7%F/O.
PUW=156K, SOW=136K. Total strokes
pumped=2500/250bbls. Stage up
pumps in .5bbls increments.
7,000.0 6,970.0
11/5/2023
12:00
11/5/2023
12:15
0.25 INTRM1, CASING CIRC P Circulate & reciprocate from 7000‘MD to
6970‘MD, ICP= 1.5BPM, 220PSI, 3%
F/O. FCP=6BPM, 375PSI. 7%F/O.
PUW=156K, SOW=136K. Total strokes
pumped=2730/273bbls. Stage up
pumps in .5bbls increments.
7,000.0 6,970.0
11/5/2023
12:15
11/5/2023
15:15
3.00 INTRM1, CASING PUTB P Continue to Run 7 5/8" 29.7# & 33.7#
L80 HYD563 casing as per detail, M/U
torque on 29.7# 10,300 FT/LBS, M/U
torque on 33,7# 12,100 FT/LBS, from
7000' MD to 8140' MD, S/O 145K. Filling
pipe on the fly via Volant tool topping off
every 10 JTS, monitoring displacement
on pit #1 & pill pit #2.
7,000.0 8,140.0
11/5/2023
15:15
11/5/2023
16:30
1.25 INTRM1, CASING WASH P Wash down from 8140'MD to 8290'MD
with 2BPM, 315PSI, 3%F/O.
SOW=145K.
8,140.0 8,290.0
11/5/2023
16:30
11/5/2023
16:45
0.25 INTRM1, CASING THGR P Make up 7-5/8'' mandrel casing hanger
& landing joint. wash down and land out
with 2.5BPM, 368PSI, 4% F/O.
SOW=147K.
8,290.0 8,330.0
11/5/2023
16:45
11/5/2023
18:30
1.75 INTRM1, CEMENT CIRC P Circulate, reciprocate, and condition
mud for cement job from 8327‘MD to
8312‘MD, ICP=2.5BPM, 340PSI 3%
F/O. FCP=6 BPM, 463 PSI. Stage up
pumps in .5BBLS increments. Total
strokes pumped=3720.
8,327.0 8,312.0
11/5/2023
18:30
11/5/2023
18:45
0.25 INTRM1, CEMENT RURD P Shut down-blow down top drive, close
lower IBOP, R/U to circulate through
cement hose.
8,327.0 8,327.0
11/5/2023
18:45
11/5/2023
20:00
1.25 INTRM1, CEMENT CIRC P Continue to circulate & reciprocate
condition for cement job from 8327‘MD
to 8312‘MD, ICP=2.5BPM, 340PSI 3%
F/O. FCP=6 BPM, 463 PSI. Stage
pumps up in .5BBLS increments.
8,327.0 8,312.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 15/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/5/2023
20:00
11/5/2023
23:15
3.25 INTRM1, CEMENT CMNT P Perform cement job for 7-5/8”"
intermediate. casing as per Halliburton
program, Flood lines with 5 bpm H2O
278 psi, Pressure Test lines to 4000psi.
Drop #1 bottom plug , pump 60 bbls
tuned 10.5 ppg spacer @ 3.75 bpm/ 573
psi 12% F/O, Drop #2 bottom plug,
pump 142 bbls 15.3 ppg primary cmt
with BM11 @ 6 bpm 787 psi 14% f/o,
pump 22 bbls 15.3 ppg primary cmt
without BM11 @ 4 bpm 275 psi 10% f/o,
Drop top plug, pump 20 bbls fresh H2O,
line up to rig pumps to displace. with
337 bbls @ 6 bpm 207 psi 14% f/o f/
2620 strokes. Cont. displacement @ 6
bpm 1045 psi F/O 13% f/ 3400 strokes,
Slow rate to 3 bpm 852 psi f/200
strokes, Slow rate to 2.5 bpm 887 psi for
200 strokes, Slow rate t/3 bpm @ 975
psi, Did not Bump plug. Stop pumping at
3593 strokes hold for 10 min. Bleed off/
check floats. Shut in to monitor floats.
Cement in place at 23:15 hrs.
8,327.0 8,330.0
11/5/2023
23:15
11/6/2023
00:00
0.75 INTRM1, CEMENT CMNT P Observed flow @ Volant cement valve,
shut in the well, R/U to observe
pressure, open valves & monitor
pressure for 30 minutes. No pressure
build up.
8,330.0 8,330.0
11/6/2023
00:00
11/6/2023
01:00
1.00 INTRM1, CEMENT CMNT P After 30 minutes monitoring, pressure
on casing string did not increase. R/D
chart recorder, open volant cement line
valve and monitior for additional 30
minutes. No flow - well is static.
8,330.0 8,330.0
11/6/2023
01:00
11/6/2023
03:00
2.00 INTRM1, CEMENT RURD P Pull landing joint as per Cameron Rep.
M/U Packoff running tool to landing joint
install packoff. Test packoff to 5000 psi
witness by CPAI Rep.
0.0 0.0
11/6/2023
03:00
11/6/2023
04:00
1.00 INTRM1, CEMENT RURD P R/D Doyon Volant casing tools and
equipment and remove from rig floor.
0.0 0.0
11/6/2023
04:00
11/6/2023
07:00
3.00 INTRM1, WHDBOP RURD P Change out saver sub from NC 50 to
XT39, Change upper rams from 7-5/8"
solid to 3-1/2" x 6" VBR's.
0.0 0.0
11/6/2023
07:00
11/6/2023
09:00
2.00 INTRM1, WHDBOP RURD P Set test plug as per Cameron Rep. R/U
and test equipment, flood lines.
0.0 0.0
11/6/2023
09:00
11/6/2023
10:00
1.00 INTRM1, WHDBOP RURD P Shell test. Observe leak from IA valve
due to test plug not being seated.
0.0 0.0
11/6/2023
10:00
11/6/2023
11:30
1.50 INTRM1, WHDBOP BOPE T Pull test and inspect test plug. No visual
damage. Reran and seat plug. Attempt
to shell test. Unsuccessful shell test.
0.0 0.0
11/6/2023
11:30
11/6/2023
12:00
0.50 INTRM1, WHDBOP BOPE T Pull test plug replace seals. Flush stack
and packoff profile.
0.0 0.0
11/6/2023
12:00
11/6/2023
12:30
0.50 INTRM1, WHDBOP BOPE T Rig down stack washer, blow down top
drive, set test plug as per Cameron Rep.
0.0 0.0
11/6/2023
12:30
11/6/2023
13:00
0.50 INTRM1, WHDBOP SVRG P Rig Service, Lubricate top drive,
drawworks pipe skate and iron
roughneck.
0.0 0.0
11/6/2023
13:00
11/6/2023
14:30
1.50 INTRM1, WHDBOP BOPE T Trouble shoot test pump. 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 16/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/6/2023
14:30
11/6/2023
21:00
6.50 INTRM1, WHDBOP BOPE P Test BOPE all tests to 250 low 4,000
high for 5 charted minutes. with
exception of manual operated & super
choke tested to 250 low & 2,000 psi for
5 charted minutes & annular tests to
3500 psi, with 4" test jt test annular, 3-
1/2" x 6" upper rams, 3-1/2" x 6" lower
rams, with 4-1/2" test jt test 3-1/2" x 6"
upper rams & 3-1/2" x 6" Lower rams,
test choke valves 1-14, manual
operated & super choke, choke & kill
manuals & Hcr's, 4" valve on kill line, 4"
FOSV x2, 4" dart valve, upper & lower
IBOP; blind/ shear rams; perform
Koomey drawdown, acc = 3000 psi.
manifold = 1500 psi. acc = 1900 psi
after all functions on bottles, 8 seconds
for 200 psi. build with 2 electrics.
pumps, 49 seconds to build a full
system. pressure with 2 electric & 2 air
pumps, 6 bottle average=1978 closing
times annular = 20 sec. upper rams = 6
sec. blind / shears = 7 seconds. Lower
rams = 6 sec. choke Hcr = 1 sec. kill
HCR = 1 sec; test PVT gain/loss and
flow out alarms, test LEL and H2S
alarms; AOGCC Rep Sully Sullivan
waived witness @ 09:21 hrs on 11/5/23
0.0 0.0
11/6/2023
21:00
11/6/2023
22:00
1.00 INTRM1, WHDBOP RURD P Rig down and blow down all testing
equipment.
0.0 0.0
11/6/2023
22:00
11/7/2023
00:00
2.00 INTRM1, WHDBOP SLPC P PJSM slip and cut drill line 3 wraps. 0.0 0.0
11/7/2023
00:00
11/7/2023
01:30
1.50 INTRM1, WHDBOP BOPE T R/U Test plug and test joint, Test HCR
and manual choke to 250 psi low and
4000 high psi, (charted). Test were over
looked by Driller. Rig back up to finish
BOPE test sequence.
0.0 0.0
11/7/2023
01:30
11/7/2023
02:00
0.50 INTRM1, WHDBOP SVRG P Rig service lubricate rig. 0.0 0.0
11/7/2023
02:00
11/7/2023
03:30
1.50 INTRM1, WHDBOP PRTS P R/U to test 7-5/8" casing to 4000psi for
30 minutes on chart @ 5 spm 7.4 bbls
pumped and 6.1 bbls bled back. (Good
Test) Charted R/D and blow down test
equipment from IA.
0.0 0.0
11/7/2023
03:30
11/7/2023
06:00
2.50 INTRM1, WHDBOP PRTS P R/U injection line on OA. Flood lines
with mud and purge air from lines,
Perform injection test on OA pumped
6bbls to fill OA 1 bbl to presure up to
854 psi pressure bled back to 687 psi in
10 minutes. Bleed bac k to pit #5 1bbl.
R/D injection lines.
0.0 0.0
11/7/2023
06:00
11/7/2023
07:00
1.00 INTRM1, WHDBOP WWSP P M/U wearbushing running tool. Inspect
wearbushing OD 10-3/4", ID 10", length
13". Install wearbushing as per
Cameron hand. Screw in lock downs.
0.0 0.0
11/7/2023
07:00
11/7/2023
09:45
2.75 INTRM1, DRILLOUT BHAH P PJSM P/U 6-1/2" production BHA as per
SLB DD/MWD to 192" MD.
0.0 192.0
11/7/2023
09:45
11/7/2023
11:15
1.50 INTRM1, DRILLOUT TRIP P TIH from 192'MD to 2844'MD. S/O 78k.
Monitoring displacement on pit #1 and
pill pit #2. Filling pipe every 20 stands.
192.0 2,844.0
11/7/2023
11:15
11/7/2023
12:00
0.75 INTRM1, DRILLOUT SRVY P Shallow hole test MWD tools - 250
GPM, 1449 PSI, 5% F/O. Good test.
Send downlink to turn on Sonicscope
tools for real time to logging of 100' free
ring casing. Log @ 450fph.
2,844.0 2,844.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 17/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/7/2023
12:00
11/7/2023
12:30
0.50 INTRM1, DRILLOUT DLOG P Real time logging with Sonicscope from
2844'MD to 3030'MD, 250 GPM, 1449
PSI, 5% F/O. Log @ 450fph.
2,844.0 3,030.0
11/7/2023
12:30
11/7/2023
12:45
0.25 INTRM1, DRILLOUT TRIP P RIH from 3030'MD to 3500'MD. S/O
84k. Monitoring displacement on pit #1
and pill pit #2. Filling pipe every 20
stands.
3,030.0 3,500.0
11/7/2023
12:45
11/7/2023
16:15
3.50 INTRM1, DRILLOUT DLOG P Real time log with Sonicscope from
3500'MD to 4357'MD @ 600fph 250
GPM, 1506 PSI, 5% F/O S/O 87k. M/U
stands in 90' mouse hole. Real time
Sonicscope Log TOC @ 3841'
3,500.0 4,357.0
11/7/2023
16:15
11/7/2023
18:30
2.25 INTRM1, DRILLOUT TRIP P TIH picking up singles from pipe shed
from 4357'MD to 4921'MD, S/O 92k,
Monitoring displacement on pit #1 and
pill pit #2. Filling pipe every 20 stands.
4,357.0 4,921.0
11/7/2023
18:30
11/7/2023
19:15
0.75 INTRM1, DRILLOUT RURD P PJSM Remove trip nipple, Install RCD
bearing onto string. Set bearing in clamp
and secure. Install drip pan and secure
same.
4,921.0 4,921.0
11/7/2023
19:15
11/7/2023
22:00
2.75 INTRM1, DRILLOUT MPDA P Break circulation through MPD chokes.
Establish reading between rig, MPD and
Novos. Ramp up and down with pumps
to tune chokes at different settings -
10ppg, 10.5ppg and 11ppg while
circulating with backside pump.
4,921.0 4,921.0
11/7/2023
22:00
11/8/2023
00:00
2.00 INTRM1, DRILLOUT MPDA P PJSM, Blow down top drive remove drip
nipple, Pull bearing off drill pipe, install
trip nipple.
4,921.0 4,921.0
11/8/2023
00:00
11/8/2023
04:00
4.00 INTRM1, DRILLOUT TRIP P RIH with 6-1/2'' production BHA. single
in from shed with 4''drill pipe from 4921'
to 7945'. S/O 98k monitor displacement
on pit#1, pill#2. filling pipe every 20
stands.
4,921.0 7,945.0
11/8/2023
04:00
11/8/2023
04:45
0.75 INTRM1, DRILLOUT WASH P Wash down from 7945 'md to 8242' MD
Top of cement @ 8162'MD with
250gpm, 1808psi, 6% F/O S/O 98k.
slack off 11k to confirm
7,945.0 8,242.0
11/8/2023
04:45
11/8/2023
06:00
1.25 INTRM1, DRILLOUT DRLG P Drill out float collar from 8,242'MD to
8,244'MD - adjusting parameters as
directed. 250 GPM, 1920 PSI, 5%, 60
RPM, 6k TQ, rt=112k, WOB=2-5k.
8,242.0 8,244.0
11/8/2023
06:00
11/8/2023
08:30
2.50 INTRM1, DRILLOUT DRLG P Continue drill out float collar ream up
from 8,244'MD to 8,240'MD 4x.
8,244.0 8,240.0
11/8/2023
08:30
11/8/2023
10:00
1.50 INTRM1, DRILLOUT CIRC P Circulate bottoms up clean and clear
rubber debris
8,244.0 8,244.0
11/8/2023
10:00
11/8/2023
10:45
0.75 INTRM1, DRILLOUT SFTY P PJSM on plan forward 8,244.0 8,244.0
11/8/2023
10:45
11/8/2023
12:00
1.25 INTRM1, DRILLOUT WWWH P Wash down from 8244' MD to 8327' tag
shoe from 8,327'MD to 8330 drill out
shoe and rathole to 8335'MD @ gpm
250, RPM 60, PSI 1,830, F/O 14%, TQ
8k ECD 10.05 work through shoe per
DD to ensure clean
8,244.0 8,335.0
11/8/2023
12:00
11/8/2023
12:15
0.25 INTRM1, DRILLOUT DRLG P Drill new formation from 8335'MD to
8355'MD @ GPM 250, RPM 60, TQ 8k,
ECD 10.37 ppg, PSI 1930.
8,335.0 8,355.0
11/8/2023
12:15
11/8/2023
13:15
1.00 INTRM1, DRILLOUT CIRC P Circulate, rotate & reciprocate from
8335‘MD to 8320‘MD, with GPM 250,
PSI 1880, F/O 13%, RPM 60, TQ 8k,
ECD 10.37ppg, P/U 104k, S/O 109k,
while pumping 10 ppg hi-vis nut plug
sweep & getting uniform mud all the way
around prior to fit, total pumped
strokes=4123.
8,335.0 8,320.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 18/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/8/2023
13:15
11/8/2023
14:30
1.25 INTRM1, DRILLOUT FIT P R/U for FIT. Perform FIT @ 5 spm to
1730 psi max. Shut in and monitor for
10 minutes, 3.2 bbls pumped, 3 bbls
bled back. R/D & blow down test
equipment. 16 ppg EMW FIT.
8,320.0 8,320.0
11/8/2023
14:30
11/8/2023
16:30
2.00 PROD1, DRILL MPDA P PJSM, install MPD bearing per MPD
Reps. Establish flow through choke per
MPD hands.
8,320.0 8,320.0
11/8/2023
16:30
11/8/2023
18:15
1.75 PROD1, DRILL CIRC P PJSM on displacement, circulate, rotate
& reciprocate from 8335‘MD to
8320‘MD, with GPM 250, PSI 1880, F/O
13%, RPM 60, TQ 8k, ECD 10.26 ppg,
P/U 112k, S/O 109k, while displacing
well to 9.0 ppg Kla-shield mud. Total
strokes pumped=3879.
8,335.0 8,320.0
11/8/2023
18:15
11/8/2023
19:00
0.75 PROD1, DRILL OWFF P OWFF @ shakers (static), change out
SLB hook load sensor and calibrate.
8,320.0 8,320.0
11/8/2023
19:00
11/8/2023
21:45
2.75 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
8355‘MD to 8460‘MD 5164‘TVD, WOB
10 k, GPM 250, PSI 1588, RPM 55, TQ
6.5 k, F/O 7 %, ECD 9.6 ppg, P/U 115k,
ROT 101k, MPD connection back PSI
160.
8,355.0 8,460.0
11/8/2023
21:45
11/9/2023
00:00
2.25 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
8460’MD to 8603’MD 5198'TVD, WOB
10 k, GPM 250, PSI 1670, RPM 120,
TQ 6.5 k, flow out= 7%, ECD 9.6 ppg,
P/U 115 k, ROT 102k, ADT 3.15, Total
bit hrs 3.44, MPD connection back PSI
225.
8,460.0 8,603.0
11/9/2023
00:00
11/9/2023
02:00
2.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
8603’MD to 8788’MD 5198'TVD, WOB
10 k, GPM 250, PSI 1670, RPM 120,
TQ 6.5 k, flow out= 7%, ECD 9.6 ppg,
P/U 115 k, ROT 102k, ADT 3.15, Total
bit hrs 3.44, MPD connection back PSI
225.
8,603.0 8,788.0
11/9/2023
02:00
11/9/2023
15:00
13.00 PROD1, DRILL WAIT T Phase 3 weather conditions, circulate
and Condition mud. with GPM 80, PSI
523, RPM 20, ECD 9.9 ppg, P/U 113k
S/O 113k TQ 4.5
8,788.0 8,788.0
11/9/2023
15:00
11/9/2023
15:30
0.50 PROD1, DRILL SFTY T PJSM on L/D drill pipe while stripping 8,788.0 8,788.0
11/9/2023
15:30
11/9/2023
17:00
1.50 PROD1, DRILL STRP T POOH from 8788' to 8321' stripping out
hole while laying down drill pipe using
MPD system. 8/17 fpm, 134/230 psi
GPM 150.
8,788.0 8,321.0
11/9/2023
17:00
11/9/2023
22:00
5.00 PROD1, DRILL WAIT T Phase 3 weather conditions, circulate
and Condition mud. with GPM 80, PSI
523, RPM 20, ECD 9.9 ppg, P/U 113k
S/O 113k TQ 4.5
8,321.0 8,321.0
11/9/2023
22:00
11/9/2023
22:45
0.75 PROD1, DRILL WAIT T Phase 3 weather conditions, with drill
string in shoe holding back pressure 275
psi.
8,321.0 8,321.0
11/9/2023
22:45
11/10/2023
00:00
1.25 PROD1, DRILL WAIT T Phase 3 weather conditions, with drill
string in shoe, Circulating with charging
pump on back side through MPD choke
@ 8 psi
8,321.0 8,321.0
11/10/2023
00:00
11/11/2023
00:00
24.00 PROD1, DRILL WAIT T Phase 3 weather conditions, with drill
string in shoe, Circulating with charging
pump on back side through MPD choke
@ 8 psi
8,321.0 8,321.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 19/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/11/2023
00:00
11/11/2023
06:00
6.00 PROD1, DRILL WAIT T Waiting on roads to clear (phase
conditions). Clean off stairs, landings
and walkways around the rig / clear
snow from the pad and parking areas.
Work on annual crew evaluations,
monitor well via charge pump.
8,320.0 8,320.0
11/11/2023
06:00
11/11/2023
12:00
6.00 PROD1, DRILL SEQP T PJSM on after phase weather &
prepping to resume Ops. Blow down top
drive, choke manifold choke/kill HCR,
gas buster blow down through mud
transfer lines. Verify cellar pump blown
down. Check doorways, snow & ice
removal on walls stairways & egresses,
re-start air heaters, de-ice crown, derrick
inspection, grease blocks, top drive
inspection & grease, transfer mud from
rock, change out intake filters on draw
works & mud pumps, C/O hydraulic
hose on ST-100, de-ice intakes on
Havoc systems, comms antenna,
remove snow from mud product storage
area, snow removal on pad, Magtec
tanks C/O. Continue monitor well on
charge pump.
8,320.0 8,320.0
11/11/2023
12:00
11/11/2023
13:30
1.50 PROD1, DRILL SEQP T Continue clean containment, Magtec
ops, transfer fluid from rock, verify pits in
order.
8,320.0 8,320.0
11/11/2023
13:30
11/11/2023
15:30
2.00 PROD1, DRILL CIRC T Circulate bottoms up, stage pumps up to
verify no mud drop out no cold mud,
cycle directional tools - verify still
functioning, take slow pump rates.
8,320.0 8,320.0
11/11/2023
15:30
11/11/2023
18:00
2.50 PROD1, DRILL REAM T Wash ream in hole from 8,320'MD to
8,340'MD. Experienced packing off, pull
back up into shoe, rotate & reciprocate
drill string to clean hole from 8,330' to
8,320' verifying parameters 80-100
RPM, 40-80 bbl/min, PSI 1,520, TQ 4.5-
7k WOB 1-5k. Wash and ream from
8,320'MD to 8,413'MD
8,320.0 8,314.0
11/11/2023
18:00
11/12/2023
00:00
6.00 PROD1, DRILL REAM T Continue wash and ream from 8,413'MD
to 8,788'MD with following range of
parameters GPM 180-250, PSI 930-
1600, F/O 3-9%, RPM 80-100, TQ 5-9k,
S/O 106k, ECD 9.9, work through tight
spots observed at following measured
depths @ 8557'MD , 8745'MD,
8775'MD, grease wash pipe.
8,314.0 8,788.0
11/12/2023
00:00
11/12/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
8788’MD to 9118’MD 5240'TVD, WOB
8k, GPM 275, PSI 2000, RPM 120, TQ
7.5 k, F/O 7%, ECD 10.0 ppg, P/U 132k,
ROT 90k, S/O 110k, ADT 4.60, Total bit
hrs 9.84, MPD connection back PSI
230.
8,788.0 9,118.0
11/12/2023
06:00
11/12/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
9118’MD to 9412’MD 5264TVD, WOB
8k, GPM 275, PSI 2068, RPM 120, TQ
6 k, F/O 7%, ECD 10.14 ppg, P/U 130k,
ROT 90k, S/O 114k, ADT 4.61, Total bit
hrs 14.45, MPD connection back PSI
230.
9,118.0 9,412.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 20/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/12/2023
12:00
11/12/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
9412’MD to 9929’MD 5264TVD, WOB
6k, GPM 275, PSI 2151, RPM 120, TQ
6 k, F/O 7%, ECD 10.34 ppg, P/U 130k,
ROT 90k, S/O 114k, ADT 4.73, Total bit
hrs 19.18, MPD connection back PSI
280.
9,412.0 9,929.0
11/12/2023
18:00
11/13/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
9929’MD to 10403’MD 5265TVD, WOB
7.5k, GPM 275, PSI 2202, RPM 120,
TQ 7 k, F/O 8%, ECD 10.40 ppg, P/U
132k, ROT 84k, S/O 106k ADT 3.56,
Total bit hrs 22.74, MPD connection
back PSI 320.
9,929.0 10,403.0
11/13/2023
00:00
11/13/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
10403’MD to 10890’MD 5264TVD, WOB
7.5k, GPM 275, PSI 2203, RPM 120,
TQ 7 k, F/O 6%, ECD 10.30 ppg, P/U
133k, ROT 85k, S/O 105k ADT 4.48,
Total bit hrs 27.22, MPD connection
back PSI 300.
10,403.0 10,890.0
11/13/2023
06:00
11/13/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
10890’MD to 11396’MD 5246TVD, WOB
7.5k, GPM 275, PSI 2203, RPM 120,
TQ 7 k, F/O 6%, ECD 10.20 ppg, P/U
134k, ROT 86k, S/O 110k ADT 4.44,
Total bit hrs 31.66, MPD connection
back PSI 270.
10,890.0 11,396.0
11/13/2023
12:00
11/13/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
11396’MD to 11936’MD 5231TVD, WOB
7.5k, GPM 275, PSI 2260, RPM 120,
TQ 7 k, F/O 6%, ECD 10.45 ppg, P/U
141k, ROT 81k, S/O 109k ADT 4.53,
Total bit hrs 36.19, MPD connection
back PSI 300.
11,396.0 11,936.0
11/13/2023
18:00
11/14/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from
11936’MD to 12530’MD 5218TVD, WOB
8k, GPM 275, PSI 2268, RPM 120, TQ
7 k, F/O 6%, ECD 10.45 ppg, P/U 141k,
ROT 81k, S/O 109k ADT 4.32, Total bit
hrs 40.51, MPD connection back PSI
290.
11,936.0 12,530.0
11/14/2023
00:00
11/14/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 12,530’
MD to 13,111’ MD 5,211' TVD, WOB 8k,
GPM 275, PSI 2346, RPM 120, TQ
8.5k, F/O 7%, ECD 10.53 ppg, P/U
140k, ROT 111k, S/O 84k ADT 4.48,
Total bit hrs 44.99, MPD connection
back PSI 340.
12,530.0 13,111.0
11/14/2023
06:00
11/14/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,111’
MD to 13,618’ MD 5,201' TVD, WOB 7k,
GPM 275, PSI 2439, RPM 120, TQ 9k,
F/O 6%, ECD 10.73 ppg, P/U 141k,
ROT 106k, S/O NA, ADT 4.37, Total bit
hrs 49.36, MPD connection back PSI
370.
13,111.0 13,618.0
11/14/2023
12:00
11/14/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 13,618’
MD to 14,091’ MD 5,192' TVD, WOB 5k,
GPM 275, PSI 2503, RPM 120, TQ 10k,
F/O 7%, ECD 10.90 ppg, P/U 141k,
ROT 105k, S/O 72k ADT 4.32, Total bit
hrs 53.68, MPD connection back PSI
380.
13,618.0 14,091.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 21/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/14/2023
18:00
11/15/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,091’
MD to 14,527’ MD 5,180' TVD, WOB 7k,
GPM 275, PSI 2544, RPM 120, TQ 10k,
F/O 6%, ECD 10.75 ppg, P/U 141k,
ROT 105k, S/O 73k ADT 3.87, Total bit
hrs 57.55, MPD connection back PSI
430.
14,091.0 14,527.0
11/15/2023
00:00
11/15/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,527’
MD to 14,915’ MD 5,180' TVD, WOB 7k,
GPM 275, PSI 2576, RPM 100, TQ 9k,
F/O 8%, ECD 10.83 ppg, P/U 140k,
ROT 105k, S/O NA. ADT 4.77, Total bit
hrs 62.32, MPD connection back PSI
460.
14,527.0 14,915.0
11/15/2023
06:00
11/15/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 14,915’
MD to 15,318’ MD 5,171' TVD, WOB 8k,
GPM 275, PSI 2615, RPM 100, TQ 9k,
F/O 7%, ECD 10.89 ppg, P/U 143k,
ROT 102k, S/O NA. ADT 4.69, Total bit
hrs 67.01, MPD connection back PSI
470.
14,915.0 15,318.0
11/15/2023
12:00
11/15/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,318’
MD to 15,833’ MD 5,163' TVD, WOB
8.5k, GPM 275, PSI 2650, RPM 100,
TQ 10k, F/O 7%, ECD 11.01 ppg, P/U
141k, ROT 103k, S/O 63K. ADT 4.63,
Total bit hrs 71.64, MPD connection
back PSI 440.
15,318.0 15,833.0
11/15/2023
18:00
11/16/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 15,833’
MD to 16,362' MD 5,159' TVD, WOB
10k, GPM 275, PSI 2784, RPM 120, TQ
10k, F/O 7%, ECD 11.17 ppg, P/U 141k,
ROT 103k, S/O NA. ADT 4.62, Total bit
hrs 76.26, MPD connection back PSI
440.
15,833.0 16,362.0
11/16/2023
00:00
11/16/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 16,362’
MD to 16,927' MD 5,164' TVD, WOB 8k,
GPM 275, PSI 2875, RPM 120, TQ 11k,
F/O 7%, ECD 11.41 ppg, P/U 144k,
ROT 102k, S/O NA. ADT 4.5, Total bit
hrs 80.76, MPD connection back PSI
370.
16,362.0 16,927.0
11/16/2023
06:00
11/16/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 16,927’
MD to 17,456' MD 5,164' TVD, WOB 7k,
GPM 275, PSI 2972, RPM 120, TQ 10k,
F/O 7%, ECD 11.47 ppg, P/U 152k,
ROT 113k, S/O NA. ADT 3.99, Total bit
hrs 84.75, MPD connection back PSI
380.
16,927.0 17,456.0
11/16/2023
12:00
11/16/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,456’
MD to 17,948' MD 5,166' TVD, WOB
11k, GPM 275, PSI 3000, RPM 110, TQ
11k, F/O 7%, ECD 11.54 ppg, P/U 163k,
ROT 107k, S/O NA. ADT 4.46, Total bit
hrs 89.21, MPD connection back PSI
400.
17,456.0 17,948.0
11/16/2023
18:00
11/17/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 17,948’
MD to 18,356' MD 5,170' TVD, WOB 7k,
GPM 275, PSI 3096, RPM 120, TQ 11k,
F/O 7%, ECD 11.7 ppg, P/U 164k, ROT
115k, S/O NA. ADT 4.31, Total bit hrs
93.52, MPD connection back PSI 455.
17,948.0 18,356.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 22/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/17/2023
00:00
11/17/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,356’
MD to 18,816' MD 5,167' TVD, WOB 9k,
GPM 275, PSI 3205, RPM 120, TQ 11k,
F/O 7%, ECD 11.75 ppg, P/U 165k,
ROT 115k, S/O NA. ADT 4.75, Total bit
hrs 98.27, MPD connection back PSI
455.
18,356.0 18,816.0
11/17/2023
06:00
11/17/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 18,816’
MD to 19,320' MD 5,167' TVD, WOB 7k,
GPM 275, PSI 3182, RPM 120, TQ 11k,
F/O 7%, ECD 11.76 ppg, P/U 186k,
ROT 122k, S/O NA. ADT 4.19, Total bit
hrs 102.46, MPD connection back PSI
430.
Observe mwt increase to 9.4+ going in
and 9.5 coming out @ ~19,000' MD.
Decision made to dump and dilute 580
bbls w/ 8.9 mud.
18,816.0 19,320.0
11/17/2023
12:00
11/17/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,320’
MD to 19,849' MD 5,164' TVD, WOB 7k,
GPM 275, PSI 3060, RPM 120, TQ 12k,
F/O 7%, ECD 11.63 ppg, P/U 190k,
ROT 127k, S/O NA. ADT 4.56, Total bit
hrs 107.02, MPD connection back PSI
430.
19,320.0 19,849.0
11/17/2023
18:00
11/18/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 19,849’
MD to 20,387' MD 5,165' TVD, WOB 8k,
GPM 275, PSI 3302, RPM 120, TQ 12k,
F/O 6%, ECD 11.72 ppg, P/U 192k,
ROT 129k, S/O NA. ADT 4.22, Total bit
hrs 111.24, MPD connection back PSI
480.
18,949.0 20,387.0
11/18/2023
00:00
11/18/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 20,387’
MD to 20,950' MD 5,166' TVD, WOB 8k,
GPM 275, PSI 3457, RPM 120, TQ 12k,
F/O 6%, ECD 11.88 ppg, P/U 201k,
ROT 135k, S/O NA. ADT 4.36, Total bit
hrs 115.60, MPD connection back PSI
480.
20,387.0 20,950.0
11/18/2023
06:00
11/18/2023
10:00
4.00 PROD1, DRILL DDRL P Drill 6-1/2” production hole from 20,950’
MD to 21,276' MD 5,162' TVD, WOB 6k,
GPM 275, PSI 3489, RPM 120, TQ 12k,
F/O 6%, ECD 11.88 ppg, P/U 204k,
ROT 141k, S/O NA. ADT 3.08, Total bit
hrs 118.68, MPD connection back PSI
455.
20,950.0 21,276.0
11/18/2023
10:00
11/18/2023
10:30
0.50 PROD1, TRIPCAS SRVY P Obtain final survey and downlink
powerdrive to neutral.
21,276.0 21,276.0
11/18/2023
10:30
11/18/2023
12:15
1.75 PROD1, TRIPCAS CIRC P Circ and condition mud w/ GPM 275,
PSI 3,415, RPM 120, TQ 11k, F/O 6%,
ECD 11.74, ROT WT 135k @ rate. Total
stks pumped - 9398 (946 bbls). Obtain
SPR's.
21,276.0 21,276.0
11/18/2023
12:15
11/18/2023
13:15
1.00 PROD1, TRIPCAS MPDA P Perform drawdown as per MPD
schedule/ J.O.M. MWT - 9.3, (I) psi -
460, (f) psi - 6. RPM @ 10 w/ 10k TQ.
21,276.0 21,276.0
11/18/2023
13:15
11/18/2023
14:30
1.25 PROD1, TRIPCAS OWFF P Observe wellbore at RCD head (static). 21,276.0 21,276.0
11/18/2023
14:30
11/18/2023
15:00
0.50 PROD1, TRIPCAS BKRM P Upon ramping pumps up to rate, and
going to L/D single used to TD, observe
slight packoff @ 4 bpm, 169 gpm, 2655
psi. Kill pump, L/D single.
21,276.0 21,257.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 23/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/18/2023
15:00
11/18/2023
18:00
3.00 PROD1, TRIPCAS CIRC T Slowly ramp pumps up to 169 gpm,
1910 psi. Losses observed at start of
circ. Pump 40 bbl LCM pill. Engage rot
@ 20 rpm, 10k TQ. Continue to stage
pumps up to 275 gpm, 3505 psi. Stage
rot up to 100 rpm, 12k TQ.
21,257.0 21,257.0
11/18/2023
18:00
11/18/2023
20:15
2.25 PROD1, TRIPCAS BKRM P Circ 2x B/U while BROOH racking back
1 std per B/U w/ GPM 275, PSI 3460,
RPM 120, TQ 10.5k, F/O 6%, ECD
11.66 ppg, MPD connection back PSI
480.
21,257.0 21,070.0
11/18/2023
20:15
11/18/2023
21:45
1.50 PROD1, TRIPCAS OTHR P Drop 1.75 OD well commander
activation ball to drift drill string. Pump
dn at 275 GPM, 3448 PSI, 120 RPM,
10.5k TQ for 16 min. Reduce rate to 84
GPM, 1040 PSI, 10 RPM, 9.5k TQ. Ball
on seat @ 1918 stks. Pressure up to
1600 psi and hold for 30 sec. Bleed off,
re-pressure up to 1300 psi and hold for
30 sec. Pressure up to 2975 to blow
ball by seat. Increase rate to 275 GPM
and observe 2275 PSI indicating well
commander shifted open. MPD held
11.0 EMW during operation on the
wellbore.
21,070.0 21,070.0
11/18/2023
21:45
11/18/2023
22:45
1.00 PROD1, TRIPCAS OTHR T Drop 2nd 1.75 OD well commander
activation ball to close well commander.
Pump dn at 275 GPM, 2275 PSI, 120
RPM, 10.5k TQ for 16 min. Reduce rate
to 84 GPM, 870 PSI, 10 RPM, 9k TQ.
Ball on seat @ 1905 stks. Pressure up
to 1300 psi and hold for 30 sec.
Increase pressure to 1800 psi and hold
of 30 sec. Pressure up to 3044 to blow
ball by seat. Increase rate to 275 GPM
and observe 3500 indicating well
commander closed. MPD held 11.0
EMW during operation on the wellbore.
21,070.0 21,070.0
11/18/2023
22:45
11/19/2023
00:00
1.25 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 3510, RPM
120, TQ 10.5k, F/O 7%, ECD 11.79 ppg,
MPD connection back PSI 480
maintaining 11.0 EWM.
21,070.0 20,797.0
11/19/2023
00:00
11/19/2023
06:00
6.00 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 3445, RPM
120, TQ 10k, F/O 7%, ECD 11.52 ppg,
MPD connection back PSI 480
maintaining 11.0 EWM. UP WT @ rate -
119K
20,797.0 19,350.0
11/19/2023
06:00
11/19/2023
12:00
6.00 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 3150, RPM
100 - 130, TQ 19k, F/O 6%, ECD 11.13
ppg, MPD connection back PSI 450
maintaining 11.0 EWM. UP WT @ rate -
119K
Encounter tight spot @ 19,000', 18,920',
18,617'
19,350.0 18,408.0
11/19/2023
12:00
11/19/2023
18:00
6.00 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 2900, RPM
100 - 150, TQ 9 - 12k, F/O 7%, ECD
11.59 ppg, MPD connection back PSI
450 maintaining 11.0 EWM. UP WT @
rate - 104K
Encounter tight spot @ 18,070', 17,675',
17,640'
18,408.0 17,493.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 24/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/19/2023
18:00
11/20/2023
00:00
6.00 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 2630, RPM
150, TQ 9k, F/O 7%, ECD 10.83 ppg,
MPD connection back PSI 450
maintaining 11.0 EWM. UP WT @ rate -
104K
17,493.0 15,847.0
11/20/2023
00:00
11/20/2023
07:00
7.00 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 2355, RPM
150, TQ 7k, F/O 7%, ECD 10.34 ppg,
MPD connection back PSI 360. UP WT
@ rate - 104K
SIMOPS -- L/D 4" DP via mousehole.
15,847.0 13,200.0
11/20/2023
07:00
11/20/2023
10:00
3.00 PROD1, TRIPCAS BKRM P Weight up fluid to 9.5 ppg on the fly
adding spike fluid while BROOH 1 std w/
GPM 275, PSI 2450, RPM 150, TQ 6k,
F/O 7%.
13,200.0 13,050.0
11/20/2023
10:00
11/20/2023
15:30
5.50 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 2400, RPM
150, TQ 7k, F/O 7%, ECD 10.70 ppg,
MPD connection back PSI 300. UP WT
@ rate - 109K
SIMOPS -- L/D 4" DP via mousehole.
13,050.0 11,266.0
11/20/2023
15:30
11/20/2023
16:30
1.00 PROD1, TRIPCAS BKRM T Repair E-Stop on ST-100. 11,266.0 11,266.0
11/20/2023
16:30
11/21/2023
00:00
7.50 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 2167, RPM
150, TQ 5k, F/O 7%, ECD 10.38 ppg,
MPD connection back PSI 300. UP WT
@ rate - 109K
SIMOPS -- L/D 4" DP via mousehole.
11,266.0 8,603.0
11/21/2023
00:00
11/21/2023
00:15
0.25 PROD1, TRIPCAS BKRM P BROOH w/ GPM 275, PSI 2167, RPM
150, TQ 5k, F/O 7%, ECD 10.38 ppg,
MPD connection back PSI 300. UP WT
@ rate - 109K SIMOPS -- L/D 4" DP via
mousehole.
8,603.0 8,512.0
11/21/2023
00:15
11/21/2023
01:45
1.50 PROD1, TRIPCAS PMPO P Pump OOH w/ GPM 275, PSI 2142, F/O
5%, ECD 10.48 ppg, UP WT - 127K.
Observe packoff while pulling BHA into
the shoe(x2). Slacked off ea time to
regain circ. Stage pumps up ½ bpm up
to 6 bpm, 1848 psi.
8,512.0 8,320.0
11/21/2023
01:45
11/21/2023
04:15
2.50 PROD1, TRIPCAS CIRC P Circ B/U (x4) while rot and recip pipe w/
270, PSI 2095, RPM 120, TQ 4k, F/O
4%, ECD 10.30 ppg, UP WT - 127K.
S/O WT - 84K.
8,320.0 8,320.0
11/21/2023
04:15
11/21/2023
05:45
1.50 PROD1, TRIPCAS OWFF P Dynamically relax wellbore as per MPD.
OWFF at RCD head. (static)
8,320.0 8,320.0
11/21/2023
05:45
11/21/2023
13:30
7.75 PROD1, TRIPCAS SMPD P Strip OOH to BHA as per Beyond
stripping schedule. 230 PSI while in
slips, 350 psi out. UP WT - 126K, S/O
WT - 118K. Monitor disp via pit 1.
8,320.0 700.0
11/21/2023
13:30
11/21/2023
15:00
1.50 PROD1, TRIPCAS OWFF P Dynamically relax wellbore as per MPD.
OWFF at RCD head. (static)
700.0 700.0
11/21/2023
15:00
11/21/2023
16:30
1.50 PROD1, TRIPCAS MPDA P Pull MPD bearing and install trip nipple. 700.0 700.0
11/21/2023
16:30
11/21/2023
17:15
0.75 PROD1, TRIPCAS TRIP P POOH on elevators monitor disp via TT.
SIMOPS - B/D MPD equipment.
Function BOPE for weekly function test.
700.0 196.0
11/21/2023
17:15
11/21/2023
19:45
2.50 PROD1, TRIPCAS BHAH P L/D completion BHA as per SLB DDX.
Monitor disp via TT
SIMOPS - Function Blind rams for
weekly function test.
196.0 0.0
11/21/2023
19:45
11/21/2023
21:00
1.25 PROD1, TRIPCAS BHAH P Clear and clean rig floor. 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 25/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/21/2023
21:00
11/21/2023
23:30
2.50 COMPZN, CASING RURD P R/U to run 4½" 12.6# P110S Hyd563
lower completion.
SIMOPS - Drift and stage frac sleeves
0.0 0.0
11/21/2023
23:30
11/22/2023
00:00
0.50 COMPZN, CASING SFTY P PJSM with rig crew, DDI TP, CPAI rig
advisor, DDI Csg, MI mud engineer.
0.0 0.0
11/22/2023
00:00
11/22/2023
06:00
6.00 COMPZN, CASING PUTB P RIH w/ 4½" 12.6# P110S Hyd563 lower
completion as per detail. Tq
connections to 5500 ft/lbs. Fill on the fly
via fill up hose. Monitor disp via pit #1.
0.0 418.0
11/22/2023
06:00
11/22/2023
12:00
6.00 COMPZN, CASING PUTB P RIH w/ 4½" 12.6# P110S Hyd563 lower
completion as per detail. Tq
connections to 5500 ft/lbs. Fill on the fly
via fill up hose. Monitor disp via pit #1.
S/O WT - 90K.
418.0 7,690.0
11/22/2023
12:00
11/22/2023
18:00
6.00 COMPZN, CASING PUTB P RIH w/ 4½" 12.6# P110S Hyd563 lower
completion as per detail. Tq
connections to 5500 ft/lbs. Fill on the fly
via fill up hose. Monitor disp via pit #1.
P/U WT - 117K, S/O WT - 85K.
7,690.0 10,971.0
11/22/2023
18:00
11/22/2023
22:15
4.25 COMPZN, CASING PUTB P RIH w/ 4½" 12.6# P110S Hyd563 lower
completion as per detail. Tq
connections to 5500 ft/lbs. Fill on the fly
via fill up hose. Monitor disp via pit #1.
P/U WT - 117K, S/O WT - 85K.
10,971.0 13,044.0
11/22/2023
22:15
11/22/2023
23:00
0.75 COMPZN, CASING OTHR P P/U SLZXP and M/U as per Baker reps. 13,044.0 13,074.0
11/22/2023
23:00
11/22/2023
23:15
0.25 COMPZN, CASING RUNL P RIH w/ 4" DP from derrick to place
hanger below BOPE. Obtain T&D
parameters; UP WT - 120K, S/O WT -
70K. ROT wt 81K. 20 RPM / 6.5 K Trq,
30 RPM / 7 K Trq
13,074.0 13,277.0
11/22/2023
23:15
11/23/2023
00:00
0.75 COMPZN, CASING MPDA P Pull Trip Nipple and install MPD
Bearing.
13,277.0 13,277.0
11/23/2023
00:00
11/23/2023
02:30
2.50 COMPZN, CASING RUNL P RIH w/ 4½" 12.6# P110S Hyd563 lower
completion on 4" DP f/13,277' to
13,780'. Pick up on string and work thru
tight spot at 13,396' and 13,775', PU wt
129K / SO wt 68 k
13,277.0 13,780.0
11/23/2023
02:30
11/23/2023
04:30
2.00 COMPZN, CASING RUNL P Continue to RIH w/liner ton DP f/13,775'
to 13,780'. Encounter loss of slack off
wt. Pick up t/13,770' and establish base
T&D parameters. P/U WT - 120K, S/O
WT - 70K, ROT WT - 97K, RPM @ 20 &
30 - 9-10K. 2 BPM - 710 PSI. Cont. to
RIH w/liner washing and reaming
f/13,780' to 13,938'. Experiencing bad
hole conditions. Losing slack off wt and
stalling out top drive w/torque stall set at
11 k ft/lbs trq and experiencing over pull
w/215k max hook load while attempting
to work pipe up.
13,780.0 13,938.0
11/23/2023
04:30
11/23/2023
06:00
1.50 COMPZN, CASING RUNL T At 13,938' all forward progress was
stopped. Encounter tight hole conditions
w/loss of slack off wt. and 195 k PU wt.
Establish circ up to 2 BPM, 710 PSI.
Engage rot from 10-30 RPM. Adjust
parameters as needed to attempt to RIH
(unsuccessful). Top drive stalling out at
torque limit of 11 k ft/lbs trq. Experience
instant overpull while trying to work pipe
up.
13,938.0 13,938.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 26/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/23/2023
06:00
11/23/2023
07:45
1.75 COMPZN, CASING PMPO T Team decision made to Pump OOH
f/19,938' to 13,595' to remove RCD
bearing and inspect SLZXP due to
instant overpull, slackoff observed at
surface. Pump @ 1 BPM, 435 PSI, UP
WT - 150K. Experience insrant over pull
of 185k max PU wt and liner skipping as
we attempt to work pipe out.
13,938.0 13,595.0
11/23/2023
07:45
11/23/2023
08:30
0.75 COMPZN, CASING MPDA T Pull MPD bearing, Drip Nipple, and
install Trip Nipple.
13,595.0 13,595.0
11/23/2023
08:30
11/23/2023
10:30
2.00 COMPZN, CASING PMPO T Continue to Pump OOH f/13,595' to
13,096' to inspect SLZXP w/ 1 BPM,
270 PSI. Minimal returns to surface.
UP WT - 147K. 61 total bbls loss while
Pumping OOH. Experience insrant over
pull of 185k max PU wt and liner
skipping as we attempt to work pipe out.
13,595.0 13,096.0
11/23/2023
10:30
11/23/2023
11:15
0.75 COMPZN, CASING OTHR T Inspect SLXZP - Observe 23 of the 24
slip segments to be missing and
damage to the hanger assembly. L/D
SLZXP . L/D liner hanger f/13,096' to
13,044'
13,096.0 13,044.0
11/23/2023
11:15
11/23/2023
12:30
1.25 COMPZN, CASING CIRC T P/U working 4" DP single, XO, and
make up to stump. Establish circ w/ 1
BPM, 274 PSI.
SIMOPS - shut down, drain stack, and
confirm no debris in BOPE.
13,044.0 13,044.0
11/23/2023
12:30
11/23/2023
15:45
3.25 COMPZN, CASING DISP T Decision made to weight up wellbore
fluid to 9.8. Stage pumps up to 5 BPM,
ICP - 285, FCP - 1314. Work string UP
WT - 120K, S/O WT - 74K. Observe
pressure spike up 2800 psi. Shut down
pumps.
13,044.0 13,044.0
11/23/2023
15:45
11/23/2023
16:45
1.00 COMPZN, CASING RUNL T Decision made to RIH 1 std from derrick
to 13,139' MD and attempt to regain
circ. Rot string @ 5-10 RPM, 6-8K TQ,
ROT WT - 103K. Unable to regain circ.
Determine debris in liner. POOH and
rack back std.
13,044.0 13,044.0
11/23/2023
16:45
11/23/2023
18:15
1.50 COMPZN, CASING WAIT T WOO. Work string 10' to ensure free
travel. UP WT - 121K. S/O WT - 75K.
13,044.0 13,044.0
11/23/2023
18:15
11/23/2023
19:00
0.75 COMPZN, CASING CIRC T Attempt to establish circ and free drill
string pack off. Pressure up to 4500 psi.
(failed)
13,044.0 13,044.0
11/23/2023
19:00
11/23/2023
23:00
4.00 COMPZN, CASING PULD T Decision made to POOH 13,044' to
12,523' @ 300 ft/hr and L/D liner
assembly. Monitor disp via TT. UP WT
- 120K.
POOH while waiting on HES cementers
to mobilize to open alpha sleeve. HES
on location @ 22:15 hrs.
13,044.0 12,523.0
11/23/2023
23:00
11/24/2023
00:00
1.00 COMPZN, CASING RURD T P/U and M/U xo and 1jt of 4" DP. RIH to
12,540' MD. R/U HES cementers. P/U
WT - 118K, S/O WT - 78K.
Total losses last 24 hrs - 148 bbls.
Total interval formation losses - 180
bbls.
12,523.0 12,540.0
11/24/2023
00:00
11/24/2023
01:00
1.00 COMPZN, CASING OTHR T PJSM, PT lines to 500 & 3000 psi low,
8500 psi high (good). Pressure up to
5800 psi @ .5 bpm and observe Alpha
sleeve open. Confirm w/ 1.5 bpm, 296
psi.
12,540.0 12,540.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 27/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/24/2023
01:00
11/24/2023
01:30
0.50 COMPZN, CASING RURD T Flush HES cementing unit. B/D and rig
down circ lines.
12,540.0 12,540.0
11/24/2023
01:30
11/24/2023
04:15
2.75 COMPZN, CASING DISP T Displace well to 9.8 ppg Klayshield. ICP
- 285, FCP - 675 @ 4 BPM, 169 GPM.
Work string 30' UP WT - 104K, S/O WT
- 61K. Total stks pumped - 5632 (567
bbls).
12,540.0 12,540.0
11/24/2023
04:15
11/24/2023
04:45
0.50 COMPZN, CASING OWFF T OWFF - Static
SIMOPS - R/U Doyon Csg.
12,540.0 12,540.0
11/24/2023
04:45
11/24/2023
12:00
7.25 COMPZN, CASING PULL T POOH f/12,540' to 9,552' laying down
4½" 12.6# P110S Hyd563 lower
completion @ 9,552' MD. Monitor disp
via TT. UP WT - 115K.
12,540.0 9,552.0
11/24/2023
12:00
11/25/2023
00:00
12.00 COMPZN, CASING PULL T POOH f/9,552' to 3,967' laying down
4½" 12.6# P110S Hyd563 lower
completion. Monitor disp via TT. UP
WT - 115K.
Retrieved 8.5 SLZXP dies of the missing
23.
Total bbls lost last 24 hrs - 43
Total bbls lost for interval - 223
9,552.0 3,967.0
11/25/2023
00:00
11/25/2023
08:45
8.75 COMPZN, CASING PULL T POOH f/3,967' to surface laying down
4½" 12.6# P110S Hyd563 lower
completion. Monitor disp via TT. UP
WT - 53K.
Retrieved 9ea SLZXP dies of the
missing 23.
Found 6 of the 275 composite 4-1/2 x 6-
1/8 centralizers damaged and chunks
missing.
C/O JT #122 due to external scarring
around jt.
Swell packers #25 to #11 did not enter
the openhole while the rest #10 to #1
entered the openhole. We saw more slot
-type scratches on the ones which
entered the openhole. Also we found
that the swelling speed was faster than
the Baker’s simulation. Swell pkrs
swelled to 6.3 to 6.5 OD. Swell pkr #8
observed swelling to 6.62 OD.
3,967.0 0.0
11/25/2023
08:45
11/25/2023
10:15
1.50 COMPZN, CASING RURD T Clear and clean rig floor. L/D frac
sleeves via beaverslide. Mobilize baker
fishing tools and equipment to the rig
floor.
0.0 0.0
11/25/2023
10:15
11/25/2023
12:30
2.25 COMPZN, CASING WWWH T M/U string magnets, wash tool, and 2 jts
of 4" DP. Flush stack and function
BOPE to clear any debris from BOPE.
L/D same. Observe no metal on
magnets.
0.0 0.0
11/25/2023
12:30
11/25/2023
13:30
1.00 COMPZN, CASING RURD T Mobilize clean out BHA to the rig floor. 0.0 0.0
11/25/2023
13:30
11/25/2023
14:45
1.25 COMPZN, CASING BHAH T M/U Baker clean out BHA to 254' MD.
(Reverse circulating junk basket,
magnets and 6-5/8" OD string mill)
0.0 254.0
11/25/2023
14:45
11/25/2023
16:15
1.50 COMPZN, CASING TRIP T RIH w/ 4" DP stds f/250' to 2,050' MD.
Obtain perameters w/ 8 BPM, 338 GPM,
1257 PSI, RPM 40, TQ 1-3K. UP WT -
75K, S/O WT - 74K, ROT WT - 72K.
254.0 2,050.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 28/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/25/2023
16:15
11/26/2023
00:00
7.75 COMPZN, CASING REAM T Wash and ream f/2,050' to 6,438' MD w/
8 BPM, 338 GPM, 1277 PSI, 10% F/O,
40 RPM, 2K TQ. S/O WT @ rate - 98K.
Formation losses last 24 hrs - 13.8 bbls
Total interval formation losses - 236 bbls
2,050.0 6,438.0
11/26/2023
00:00
11/26/2023
00:45
0.75 COMPZN, CASING REAM T Wash and ream f/6,438' to 6,679' MD w/
8 BPM, 338 GPM, 1828 PSI, 10% F/O,
40 RPM, 2.5K TQ. S/O WT @ rate -
96K.
6,438.0 6,679.0
11/26/2023
00:45
11/26/2023
01:30
0.75 COMPZN, CASING SFTY T B/D TD. PJSM on Slip and Cut.
Conduct Kick while tripping drill.
6,679.0 6,679.0
11/26/2023
01:30
11/26/2023
03:15
1.75 COMPZN, CASING SLPC T Cut and slip 74' Drill Line. SIMOPS -
Had to trouble shoot inoperable mud
pumps and Amphion system.
6,679.0 6,679.0
11/26/2023
03:15
11/26/2023
03:45
0.50 COMPZN, CASING SVRG T Service Top drive - DW - Blocks. 6,679.0 6,679.0
11/26/2023
03:45
11/26/2023
07:45
4.00 COMPZN, CASING REAM T Wash and ream f/6,679' to 8,557' MD w/
7 BPM, 296 GPM, 1655 PSI, 10% F/O,
40 RPM, 4.5K TQ. S/O WT @ rate -
103K.
6,679.0 8,557.0
11/26/2023
07:45
11/26/2023
08:15
0.50 COMPZN, CASING RGRP T Downtime - VFD / MCC / Electrical issue
causing Amphion to not operate Mud
pumps. Reset and cleared the J-Logs
to rectify the issue.
8,557.0 8,557.0
11/26/2023
08:15
11/26/2023
08:45
0.50 COMPZN, CASING REAM T Wash and ream f/8,557' to 8,575' MD w/
7 BPM, 296 GPM, 1668 PSI, 10% F/O,
60 RPM, 3K TQ. S/O WT @ rate -
107K. UP WT - 115K, ROT WT - 112K.
8,557.0 8,575.0
11/26/2023
08:45
11/26/2023
09:45
1.00 COMPZN, CASING BKRM T BROOH f/8,575' to 8,283 w/ 7 BPM, 296
GPM, 1610 PSI, 10% F/O, 40 RPM, 3K
TQ. ROT UP WT @ rate - 104K.
8,575.0 8,283.0
11/26/2023
09:45
11/26/2023
11:15
1.50 COMPZN, CASING CIRC T Circ and condition mud w/ 7-8 BPM, 338
-296 GPM, 1612-1980 PSI, 10% F/O, 40
RPM, 3K TQ. Total stks pumped - 4511
(454 bbls).
SIMOPS - Pump 30 bbl super sweep
pill.
Pump 30 bbl Dry Job.
8,283.0 8,283.0
11/26/2023
11:15
11/26/2023
11:30
0.25 COMPZN, CASING OWFF T OWFF - Static 8,283.0 8,283.0
11/26/2023
11:30
11/26/2023
16:00
4.50 COMPZN, CASING TRIP T POOH f/8,283' to 254' while racking 4"
DP/HWDP to 254' MD. UP WT - 119K.
Monitor disp via TT.
8,283.0 254.0
11/26/2023
16:00
11/26/2023
16:15
0.25 COMPZN, CASING OWFF T OWFF - static 254.0 254.0
11/26/2023
16:15
11/26/2023
17:00
0.75 COMPZN, CASING BHAH T L/D Baker cleanout assembly f/254'.
Monitor disp via TT.
Recover 2 ea dies from RCJB for a total
of 11 recovered of the 23 missing. Also
large chunks of shale recovered in the
RCJB.
254.0 0.0
11/26/2023
17:00
11/26/2023
17:30
0.50 COMPZN, CASING BHAH T Clean and clear rig floor. 0.0 0.0
11/26/2023
17:30
11/26/2023
18:00
0.50 COMPZN, CASING WWWH T M/U stack flushing tool and flush BOPE
w/ water.
0.0 0.0
11/26/2023
18:00
11/26/2023
19:30
1.50 COMPZN, CASING RURD T R/U to test BOPE. Pull wear bushing
and install test plug as per Cameron
rep.
0.0 0.0
11/26/2023
19:30
11/26/2023
21:30
2.00 COMPZN, CASING BOPE T Shell test BOPE. Found blind sheer
door leaking. Tighten door and double
check all other door bolts.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 29/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/26/2023
21:30
11/27/2023
00:00
2.50 COMPZN, WHDBOP BOPE T BOPE test. All tests at 250/4000 psi.
Test with 4” test joint. Test annular to
250/3500 psi. Test upper vbr's and
lower vbr's. Test choke valves #1-2 & 5-
14, test 4” dart valve and 2ea TIW
valves, test rig floor, mezzanine, HCR
and manual kill valves, hyd and manual
chokes to 2000 psi. and demonstrate
bleed off. Perform accumulator test.
Starting pressure=3000 psi, after
function= 1850 psi, 200 psi attained = 9
sec's, full recovery = 48 sec. 6 nitrogen
bottles ave 1967 psi. Test gas alarms,
PVT and flow show. Witness was
waived by AOGCC Rep. Guy Cook.
Formation losses last 24 hours: 18 bbls
Total interval formation losses: 249.8
bbls
0.0 0.0
11/27/2023
00:00
11/27/2023
03:00
3.00 COMPZN, WHDBOP BOPE T BOPE test. All tests at 250/4000 psi.
Test blind shear rams. With 4½” test
joint, test annular to 250/3500 psi. Test
upper vbr's and lower vbr's. Test choke
valves 3 & 4. Test HCR and manual
choke valves, Test upper and lower
IBOP. F/P on upper IBOP - service -
retest good. Witness was waived by
AOGCC Rep. Guy Cook.
0.0 0.0
11/27/2023
03:00
11/27/2023
03:45
0.75 COMPZN, CASING RURD T Pull test plug and install 10.0 ID wear
bushing. RILDS (x2).
0.0 0.0
11/27/2023
03:45
11/27/2023
05:00
1.25 COMPZN, CASING RURD T R/D and B/D test equipment. Clear and
clean rig floor.
0.0 0.0
11/27/2023
05:00
11/27/2023
06:30
1.50 COMPZN, CASING BHAH T Mobilize clean out BHA to the rig floor
via beaverslide.
0.0 0.0
11/27/2023
06:30
11/27/2023
08:15
1.75 COMPZN, CASING BHAH T M/U Baker scraper BHA to 115' MD. 0.0 115.0
11/27/2023
08:15
11/27/2023
16:00
7.75 COMPZN, CASING PULD T RIH w/ scraper assembly picking up
4"DP F/ 115' MD to 7,014' MD. Monitor
disp via TT. UP WT - 119K, S/O WT -
100K.
115.0 7,014.0
11/27/2023
16:00
11/27/2023
16:45
0.75 COMPZN, CASING TRIP T RIH w/ 4" DP from derrick F/ 7,014' MD
to 8,054' MD. Monitor disp via TT. UP
WT - 119K, S/O WT - 100K.
7,014.0 8,054.0
11/27/2023
16:45
11/27/2023
18:00
1.25 COMPZN, CASING REAM T Wash and ream F/ 8,054' MD to 8,330'
MD w/ 6.5 BPM, 275 GPM, 1520 PSI,
5% F/O, 20 RPM, 3K TQ. ROT WT @
rate - 105K.
8,054.0 8,330.0
11/27/2023
18:00
11/27/2023
19:15
1.25 COMPZN, CASING CIRC T Rot and recip pipe F/ 8,330' MD to
8,300' MD. Circ 25 bbl weighted 10.7
ppg Hi-vis w/ SuperSweep pill. Observe
minimal swarf from wellbore upon
sweep returns. Pump sweep w/ 270
GPM, 1310 PSI, 5% F/O, 20 RPM, 3K
TQ. ROT WT @ rate - 105. Total stks
pumped - 4672 (470 bbls).
8,330.0 8,300.0
11/27/2023
19:15
11/27/2023
19:30
0.25 COMPZN, CASING CIRC T Pump 20 bbl dry job. B/D TD. 8,330.0 8,330.0
11/27/2023
19:30
11/27/2023
19:45
0.25 COMPZN, CASING OWFF T OWFF - static. 8,330.0 8,330.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 30/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/27/2023
19:45
11/28/2023
00:00
4.25 COMPZN, CASING TRIP T POOH on elevators F/ 8,330' MD to
2,100' MD. Monitor disp via TT. UP WT
- 120K.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 254.81
bbls
8,330.0 2,100.0
11/28/2023
00:00
11/28/2023
01:45
1.75 COMPZN, CASING TRIP T POOH on elevators F/ 2,100' MD to
115' MD. Monitor disp via TT. UP WT -
50K.
2,100.0 115.0
11/28/2023
01:45
11/28/2023
02:00
0.25 COMPZN, CASING OWFF T OWFF - static. 115.0 115.0
11/28/2023
02:00
11/28/2023
04:00
2.00 COMPZN, CASING BHAH T L/D Baker scraper BHA F/ 115' MD.
Monitor disp via TT.
115.0 0.0
11/28/2023
04:00
11/28/2023
05:00
1.00 COMPZN, CASING BHAH T Clear and clean rig floor. 0.0 0.0
11/28/2023
05:00
11/28/2023
07:15
2.25 COMPZN, CASING OTHR T C/O XT-39 saver sub. 0.0 0.0
11/28/2023
07:15
11/28/2023
07:45
0.50 COMPZN, CASING SVRG T Service topdrive, blocks, and iron
roughneck.
0.0 0.0
11/28/2023
07:45
11/28/2023
08:15
0.50 COMPZN, CASING BHAH T Organize rig floor and ready for P/U of
SLB clean out BHA.
0.0 0.0
11/28/2023
08:15
11/28/2023
10:30
2.25 COMPZN, CASING BHAH T M/U 6½" clean out bha as per SLB
DD/MWD to 462' MD. UP WT - 54K,
S/O WT - 54K. Monitor disp via Pit 1.
0.0 462.0
11/28/2023
10:30
11/28/2023
13:00
2.50 COMPZN, CASING PULD T Single in the hole on 4" DP F/ 462' MD
to 2,358' MD. UP WT - 76K, S/O WT -
76K. Monitor disp via Pit 1.
462.0 2,358.0
11/28/2023
13:00
11/28/2023
13:15
0.25 COMPZN, CASING DHEQ T Shallow pulse test PWD w/ 250 GPM,
1293 PSI, 6% F/O. Cycle pumps 3x to
confirm good.
2,358.0 2,358.0
11/28/2023
13:15
11/28/2023
14:00
0.75 COMPZN, CASING PULD T Single in the hole on 4" DP F/ 2,358' MD
to 2,732' MD. UP WT - 81K, S/O WT -
81K. Monitor disp via Pit 1.
2,358.0 2,732.0
11/28/2023
14:00
11/28/2023
17:45
3.75 COMPZN, CASING TRIP T RIH w/ stds of 4" DP F/ 2,732' MD to
8,218' MD. UP WT - 108K, S/O WT -
95K. Monitor disp via Pit 1. Fill pipe
every 20 stds.
2,732.0 8,218.0
11/28/2023
17:45
11/28/2023
19:00
1.25 COMPZN, CASING CIRC T Rot and recip F/ 8,218' MD to 8,300' MD
w/ 250 GPM, 1794 PSI, 5% F/O, 40
RPM, 3.5K TQ. ECD 10.68. UP WT -
122K, S/O WT 105K, ROT WT - 113K.
Total stks pumped - 2950 (297 bbls).
8,218.0 8,300.0
11/28/2023
19:00
11/28/2023
19:45
0.75 COMPZN, CASING MPDA T B/D TD. Pull trip nipple. Install drain
nipple and MPD bearing.
8,300.0 8,300.0
11/28/2023
19:45
11/28/2023
20:30
0.75 COMPZN, CASING MPDA T Establish circ through MPD manifold w/
127 GPM, 621 PSI, 2% F/O. Obtain
SPR's and parameters prior to going
into open hole UP WT - 131K, S/O WT -
103K, ROT WT - 112K @ 20 RPM -
3.5K TQ.
8,300.0 8,300.0
11/28/2023
20:30
11/28/2023
21:30
1.00 COMPZN, CASING TRIP T RIH on elevators w/ 4" DP F/ 8300' MD
to 8,808' MD. Observe 10K hookload
drop as we entered open hole. Cont in
the hole and observe 30K (72K)
hookload drop at 8,808' MD.
8,300.0 8,808.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 31/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/28/2023
21:30
11/28/2023
22:45
1.25 COMPZN, CASING REAM T POOH up to 8,782' MD. UP WT - 136K.
Kelly up and wash and ream in the hole
down to 8,970' MD w/ 250 GPM, 1880
PSI, 15% F/O, 60 RPM, 4K TQ. ECD
10.95. S/O WT @ rate 102K, Total stks
pumped - 3269 (329 bbls). Observe
small amounts of swarf and super
sweep at bottoms up.
8,782.0 8,970.0
11/28/2023
22:45
11/29/2023
00:00
1.25 COMPZN, CASING SMPD T Strip in the hole F/ 8,970' MD to 9915'
MD. Holding 220 PSI backpressure
while out of slips and 320 in slips via
MPD. S/O WT - 90K. Observe 1 bbl
displacment. Reduce pressure 1/10
PPG at a time to achieve correct
displacement. 90 psi out of slips - 260
in slips = 10.7 ppg EMW.
Formation losses last 24 hours: 27.86
bbls
Total interval formation losses: 282.67
bbls
8,970.0 9,915.0
11/29/2023
00:00
11/29/2023
03:00
3.00 COMPZN, CASING SMPD T Strip in the hole F/ 9,915' MD to 11,805'
MD. S/O WT - 85K. Holding 90 psi out
of slips - 260 in slips = 10.7 ppg EMW.
Encounter obstruction at 11,805 setting
dn 20K (65K) hookload.
9,915.0 11,805.0
11/29/2023
03:00
11/29/2023
03:30
0.50 COMPZN, CASING REAM T Attempt to pull up to break free -
unsuccessful due to block height. Kelly
up & break circ staging pumps up at .5
bpm up to 165 GPM, ICP - 365, FCP -
1057, 17% F/O. Attempt to work free
pulling up to max allowable derrick
height observing 174K hook load. S/O
attempting to slide past obstruction
(failed). Engage rot @ 10 RPM, 9.5K
TQ and successfully free pipe indicating
possibly differentially stuck.
11,805.0 11,805.0
11/29/2023
03:30
11/29/2023
05:30
2.00 COMPZN, CASING CIRC T Stage pumps up to 212 GPM, PSI -
1650, 22% F/O. Increase rot to 60
RPM, 5K TQ and circ b/u working pipe
up to 11,800' MD dn to 11,900' MD.
Total stks pumped - 3850 (388 bbls).
Observe 80% increase in cuttings during
circulation. All cuttings are small
pulverized cuttings.
11,800.0 11,900.0
11/29/2023
05:30
11/29/2023
06:30
1.00 COMPZN, CASING SMPD T Strip in the hole F/ 11,900' MD to
12,656' MD. S/O WT - 84K. Holding
130 psi out of slips - 320 in slips.
Reduce backpressure to aid in pipe
displacement. Encounter obstruction at
12,525' MD (top of std). Setting dn 20k
(65K) hookload.
Steady stream of small pulverized
cuttings on shakers while reaming in the
hole.
11,900.0 12,525.0
11/29/2023
06:30
11/29/2023
06:45
0.25 COMPZN, CASING WASH T P/U to 12,500' MD and kelly up. Wash
dn w/ 85 GPM, 524 PSI, 22% F/O to
11,563' MD.
12,500.0 12,563.0
11/29/2023
06:45
11/29/2023
07:00
0.25 COMPZN, CASING SMPD T Strip in the hole F/ 12,563' MD to
12,656' MD. S/O WT - 78K. Holding
118 psi out of slips - 320 in slips. EMW -
10.7 ppg. Encounter obstruction at
12,658' MD. Setting dn 10k (65K)
hookload.
12,563.0 12,656.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 32/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/29/2023
07:00
11/29/2023
09:15
2.25 COMPZN, CASING REAM T Wash and ream F/ 12,656' MD to
13,030' MD w/ 212 GPM, 1776 PSI,
ECD 11.53, 33% F/O, 40 RPM, 7K TQ.
ROT WT @ rate - 96K. (At 12,656'
attempt to make connection and got
differentially stuck. Not able to work pipe
free with PU and SO only. Engage
rotary and break pipe fee with 12.5 k
ft/lbs of trq)
Steady stream of small pulverized
cuttings on shakers while reaming in the
hole.
12,656.0 13,030.0
11/29/2023
09:15
11/29/2023
09:30
0.25 COMPZN, CASING SMPD T Attempt to Strip in the hole F/ 13,030'
MD to 13,125' MD. S/O WT - 84K.
Holding 118 psi out of slips - 320 in slips
= 10.7 ppg EMW. Observe excessive
drag of 10K.
13,030.0 13,125.0
11/29/2023
09:30
11/29/2023
11:00
1.50 COMPZN, CASING REAM T Wash and ream F/ 13,125' MD to
13,600' MD w/ 212 GPM, 1780 PSI,
ECD 11.33, 33% F/O, 40 RPM, 6K TQ.
ROT WT @ rate - 96K. Reduce MPD
backpressure while in slips f/10.7 ppg
EMW to 10.5 ppg EMW to mitigate
differentially sticking/pipe displacement.
Fully open chokes while washing in the
hole.
13,125.0 13,600.0
11/29/2023
11:00
11/29/2023
11:45
0.75 COMPZN, CASING SMPD T Attempt to Strip in the hole F/ 13,600'
MD to 13,790' MD. S/O WT - 80K.
Holding 60 psi out of slips - 270 in slips
to maintain 10.5 ppg EM. Observe
obstruction @ 13,790' MD (again at the
top of a std indicating differentially
sticking) Decision made to wash and
ream to btm.
13,600.0 13,790.0
11/29/2023
11:45
11/29/2023
18:00
6.25 COMPZN, CASING REAM T Wash and ream F/ 13,790' MD to
15,670' MD w/ 212 GPM, ICP -1800
PSI, FCP - 1780 (i)ECD 11.34, (f)ECD -
11.12, 33% F/O, 60 RPM, 7K TQ. ROT
WT @ rate - 100K. MPD chokes open
while RIH. Adjust in slip psi to maintain
10.5 ppg EMW.
Reduce in slip psi @ 14,446' MD to 150
Reduce in slip psi @ 14,541' MD to 130
Reduce in slip psi @ 15,294' MD to 120
13,790.0 15,670.0
11/29/2023
18:00
11/29/2023
22:00
4.00 COMPZN, CASING REAM T Wash and ream F/ 15,670' MD to
16,939' MD w/ 212 GPM, ICP -1780
PSI, FCP - 1870 (i)ECD 11.12, (f)ECD -
11.25, 50% F/O, 60 RPM, 8K TQ. ROT
WT @ rate - 90K. MPD chokes open
while RIH. Adjust in slip psi to maintain
10.5 ppg EMW.
Observe packoff signs @ 16,939' MD.
Reduce in slip psi @ 16,435' MD to 100
Reduce in slip psi @ 16,907' MD to 80.
Steady stream of small pulverized
cuttings on shakers while reaming in the
hole.
15,670.0 16,939.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 33/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/29/2023
22:00
11/29/2023
23:00
1.00 COMPZN, CASING REAM T Work pipe up F/ 16,939' MD to 16,907'
MD 212 GPM, PSI - 2080, ECD - 11.25,
50% F/O, 60 - RPM, 9-10K TQ. Work
pipe dn to 17,002' MD and wipe back up
to 16,973' MD at same rate to ensure
hole clean (good).
16,907.0 17,002.0
11/29/2023
23:00
11/30/2023
00:00
1.00 COMPZN, CASING REAM T Wash and ream F/ 17,002' MD to
17,380' MD w/ 212 GPM, ICP -1870
PSI, FCP - 1955 (i)ECD 11.25, (f)ECD -
11.43, 51% F/O, 60 RPM, 8-9K TQ.
ROT WT @ rate - 96K. MPD chokes
open while RIH. Adjust in slip psi to
maintain 10.5 ppg EMW currently @ 80
psi.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 282.67
bbls
Steady stream of small pulverized
cuttings on shakers while reaming in the
hole.
17,002.0 17,380.0
11/30/2023
00:00
11/30/2023
03:30
3.50 COMPZN, CASING REAM T Wash and ream F/ 17,380' MD to
18,029' MD w/ 212 GPM, ICP -1870
PSI, FCP - 1955 (i)ECD 11.25, (f)ECD -
11.43, 51% F/O, 60 RPM, 8-9K TQ.
ROT WT @ rate - 96K. MPD chokes
open while RIH.
Adjust in slip psi to maintain 10.5 ppg
EMW currently @ 80 psi.
Steady stream of small pulverized
cuttings on shakers while reaming in the
hole.
Observe tight hole / packoff conditions
@
17,515' MD
18,029' MD.
17,380.0 18,029.0
11/30/2023
03:30
11/30/2023
05:00
1.50 COMPZN, CASING CIRC T Decision made to circ B/U while rot and
recip pipe F/ 18,029' MD to 17,943' MD
w/ 212 GPM, 1949 PSI, ECD - 11.26,
51% F/O, 80 RPM, 8-9K TQ. ROT WT
@ rate - 100K. Total stks pumped -
5000 (503 bbls).
Steady stream of small pulverized
cuttings on shakers @ B/U.
18,029.0 18,029.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 34/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/30/2023
05:00
11/30/2023
12:00
7.00 COMPZN, CASING REAM T Wash and ream F/ 18,029' MD to
19,145' MD w/ 250 GPM, ICP -1955
PSI, FCP - 2677 (i)ECD 11.43, (f)ECD -
11.36, 51% F/O, 120 RPM, 8-9K TQ.
ROT WT @ rate - 112K. MPD chokes
open while RIH. Mud wt in/out -
9.6/9.7+
Adjust in slip psi to maintain 10.5 ppg
EMW
Increase pressure to 100 @ 18,035' MD
Increase pressure to 120 @ 18,406' MD
Increase pressure to 130 @ 19,049' MD
Steady stream of small pulverized
cuttings on shakers while reaming in the
hole.
Observe tight hole / packoff conditions
@
18,322' MD
18,029.0 19,145.0
11/30/2023
12:00
11/30/2023
21:45
9.75 COMPZN, CASING REAM T Wash and ream F/ 19,145' MD to
21,276' MD w/ 212 GPM, ICP -2677
PSI, FCP - 3042 (i)ECD 11.36, (f)ECD -
11.61, 51% F/O, 120 RPM, 10K TQ.
ROT WT @ rate - 130K. MPD chokes
open while RIH.
Maintain 10.5 ppg EMW w/ 130 psi
while in slips.
Steady stream of small pulverized
cuttings on shakers while reaming in the
hole.
19,145.0 21,276.0
11/30/2023
21:45
12/1/2023
00:00
2.25 COMPZN, CASING BKRM T BROOH circ B/U's F/ 21,276' MD to
21,208' MD w/ 258 GPM, ICP - 2990
PSI, FCP - 3024 (i)ECD 11.54, (f)ECD -
11.51, 51% F/O, 120 RPM, 10K TQ.
ROT WT @ rate - 131K. MPD chokes
open while BROOH. Continue to
maintain 10.5 ppg EMW w/ 130 psi
while in slips. Mud Wt in/out - 9.5 Total
stks pumped - 12,016 (1210 bbls)
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 282.67
bbls
Decreasing pulverized cuttings on
shakers. No increase at bottoms up's.
21,276.0 21,208.0
12/1/2023
00:00
12/1/2023
04:00
4.00 COMPZN, CASING BKRM T BROOH circ B/U's F/ 21,208' MD to
21,072' MD w/ 258 GPM, ICP - 3024
PSI, FCP - 2980 (i)ECD 11.51, (f)ECD -
11.50, 51% F/O, 120 RPM, 10K TQ.
ROT WT @ rate - 131K. MPD chokes
open while BROOH. Continue to
maintain 10.5 ppg EMW w/ 130 psi
while in slips. Mud Wt in/out - 9.5 ppg.
Total stks pumped - 18,974 (1911 bbls).
Pumped total of 5x b/u - 30,990 stks
( 3121 bbls).
21,208.0 21,072.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 35/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/1/2023
04:00
12/1/2023
12:00
8.00 COMPZN, CASING SMPD T Strip OOH F/ 21,072' MD to 17,860' MD
racking back 4" HWDP. UP WT - 154K.
Maintaining 10.5 ppg EWM w/ MPD
backpressure @ 200-400 psi out/in.
Adjusting pressure for losses.
Attempt to drop 1.75 OD steel rabbit.
Issue with it falling throught the HWDP.
Decision to drop the rabbit on DP.
21,072.0 17,860.0
12/1/2023
12:00
12/1/2023
18:00
6.00 COMPZN, CASING SMPD T Strip OOH F/ 17,860' MD to 12,750' MD
racking back 4" DP. UP WT - 143K.
Maintaining 10.5 ppg EWM w/ MPD
backpressure @ 200-400 psi out/in.
Adjusting pressure for losses.
Drop 1.75 OD hollow steel rabbit w/
~100' tail.
17,860.0 12,750.0
12/1/2023
18:00
12/2/2023
00:00
6.00 COMPZN, CASING SMPD T Strip OOH F/ 12,750' MD to 7,646' MD
racking back 4" DP. UP WT - 125K.
Maintaining 10.5 ppg EWM w/ MPD
backpressure @ 200-340 psi out/in.
Adjusting pressure for losses. Observe
no issues pulling into the shoe.
Formation losses last 24 hours: 0 bbls
Total interval formation losses: 282.67
bbls
12,750.0 7,646.0
12/2/2023
00:00
12/2/2023
04:00
4.00 COMPZN, CASING SMPD T Strip OOH F/ 7,646' MD to 4,336' MD
racking back 4" DP. UP WT - 100K.
Maintaining 10.5 ppg EWM w/ MPD
backpressure @ 200-340 psi out/in.
Adjusting pressure for losses.
7,646.0 4,336.0
12/2/2023
04:00
12/2/2023
04:30
0.50 COMPZN, CASING OWFF T Relax wellbore - OWFF - static. 4,336.0 4,336.0
12/2/2023
04:30
12/2/2023
06:00
1.50 COMPZN, CASING MPDA T Pull Drip nipple and MPD bearing.
Install trip nipple pulling OOH to 4,246'
MD.
4,336.0 4,246.0
12/2/2023
06:00
12/2/2023
09:30
3.50 COMPZN, CASING CIRC T Rot and recip F/ 4,246' MD to 4,154' MD
w/ 250 GPM, 1450 PSI, 25% F/O, 120
RPM, 2K TQ. ECD 10.25, UP WT - 86K,
S/O WT - 93K, ROT WT 90K. Total
stks pumped - 7500 (755 bbls).
4,246.0 4,246.0
12/2/2023
09:30
12/2/2023
09:45
0.25 COMPZN, CASING OWFF T OWFF - static. 4,246.0 4,246.0
12/2/2023
09:45
12/2/2023
10:00
0.25 COMPZN, CASING CIRC T Pump 11.4 ppg 15 bbl slug w/ 4 BPM,
169 GPM, 630 PSI. B/D TD
4,246.0 4,246.0
12/2/2023
10:00
12/2/2023
15:00
5.00 COMPZN, CASING PULD T POOH on elevators L/D 4" DP F/ 4,246'
MD to 557' MD. Monitor disp via TT. UP
WT - 85K.
4,246.0 557.0
12/2/2023
15:00
12/2/2023
15:15
0.25 COMPZN, CASING SFTY T Drill crew conduct Kick while tripping
drill. SIMOPS - OWFF - static.
557.0 557.0
12/2/2023
15:15
12/2/2023
16:00
0.75 COMPZN, CASING TRIP T POOH racking back 4" HWDP F/ 557'
MD to 156' MD. Monitor disp via TT.
557.0 156.0
12/2/2023
16:00
12/2/2023
17:30
1.50 COMPZN, CASING BHAH T L/D BHA F/ 156' MD as per SLMB
DD/MWD. Monitor disp via TT.
Retrieve 1.75 drift @ top of mills.
156.0 0.0
12/2/2023
17:30
12/2/2023
18:00
0.50 COMPZN, CASING BHAH T Clear and clean rig floor. 0.0 0.0
12/2/2023
18:00
12/2/2023
20:00
2.00 COMPZN, CASING PULD T L/D 12 stds via mousehole. Monitor
wellbore via TT.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 36/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/2/2023
20:00
12/2/2023
22:30
2.50 COMPZN, CASING RURD T Mobilize frac sleeves to the rig floor and
drift. Verified by Baker reps and CPAI
rep. Stage SLZXP in pipeshed. Monitor
wellbore via TT.
SIMOPS:
Blow dn choke and kill lines. Flush and
blow dn mud pump injection/MPD lines.
Function test all rams - HCR and
manual choke & kill valves.
C/O IBOP assembly.
0.0 0.0
12/2/2023
22:30
12/3/2023
00:00
1.50 COMPZN, CASING RURD T R/U to run 4½" 12.6# P110S Hyd563
lower completion while continuing
changing out IBOP assembly. Monitor
wellbore via TT.
0.0 0.0
12/3/2023
00:00
12/3/2023
03:30
3.50 COMPZN, CASING RURD T Install pre assembled IBOP assembly.
Remove 4½ IF saver sub. Install XT-39
saver sub. Install 4" die blocks into
grabber assembly.
SIMOPS - service suction and discharge
ends of mud pumps.
0.0 0.0
12/3/2023
03:30
12/3/2023
04:15
0.75 COMPZN, CASING BOPE T Install test sub. Attempt to test upper
and lower IBOP to 250 low / 4000 high
for 5/5 charted min (failed).
Troubleshoot pressure drop while trying
to achieve 4000 psi.
0.0 0.0
12/3/2023
04:15
12/3/2023
06:30
2.25 COMPZN, CASING BOPE T Found bladder in sensator had failed on
initial PT to 4000 psi. Found the small
volume to test problematic on reaching
4000 psi for a solid 5 min. Re-test to 250
low / 4000 high for 5/5 charted min
(good).
0.0 0.0
12/3/2023
06:30
12/3/2023
07:00
0.50 COMPZN, CASING WWWH T Flush BOPE stack w/ 10 BPM, 423
GPM, 10 PSI, 10 RPM. B/D and R/D
stack flushing tool & 4" DP dbl used.
0.0 0.0
12/3/2023
07:00
12/3/2023
08:00
1.00 COMPZN, CASING SFTY T Double check rig up. PJSM with DDI rig
crew, CPAI rig supervisor, MPD advisor,
DDI csg, Baker reps, CPAI fluid advisor
on running lower completion.
0.0 0.0
12/3/2023
08:00
12/3/2023
10:15
2.25 COMPZN, CASING PUTB T Run 4½" 12.6# P110S Hyd563 lower
completion to 1,335' MD as per detail.
Monitor disp via constant hole fill via TT.
Tq all connections to 5500 FT/LBS.
0.0 1,335.0
12/3/2023
10:15
12/3/2023
10:45
0.50 COMPZN, CASING OWFF T Perfom inflow test monitoring wellbore
via constant hole fill. Find well to be
static.
1,335.0 1,335.0
12/3/2023
10:45
12/3/2023
20:45
10.00 COMPZN, CASING PUTB T Run 4½" 12.6# P110S Hyd563 lower
completion F/ 1,335' MD to 8,317' MD
as per detail. Monitor disp via constant
hole fill via TT. Tq all connections to
5500 FT/LBS.
1,335.0 8,317.0
12/3/2023
20:45
12/3/2023
21:00
0.25 COMPZN, CASING PUTB T M/U xo/floor valve to stump. Kelly up
and obtain T&D. P/U WT - 71K, S/O
WT - 64K, ROT WT - 66K @ 20-30
RPM.
B/D hole fill pump. Line up jet pump on
TT to obtain the ability to fill DP/HWDP
and the hole simultaneously.
8,317.0 8,317.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 37/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/3/2023
21:00
12/3/2023
22:00
1.00 COMPZN, CASING PUTB T Run 4½" 12.6# P110S Hyd563 lower
completion F/ 8,317' MD to 9,107' MD
as per detail. S/O WT - 61K. Monitor
disp via constant hole fill via TT. Tq all
connections to 5500 FT/LBS.
8,317.0 9,107.0
12/3/2023
22:00
12/3/2023
22:30
0.50 COMPZN, CASING OWFF T Perfom inflow test monitoring wellbore
via constant hole fill. Stab xo/floor
valve. Kelly up and rotate string at 10
RPM, 2.2K TQ, ROT WT - 65K. Find
well to be static.
9,107.0 9,107.0
12/3/2023
22:30
12/4/2023
00:00
1.50 COMPZN, CASING PUTB T Run 4½" 12.6# P110S Hyd563 lower
completion F/ 9,107' MD to 9,445' MD
as per detail. P/U WT - 72K, S/O WT
61- K. Monitor disp via constant hole fill
via TT. Tq all connections to 5500
FT/LBS.
9 bbl loss for RIH.
Total interval formation losses: 291.67
bbls
9,107.0 9,445.0
12/4/2023
00:00
12/4/2023
01:00
1.00 COMPZN, CASING PUTB T Run 4½" 12.6# P110S Hyd563 lower
completion F/ 9,445' MD to 10,958' MD
as per detail. S/O WT - 60K. Monitor
disp via constant hole fill via TT. Tq all
connections to 5500 FT/LBS.
9,445.0 10,958.0
12/4/2023
01:00
12/4/2023
01:30
0.50 COMPZN, CASING PUTB T Trouble shoot pipe skate. Breaker
tripped, reset breaker, reset VFD,
tighten up skate trough wench cables,
and successfully regain ownership at
the skate controls.
10,958.0 10,958.0
12/4/2023
01:30
12/4/2023
04:00
2.50 COMPZN, CASING PUTB T Run 4½" 12.6# P110S Hyd563 lower
completion F/ 10,958' MD to 13,066' MD
as per detail. S/O WT - 57K. Monitor
disp via constant hole fill via TT. Tq all
connections to 5500 FT/LBS.
10,958.0 13,066.0
12/4/2023
04:00
12/4/2023
04:30
0.50 COMPZN, CASING OTHR T P/U & M/U Baker SLZXP. Fill tie-back
w/ ZanPlex. RIH to 13,106' MD. S/O
WT - 59K. Continue to have constant
hole fill via TT.
13,066.0 13,106.0
12/4/2023
04:30
12/4/2023
04:45
0.25 COMPZN, CASING RUNL T RIH w/ 4½" 12.6# P110S Hyd563 lower
completion on 4" DP F/ 13,106' MD to
13,200' MD as per detail. Obtain T & D
values - P/U UP - 77K, S/O WT - 58K,
ROT WT - 66K w/ 20 RPM & 3.6K TQ,
ROT WT - 64K w/ 30 RPM & 3.9K TQ.
13,200.0 13,200.0
12/4/2023
04:45
12/4/2023
06:00
1.25 COMPZN, CASING RUNL T RIH w/ 4½" 12.6# P110S Hyd563 lower
completion on 4" DP F/ 13,200' MD to
13,938' MD as per detail. S/O WT - 67K.
Monitor disp via constant hole fill, fill
pipe via fill up hose. Take T & D every
10th std.
13,200.0 13,938.0
12/4/2023
06:00
12/4/2023
09:00
3.00 COMPZN, CASING RUNL P RIH w/ 4½" 12.6# P110S Hyd563 lower
completion on 4" DP F/ 13,938' MD to
17,353' MD as per detail. S/O WT - 67K.
Monitor disp via constant hole fill, fill
pipe via fill up hose. Take T & D every
10th std. Values taken @ 17,070' MD -
W/ 20 RPM - 5K TQ - 78K S/O. W/ 30
RPM - 5.5K TQ - 78K S/O - No ROT
S/O WT - 69K, P/U WT - 107K.
13,938.0 17,353.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 38/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/4/2023
09:00
12/4/2023
13:15
4.25 COMPZN, CASING RUNL P RIH w/ 4½" 12.6# P110S Hyd563 lower
completion on 4" HWDP F/ 17,353' MD
to 21,212' MD as per detail. S/O WT -
122K. Monitor disp via constant hole fill,
fill pipe via fill up hose. Take T & D
every 10th std. Drift HWDP out of the
derrick.
17,353.0 21,212.0
12/4/2023
13:15
12/4/2023
13:30
0.25 COMPZN, CASING RUNL P Kelly up to std #88 and obtain final T &
D values - P/U WT - 166K, S/O WT -
96K, ROT WT - 130K w/ 20 RPM & 8K
TQ. Rot dn and tag botm w/ 5K dn wt
@ 21,276' MD. P/U and set liner in
tension at setting depth of 21,240' MD.
Observe 175K P/U WT.
21,212.0 21,240.0
12/4/2023
13:30
12/4/2023
14:30
1.00 COMPZN, CASING OWFF P Conduct in flow test. Observe well to be
static.
SIMOPS - PJSM on bursting Arsenal
disk.
21,240.0 21,240.0
12/4/2023
14:30
12/4/2023
15:30
1.00 COMPZN, CASING CIRC P Pump 2.7 bbls to burst disc. Observe
shear out at 1000 psi. Fill liner w/ 45
bbls of mud, 25 bbls high vis sweep, 30
bbls brine sweep @ 3 bpm, 127 GPM.
Allow to U-Tube & bleed air from
system. 85 total bbls to fill liner.
21,240.0 21,240.0
12/4/2023
15:30
12/4/2023
18:30
3.00 COMPZN, CASING DISP P Displace wellbore to 9.5 ppg 3% KCl
Drilling mud w/ 211 GPM, ICP - 927, 4%
F/O, FCP - 1465, 9% F/O. Total stks
pumped - 9092 (916 bbls).
21,240.0 21,240.0
12/4/2023
18:30
12/4/2023
19:00
0.50 COMPZN, CASING OWFF P OWFF - static. SIMOPS - prep pits with
CI brine.
21,240.0 21,240.0
12/4/2023
19:00
12/4/2023
21:45
2.75 COMPZN, CASING PACK P Drop 1.125" pheonolic ball to close WIV.
Pump dn at 212 GPM, 1,230 PSI, 9%
F/O. Reduce rate @ 1200 stks to 84
GPM, 535 PSI. At 3000 stks decision
made to surge pumps in aid of landing
ball on seat w/ 0-126 GPM (3X).
Successfully land ball at 3,280 stks
pumped w/ 126 GPM, 722 PSI.
Pressure up to 2917 and hold for 5 min
to set pkr. S/O to 50K hookload to
confirm set (good). Pressure up to
neutralize/release HRD-E running tool to
3,900 psi for 5 min. Observe seat blow
at 3,661 psi. P/U to 130K hookload to
confirm release (failed). Slack off to
75K hookload to confirm pkr still set
(good). Pick up to 145K hookload to
confirm release (failed). Engage rot to
10 RPM - tq stall at 8K. Slack off to 90K
hookload, P/U to 150K - increase tq stall
to 10K. P/U to 155K and observe
released.
21,240.0 21,240.0
12/4/2023
21:45
12/4/2023
22:45
1.00 COMPZN, CASING PRTS P Space out - B/D TD. Flood kill line,
close upper pipe rams. Test pkr to 3850
psi for 30 min (good). 65 stks to
pressure up - 2.5 bbls bled back.
Observe mud very aerated upon testing.
8,148.0 8,148.0
12/4/2023
22:45
12/4/2023
23:15
0.50 COMPZN, WELLPR PACK P Apply 300 psi to string while p/u string.
P/U 7' and observe pressure drop once
exit the liner top. Increase rate to 5
BPM, 211 GPM, 500 PSI to clear liner
top. Liner top 8,148' MD. L/D single.
8,148.0 8,135.0
12/4/2023
23:15
12/4/2023
23:45
0.50 COMPZN, WELLPR OWFF P OWFF - static.
SIMOPS - PJSM on displacing well.
8,135.0 8,135.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 39/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/4/2023
23:45
12/5/2023
00:00
0.25 COMPZN, WELLPR DISP P Displace well to CI 3% KCl/NaCl brine.
Pump 25 bbl spacer.
Formation losses last 24 hours: 80 bbls
Total interval formation losses: 363 bbls
8,135.0 8,135.0
12/5/2023
00:00
12/5/2023
02:00
2.00 COMPZN, WELLPR CIRC P Displace Klasheild to KCL. Pump 326
bbls 9.5 ppg KCL (3438 strokes) 3600
total strokes pumped. Build and pump
20 bbls 9.5+ ppg KCL due to utubing.
Well static.
8,135.0 8,135.0
12/5/2023
02:00
12/5/2023
02:30
0.50 COMPZN, WELLPR OWFF P OWFF for 30 min (well static). 8,135.0 8,135.0
12/5/2023
02:30
12/5/2023
06:00
3.50 COMPZN, WELLPR TRIP P TOOH laying down singles of 4" Heavy
weight drill pipe from 8135' MD to 4663'
MD. P/U 119k, S/O 107k. Monitor
displacement via trip tank. Total joints
layed down 114.
8,135.0 4,663.0
12/5/2023
06:00
12/5/2023
07:45
1.75 COMPZN, WELLPR TRIP P TOOH laying down singles of 4" drill
pipe from 4663' MD to 3822' MD. P/U
90k. Monitor displacement via trip tank.
Total joints layed down 28. Not getting
proper displacement. Decision made to
circulate bottoms up.
4,663.0 3,822.0
12/5/2023
07:45
12/5/2023
08:30
0.75 COMPZN, WELLPR CIRC P Circulate bottoms @ 5 bpm, PSI 209,
F/O 11%, (Total Strokes pumped 1236).
Blow down top drive.
3,822.0 3,822.0
12/5/2023
08:30
12/5/2023
12:00
3.50 COMPZN, WELLPR TRIP P TOOH laying down singles of 4" drill
pipe from 3822' MD to 1495'MD. P/U
54K. Monitor displacement via trip, tank,
Total joints layed down 75.
3,822.0 1,495.0
12/5/2023
12:00
12/5/2023
13:30
1.50 COMPZN, WELLPR TRIP P TOOH laying down singles of 4" drill
pipe from 1495' MD to 47' 'MD. P/U 45K.
Monitor displacement via trip, tank, Total
joints layed down 50.
1,495.0 47.0
12/5/2023
13:30
12/5/2023
14:15
0.75 COMPZN, WELLPR BHAH P PJSM. Lay down liner running assy. as
per Baker Rep. Monitor well via trip
tank. Liner running assy. inspected and
verified by Baker Rep. (Blind Rams
closed at 14:00hrs).
47.0 0.0
12/5/2023
14:15
12/5/2023
15:00
0.75 COMPZN, WELLPR CLEN P Clean and clear rig floor. Prepare to lay
down 4" drill pipe out of derrick via
mouse hole. Monitoring well via IA
sensor gauge.
0.0 0.0
12/5/2023
15:00
12/5/2023
17:00
2.00 COMPZN, WELLPR PULD P PJSM. Lay down 4" drill pipe from
derrick via mouse hole, Monitoring well
at IA sensor gauge. Total joints layed
down 42.
0.0 0.0
12/5/2023
17:00
12/5/2023
18:00
1.00 COMPZN, WELLPR SFTY P Safety Stand Down. Incidents review.
Team discussion with both crews of
expectations moving forward.
0.0 0.0
12/5/2023
18:00
12/5/2023
22:00
4.00 COMPZN, WELLPR PULD P PJSM, continue lay down 4" drill pipe
from derrick via mouse hole, Monitoring
well at IA sensor gauge. Total joints
layed down 93.
0.0 0.0
12/5/2023
22:00
12/5/2023
22:30
0.50 COMPZN, WELLPR SVRG P Rig service. Found hydraulic hose
leaking on ST-100.
0.0 0.0
12/5/2023
22:30
12/5/2023
23:00
0.50 COMPZN, WELLPR RGRP T Change out lower jaw clamp and
hydraulic hose on ST-100.
0.0 0.0
12/5/2023
23:00
12/6/2023
00:00
1.00 COMPZN, WELLPR PULD P Continue lay down 4" drill pipe from
derrick via mouse hole, Monitoring well
at IA sensor gauge. Total joints layed
down 21.
0.0 0.0
12/6/2023
00:00
12/6/2023
00:30
0.50 COMPZN, WELLPR SVRG P Lubricate rig, while trouble shooting iron
roughneck.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 40/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/6/2023
00:30
12/6/2023
05:30
5.00 COMPZN, WELLPR RGRP T Downtime Iron roughneck, Electrical
wires compromised, Iron roughneck
failed. Rig electrician spliced 3 wires
and reroute wires to prevent failure.
Repair photo sensor.
0.0 0.0
12/6/2023
05:30
12/6/2023
06:00
0.50 COMPZN, WELLPR PUTB P Lay down 4" drill pipe from derrick via
mouse hole, Monitoring well via IA
pressure sensor gauge. Total joints
layed down 9.
0.0 0.0
12/6/2023
06:00
12/6/2023
10:45
4.75 COMPZN, WELLPR PUTB P Lay down 4" drill pipe from derrick via
mouse hole, Monitoring well via IA
pressure sensor gauge. Total joints
layed down 99.
0.0 0.0
12/6/2023
10:45
12/6/2023
11:15
0.50 COMPZN, WELLPR WWSP P M/U wear bushing puller. Drain stack.
Pull wear bushing as per Cameron Rep.
instructions.
0.0 0.0
12/6/2023
11:15
12/6/2023
11:30
0.25 COMPZN, WELLPR RURD P Blow down choke lines. Make up well
head washing tool.
0.0 0.0
12/6/2023
11:30
12/6/2023
12:00
0.50 COMPZN, WELLPR WASH P Wash stack and well head area 3X,
GPM 252, PSI 120, RPM 10.
0.0 0.0
12/6/2023
12:00
12/6/2023
15:30
3.50 COMPZN, RPCOMP RURD P Demobilize tools from rig floor from
laying down 4" drill pipe and pulling
wear bushing. Mobilize tools to floor to
rig up for upper completion run. Make
up 4.5" Hydril 563 cross over to FOSV.
R/U Doyon power tongs, Halliburton tec
line, clamps, tec line hanger, spooler
sheave and handling tools. Rig up
control line in sheave and hang off in
derrick.
0.0 0.0
12/6/2023
15:30
12/6/2023
18:00
2.50 COMPZN, RPCOMP PUTB P PJSM, pick up and run 4.5" 12.6# L-80
HYD 563 tubing from surface to 519'
Make up torque 3800 ft lbs. Make up
mechanical locator, landing nipple,
double check valve, Packer OPSIS
mandrel. Test to 10,000 psi for 10
minutes. Test Halliburton tec line every
1000' monitoring returns via trip tank.
Total joints picked up 10.
0.0 519.0
12/6/2023
18:00
12/7/2023
00:00
6.00 COMPZN, RPCOMP PUTB P RIH with 4.5" 12.6# L-80 HYD 563
tubing from 519' to 4545'. Make up
torque 3800 ft lbs, Test Halliburton tec
line every 1000' monitoring returns via
trip tank. Total joints picked up100.
519.0 4,545.0
12/7/2023
00:00
12/7/2023
06:00
6.00 COMPZN, RPCOMP PUTB P RIH with 4.5" 12.6# L-80 HYD 563
tubing from 4545' to 8151'. Make up
torque 3800 ft lbs. Test Halliburton tec
line every 1000'. Monitoring returns via
trip tank. Total joints 200 in. Fully
located no-go out with 15k WOB. Saw
no indication of shear. Decision was
made to rig up and reverse circulate to
confirm fully located. P/U 110k, S/O 91k.
4,545.0 8,151.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 41/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/7/2023
06:00
12/7/2023
09:00
3.00 COMPZN, RPCOMP THGR P Lay down joint #200. Make up space out
pups with XT head pin and cement hose
to reverse circulate. Break circulation
through IA. Close annular attempt to
reverse circulate. Fluid leaking past
annular. Multiple attempts to adjust
pressures on annular from 400 to 1200
psi. Able to reverse circulate at 1/2 bpm,
30 psi - fluid still leaking past annular.
Open annular. RIH and fully locate TOL
with 20k WOB. Attempt to reverse
circulate 1/2 bpm, 45 psi - fluid still
leaking past annular. Observe 15 psi
pressure increase. Decision made to
call space out good.
8,151.0 8,151.0
12/7/2023
09:00
12/7/2023
10:00
1.00 COMPZN, RPCOMP THGR P POOH lay down space out pup and
reverse circulation equipment.
8,151.0 8,151.0
12/7/2023
10:00
12/7/2023
11:00
1.00 COMPZN, RPCOMP THGR P Make up tubing hanger to joint #198 in
hole. Terminate tec wire through tubing
hanger. Test tec wire void through
hanger to 5000 psi for 15 min. RIH and
land on hanger to 8157.4' 1' from fully
located on TOL. Run in lock downs.
Final pick up weight 110k, S/O 91k.
8,151.0 8,157.0
12/7/2023
11:00
12/7/2023
12:00
1.00 COMPZN, RPCOMP PRTS P Cameron pressure test tubing hanger
seals to 5000 psi for 15 minutes - COP
rep witness. Rig up to set packer and
chart on tubing and IA. SIMOPS: clean
pits and take on fuel to rig, Rig down
tank farm. 197 cross collars clamps
used and 6 mid collar clamps used.
8,157.0 8,157.0
12/7/2023
12:00
12/7/2023
15:30
3.50 COMPZN, RPCOMP PRTS P Set Halliburton packer - pressure down
tubing to 4550 psi and chart for 10 mins,
( 23 strokes pumped, 2.4 bbls to fill).
Bleed tubing pressure down to 2200 psi.
Pressure test IA to 3850 psi and chart
for 30 mins, (3.7 strokes pumped, 3.8
bbls to fill). Bled IA to 3000 psi. Bleed
tubing to 0 psi rapidly to shear SOV.
OWFF well static.
8,157.0 8,157.0
12/7/2023
15:30
12/7/2023
18:00
2.50 COMPZN, WHDBOP MPSP P Back out and lay down landing joint.
Install BPV. Test BPV to 2500 psi for 10
mins on chart. Demobilize upper
completion running tools and equipment
from rig floor.
0.0 0.0
12/7/2023
18:00
12/7/2023
20:00
2.00 COMPZN, WHDBOP NUND P Remove MPD riser and Mouse hole.
Install drip nipple. Remove MPD catch
can, Orbit valve, Kill lines on BOP stack.
Hold PJSM on splitting stack.
0.0 0.0
12/7/2023
20:00
12/7/2023
22:30
2.50 COMPZN, WHDBOP NUND P PJSM for splitting BOP stack. Conduct
hazard assesment for non routine task.
SIMOPS: prepare pipe shed and cold
starts for move.
0.0 0.0
12/7/2023
22:30
12/8/2023
00:00
1.50 COMPZN, WHDBOP NUND P Split BOP stack and rack back with RCD
head, annular, upper pipe rams and
blind rams on pedestal.
0.0 0.0
12/8/2023
00:00
12/8/2023
02:15
2.25 COMPZN, WHDBOP NUND P Rig up on double spool gates and pick
up lower rams and mud cross to BOP
deck. Pick up spacer spool and dual
stud adapter assembly and stage in
cellar from transport.
0.0 0.0
12/8/2023
02:15
12/8/2023
05:00
2.75 COMPZN, WHDBOP RURD P Prepare tubing head adapter and Tec
wire as per Halliburton Rep. Nipple up
orient frac tree adapter per CPAI pad
operator. Make up LRS hardline and
prepare for freeze protect.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 42/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/8/2023
05:00
12/8/2023
06:00
1.00 COMPZN, WHDBOP THGR P Terminate tec wire per Cameron and
Halliburton. Test tubing head adapter to
5000 psi. Final Halliburton downhole
info - 2502 psi, 124.8 degreesF.
0.0 0.0
12/8/2023
06:00
12/8/2023
09:30
3.50 COMPZN, WHDBOP NUND P M/U frac tree master valve, hydraulic
SSV and swab valve.
0.0 0.0
12/8/2023
09:30
12/8/2023
12:00
2.50 COMPZN, WHDBOP RURD P Continue running 10k hardline to cellar
and make up Little Red Service to frac
tree. Finish rig up hooking up Magtexc
hoses to cellar for freeze protect job.
SIMOPS: Work in pipe shed with
Directional crew and welder welding at
shakers, and cleaning under rotary
table.
On Rig gen power at 10:30hrs 12-8-23.
0.0 0.0
12/8/2023
12:00
12/8/2023
18:00
6.00 COMPZN, WHDBOP PRTS T PJSM on 10k frac tree pressure test,
install bleeder valve on tree to bleed air.
Fill frac tree with diesel, Test hard lines
10,000 psi - good test. Attempt to test
frac tree - leaks to 2 flanges. Bleed
pressure and tighten flanges. High
pressure block about SSV, re-torque
flange bolts, Attempt second test - leak
on LRS unit. Bleed pressure and repair
same. Attempt 3rd test - 250 low test
(good). Increase pressure to 5,000 psi -
observe 2 flanges leaking. Bleed
pressure and tighten flanges. Retighten
flanges on master valve. Master block
flange.
0.0 0.0
12/8/2023
18:00
12/8/2023
21:00
3.00 COMPZN, WHDBOP PRTS T Pressure up to 500 psi and work all
valves on frac tree. Leave all valves half
open to work all air out of valves.
Attempt 4th test - pressure up to 5,100
psi for 15 min - pressure bled to off 647
psi in 15 min. Bleed pressure to 0 psi
and close lower master valve. Attempt
5th pressure test - pressure up to 5,149
psi - pressure bleed off 360 psi in 15
min. Observe no visible leaks. Bleed
pressure off.
0.0 0.0
12/8/2023
21:00
12/8/2023
22:00
1.00 COMPZN, WHDBOP PRTS T Cameron bleed trapped air pressure
from valve cavities - all had air and
diesel in valve cavities except SSV.
Called out COP valve shop to grease all
frac tree valves.
0.0 0.0
12/8/2023
22:00
12/8/2023
22:30
0.50 COMPZN, WHDBOP PRTS T Attempt 6th test - pressure up to 5,100
psi - pressure bleed off 397 psi in 15
min. No visible leaks.
0.0 0.0
12/8/2023
22:30
12/8/2023
23:00
0.50 COMPZN, WHDBOP PRTS T Pull Cameron 2 way check valve.
Inspect O-ring seals. All seals in good
working order as per Cameron Rep. Fill
frac tree with diesel, Reinstall 2 way
check valve.
0.0 0.0
12/8/2023
23:00
12/9/2023
00:00
1.00 COMPZN, WHDBOP PRTS T Attempt 7th test - pressure up to 5,049
psi - pressure bleed off 367 psi in 15
min. No visible leaks. RU to test
individual tree valves.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 43/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/9/2023
00:00
12/9/2023
05:30
5.50 COMPZN, WHDBOP PRTS T Continue testing Frac tree w/ LRS, test
against closed swab with 5,000 psi,
pressure dropped off to 4,680 psi in 15
minutes, bleed off psi and open up all
valves on tree, pressure up to 1,135 psi
bled to 1,120 psi after 5 minutes,
increased psi to 2,000 stabilized @
1,946 psi after 5 minutes, increase psi to
3,400 stabilized @ 3,268 psi after 5
minutes, increase psi to 4,030 stabilized
@ 3,922 psi after 5 min, increased to
5,000 psi, psi bled to 2,874 psi over 3
hrs. pressure held constant at 2874 psi
for 15 minutes. Simops: continue
preparing next well cellar area, begin
between well maintenance on rams,
transfer water to pump room in
preparation for move, seat pump #1.
0.0 0.0
12/9/2023
05:30
12/9/2023
06:00
0.50 COMPZN, WHDBOP PRTS T Decision made to bleed off all psi and
rig down hardline & proceed with freeze
protect OA while plan forward options
are discussed for frac tree.
0.0 0.0
12/9/2023
06:00
12/9/2023
08:00
2.00 COMPZN, WHDBOP RURD T Rig down LRS equipment, 10k hardlines
and stow on trailer & LRS truck. Cap &
plug all ports on frac tree used for
pressure test. Rig up mud pump
injection line to OA on well head to
perform infectivity test. SIMOPS:
Continue maintenance on lower rams.
Place heater trunks & hooch to warm up
tires. Vacuum out centrifugal pumps.
0.0 0.0
12/9/2023
08:00
12/9/2023
09:00
1.00 COMPZN, WHDBOP FRZP P PJSM. Conduct injectivity test. Bring on
pumps. Fill lines from mud pump #2 to
OA with .5 bpm.@ 973 psi / 2 bbls
pumped. Formation appeared to break
over & pressure dropped to 854 psi.
Pressure slowly increased while
injecting at .5 bpm to 1107 psi max / 5.8
bbls total pumped. Shut down pumps &
isolated OA. Monitor pressure for 10
minutes. Initial 1,100 psi & final 603 psi
after 10 minutes test concluded. Blow
down injection line to pumps.
0.0 0.0
12/9/2023
09:00
12/9/2023
12:00
3.00 COMPZN, WHDBOP FRZP P Rig up LRS to OA & pressure test lines
to 2,400 psi. LRS freeze protect OA as
per CPAI pump down schedule. LRS
pump at .5 - 1 bpm until max pressure of
1500 psi initial &1585 final psi observed.
Let pressure relax & repeat process for
total of 16 bbls pumped into OA.
SIMOPS: Build dance floor for cellar.
Complete maintenance on lower BOP
rams.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 44/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/9/2023
12:00
12/9/2023
15:30
3.50 COMPZN, WHDBOP FRZP P Continue to freeze protect OA. LRS
pump at .5 - 1 bpm until max pressure of
1585 psi observed. Let pressure relax
and repeat the process for total of 24
bbls pumped. At 24 bbls formation broke
down & continued freeze protect at 1.5 -
2 bpm / initial 1100 psi - final 900 psi.
Shut in after pumping. Pressure almost
immediate dropped to ~760 psi.
Pumped a total of 85 bbls freeze protect
on OA. Left 760 psi on OA. Rig down
LRS from OA.
SIMOPS: PJSM on pressure testing frac
tree with DHD crew. Cameron pulled a
two-way check valve and redressed it
with new seals. Rig up rig test pump to
pump diesel through tubing tree cap.
Pressure test frac tree to 2,800 psi and
chart for 30 min. 1st attempt lost 225 psi
in 5 minutes. Bump pressure, 2nd
attempt lost 300 psi in 30 min (pressure
drop slowing throughout test). Bleed
pressure. Re-pressure up to 2800 psi,
lost 168 psi in 30 minutes with pressure
stabilizing. Bleed off pressure. Close
swab valve and pressure test against
tree cap to 2,800 psi and chart for 30
minutes lost 124 psi in 30 minutes with
pressure stabilizing.
Discussed pressure tests with DHD
crew and town. MIT of frac tree to 2800
psi is sufficient to verify barrier and
secure well. Decision made to move rig
off and tree will be swapped out post rig
prior to frac job.
0.0 0.0
12/9/2023
15:30
12/9/2023
17:30
2.00 COMPZN, WHDBOP PRTS P DHD request to pressure test hydraulic
SSV against tree cap. Open swab valve,
close SSV, purge lines. Test hydraulic
SSV to 2,800psi and chart for 30
minutes. On the 1st attempt, lost 200
psi in 5 minutes. Bump pressure up,
2nd attempt lost 254 psi in 30 minutes.
Bump pressure up, 3rd attempt lost 95
psi in 20 minutes. Bump pressure up,
4th attempt 81 psi in 30 minutes with
pressure stabilizing. Rig down testing
equipment and blow down lines
0.0 0.0
12/9/2023
17:30
12/9/2023
18:00
0.50 COMPZN, WHDBOP PULL P Cameron pull HP/two-way check valve
and BPV. Re-install tree cap.
0.0 0.0
12/9/2023
18:00
12/9/2023
20:00
2.00 COMPZN, WHDBOP RURD P Prepare for freeze protect. Rig up to
take returns to cellar via frac valve.
Verify Tec lines are clear. SIMOPS:
Install 4'' conductor valves on next well.
Secure surface drill pipe/ tools in pipe
shed.
0.0 0.0
12/9/2023
20:00
12/9/2023
21:45
1.75 COMPZN, WHDBOP FRZP P Hold PJSM for freeze protecting IA and
tubing. Begin pumping down IA taking
returns to cellar box, 1 BPM @ 181 psi
starting pressure, Max pressure 477 psi,
final pressure 181 psi @ 1.2 BPM. Total
pumped - 94 bbls diesel.
0.0 0.0
12/9/2023
21:45
12/9/2023
22:00
0.25 COMPZN, WHDBOP WWSP P PJSM. Set HP back pressure valve as
per Cameron.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 45/45
3S-617
Report Printed: 1/2/2024
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/9/2023
22:00
12/10/2023
00:00
2.00 DEMOB, MOVE RURD P Rig down LRS. Remove flange from IA
and OA valves. Install analog pressure
gauges. Secure frac tree @ 11:30 hrs.
Warm up cold start generators. Blow
down water lines and pressure washers.
Chain down pipe skate trough. Release
rig at 0000 hrs to 3S-624
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 12/10/2023
Page 1/1
3S-617
Report Printed: 1/2/2024
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
10/29/2023 05:30
Cementing End Date
10/29/2023 09:00
Wellbore Name
3S-617
Comment
SURFACE CEMENT JOB CEMENT 10 3/4'' SURFACE CSG AS PER HAL. PUMP SCH., FLOOD LINES 5 BBLS H20@ 2 BPM, 160PSI, PT LINES T/ 3500PSI,
PUMP 60 BBL, 10.2 PPG TUNED PRIME SPACE W/ 8LB RED DYE @ 3-4 BPM, 295-355 PSI, SHUTDOWN AND DROP BOTTOM PLUG. PUMP 450 BBLS
10.7 PPG LEAD CEMENT @ 5.5 BPM, 540 PSI. PUMP 56 BBLS 15.8 PPG TAIL CMT @ 3 BPM, 450 PSI, SHUTDOWN AND DROP TOP PLUG. FLUSH W/ 20
BBLS FRESH H20, LINE UP T/ RIG PUMPS T/ DISP. W/ 240 BBLS @ 6 BPM, 152-460 PSI F/ 2275 STKS, SLOW RATE T/ 3 BPM, 500 PSI F/ FINAL 2399
STKS, BUMP PLUG @ 2394 STKS INT. 500 PSI, PRESSURE UP T/ 1000 PSI HOLD F/ 5 MIN. CHECK FLOATS, (GOOD) CEMENT IN PLACE @ 08:48 HRS
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
39.7
Bottom Depth (ftKB)
2,778.8
Full Return?
Yes
Vol Cement …
201.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
5
P Pump Final (psi)
500.0
P Plug Bump (psi)
1,051.0
Recip?
Yes
Stroke (ft)
8.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
SURFACE CEMENT JOB CEMENT 10 3/4'' SURFACE CSG AS PER HAL. PUMP SCH., FLOOD LINES 5 BBLS H20@ 2 BPM, 160PSI, PT LINES T/ 3500PSI,
PUMP 60 BBL, 10.2 PPG TUNED PRIME SPACE W/ 8LB RED DYE @ 3-4 BPM, 295-355 PSI, SHUTDOWN AND DROP BOTTOM PLUG. PUMP 450 BBLS
10.7 PPG LEAD CEMENT @ 5.5 BPM, 540 PSI. PUMP 56 BBLS 15.8 PPG TAIL CMT @ 3 BPM, 450 PSI, SHUTDOWN AND DROP TOP PLUG. FLUSH W/ 20
BBLS FRESH H20, LINE UP T/ RIG PUMPS T/ DISP. W/ 240 BBLS @ 6 BPM, 152-460 PSI F/ 2275 STKS, SLOW RATE T/ 3 BPM, 500 PSI F/ FINAL 2399
STKS, BUMP PLUG @ 2394 STKS INT. 500 PSI, PRESSURE UP T/ 1000 PSI HOLD F/ 5 MIN. CHECK FLOATS, (GOOD) CEMENT IN PLACE @ 08:48 HRS
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.7
Est Btm (ftKB)
1,537.0
Amount (sacks)
861
Class
G
Volume Pumped (bbl)
448.0
Yield (ft³/sack)
2.92
Mix H20 Ratio (gal/sack)
14.94
Free Water (%) Density (lb/gal)
10.70
Plastic Viscosity (cP) Thickening Time (hr)
6.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
1,537.0
Est Btm (ftKB)
2,778.8
Amount (sacks)
275
Class
G
Volume Pumped (bbl)
56.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.02
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr)
4.50
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
3S-617
Report Printed: 1/2/2024
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
11/5/2023 20:00
Cementing End Date
11/5/2023 23:15
Wellbore Name
3S-617
Comment
Perform cement job for 7-5/8”" intermediate. casing as per Halliburton program, Flood lines with 5 bpm H2O 278 psi, Pressure Test lines to 4000psi,Drop #1
bottom plug , pump 60 bbls tuned 10.5 ppg spacer @ 3.75 bpm/ 573 psi 12% F/O, Drop #2 bottom plug, pump 142 bbls 15.3 ppg primary cmt with BM11 @ 6 bpm
787 psi 14% f/o, pump 22 bbls 15.3 ppg primary cmt without BM11 @ 4 bpm 275 psi 10% f/o, Drop top plug, pump 20 bbls fresh H2O, line up to rig pumps to
displace. with 337 bbls @ 6 bpm 207 psi 14% f/o f/ 2620 strokes. Cont. displacement @ 6 bpm 1045 psi F/O 13% f/ 3400 strokes, Slow rate to 3 bpm 852 psi
f/200 strokes, Slow rate to 2.5 bpm 887 psi for 200 strokes, Slow rate t/3 bpm @ 975 psi, Did not Bump plug. Stop pumping at 3593 strokes hold for 10 min. Bleed
off/ check floats. Shut in to monitor floats Cement in place at 2315 hrs
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
3,015.0
Bottom Depth (ftKB)
8,330.6
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
4
P Pump Final (psi)
975.0
P Plug Bump (psi) Recip?
Yes
Stroke (ft)
8.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Perform cement job for 7-5/8”" intermediate. casing as per Halliburton program, Flood lines with 5 bpm H2O 278 psi, Pressure Test lines to 4000psi,Drop #1
bottom plug , pump 60 bbls tuned 10.5 ppg spacer @ 3.75 bpm/ 573 psi 12% F/O, Drop #2 bottom plug, pump 142 bbls 15.3 ppg primary cmt with BM11 @ 6 bpm
787 psi 14% f/o, pump 22 bbls 15.3 ppg primary cmt without BM11 @ 4 bpm 275 psi 10% f/o, Drop top plug, pump 20 bbls fresh H2O, line up to rig pumps to
displace. with 337 bbls @ 6 bpm 207 psi 14% f/o f/ 2620 strokes. Cont. displacement @ 6 bpm 1045 psi F/O 13% f/ 3400 strokes, Slow rate to 3 bpm 852 psi
f/200 strokes, Slow rate to 2.5 bpm 887 psi for 200 strokes, Slow rate t/3 bpm @ 975 psi, Did not Bump plug. Stop pumping at 3593 strokes hold for 10 min. Bleed
off/ check floats. Shut in to monitor floats Cement in place at 2315 hrs
Cement Fluids & Additives
Fluid
Fluid Type
Primary Cement
Fluid Description Estimated Top (ftKB)
3,015.0
Est Btm (ftKB)
8,335.0
Amount (sacks)
752
Class
G
Volume Pumped (bbl)
162.0
Yield (ft³/sack)
1.25
Mix H20 Ratio (gal/sack)
5.56
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP)
16.0
Thickening Time (hr)
5.27
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
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InterpolatedInterpolated (3 3 -3 (7 (7 ( 6 ( 3 3 - 6 ( 7 73 3 3 7 3 (( 3 (3
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:142 DATE: 11/27/23
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #22230850 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/4000 Annular:250/3500 Valves:250/4000 MASP:1786
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1FP
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 3-1/2" x 6" VBR P Flow Indicator PP
#2 Rams 1 Blind/ Shear P Meth Gas Detector PP
#3 Rams 1 3-1/2" x 6" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3-1/8" 5M P System Pressure (psi)3000 P
Kill Line Valves 3 3-1/8" 5M P Pressure After Closure (psi)1850 P
Check Valve 0NA200 psi Attained (sec)9 (Sec)P
BOP Misc 0NAFull Pressure Attained (sec)48 (sec)P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge: 1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 1967psi P
No. Valves 14 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 11 P
#1 Rams 7 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0NA #3 Rams 7 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:1 Test Time:5.5 hrs HCR Choke 2 P
Repair or replacement of equipment will be made within 0 days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 11/26/23 / 06:00
Waived By
Test Start Date/Time:11/26/2023 21:30
(date) (time)Witness
Test Finish Date/Time:11/27/2023 3:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
F. Carlo/H. Huntington
Conoco
Adam Dorr/Byron Marmon
KRU 3S-617
Test Pressure (psi):
rig142@doyondrilling.com
d142cm@conocophillips.com
Test Annular w/ 4" & 4-1/2" test jt 250/3500psi, Test upper & lower 3-1/2" x 6"VBR 250/4000psi w/ 4" & 4-1/2" test jt. Test 2ea-
4"FOSV/ 1ea-4" Dart 250/4000psi Test manual & hydraulic choke to 2,000 psi, Choke valves #'s 1-14, Choke & Kill Manuals &
HCR, 4"Demco valve on Kill, Upper & Lower IBOP,250/4000psi, test all H2S and gas alarms, PVT, and flow alarms/both
audible and visual. All rams functioned from both primary and remote controls. Drawdown conducted w/ 2 air, and 2ea
electrical air pumps. Rig is on 3-week test cycle. One FP on Hydraulically operated IBOP, greased and retested good.
Form 10-424 (Revised 08/2022) 2023-1127_BOP_Doyon142_KRU_3S-617
99
9
9
9999
9
9
9
9
-5HJJ
FP
Rig is on 3-week test cycle
y
FP on Hydraulically operated IBOP
1
Regg, James B (OGC)
From:Rig 142 <rig142@doyondrilling.com>
Sent:Saturday, November 4, 2023 6:03 PM
To:Regg, James B (OGC)
Cc:DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Subject:7-5/8" casing rams 11-4-23
Attachments:7.625in Casing Rams Test Chart 11-4-2023.pdf
Kelly Haug
Rig 142 Tourpusher
Rig142@doyondrilling.com
Doyon Rig 142 Office 907-670-6002
Cell, 907-355-5834
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
KRU 3S-617PTD 2230850
PTD 2230850
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 3S-617
JBR 12/06/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
Tested all Gas alarmes and PVT's, Tested with 5" test joint, Kill Line OTECO flange leaked was tightened and passed retest.
Precharge Bottles Pressures = 3@900, 2@910, 3@920, 1@940, 2@950, 4@1000 and 1 @1050.
Test Results
TEST DATA
Rig Rep:B. Marmon / M ArthurOperator:ConocoPhillips Alaska, Inc.Operator Rep:M. Sam / H. Huntington
Rig Owner/Rig No.:Doyon 142 PTD#:2230850 DATE:10/30/2023
Type Operation:DRILL Annular:
250/3500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopBDB231031100135
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 5
MASP:
1786
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 3 1/2"x6"P
#2 Rams 1 Blind/Shear P
#3 Rams 1 3 1/2"x6"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"P
HCR Valves 2 3 1/8"P
Kill Line Valves 1 3 1/8"P
Check Valve 0 NA
BOP Misc 1 flange FP
System Pressure P3000
Pressure After Closure P1900
200 PSI Attained P9
Full Pressure Attained P50
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1966
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P19
#1 Rams P8
#2 Rams P7
#3 Rams P8
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
99
9 9999
9
9
9
9
9
flange FP
Kill Line OTECO flange leaked
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
700 G Street
Anchorage, AK, 99501
Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-617
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-085
Surface Location: 2748' FSL, 4155' FWL, SENE S18 T12N R8E
Bottomhole Location: 3362' FSL, 3110' FWL, NESW S35 T13N R7E
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of October 2023.
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.10.17 21:10:16
-06'00'
17
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: 21263 TVD: 5145
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
10/29/2023
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
3361' to ADL025528
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 63.3 15. Distance to Nearest Well Open
Surface: x-476135 y- 5993884 Zone- 4 24.3 to Same Pool: 2745' to 3S-611
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 89.4 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 94 H-40 Welded 81 39 39 120 120
13.5" 10.75" 45.5 L-80 Hyd563 2739 39 39 2778 2562
9.875" 7.625" 29.7 L80 Hyd563 7478 39 39 7517 4806
9.875" 7.625" 33.7 P110S Hyd563 800 7517 4806 8317 5139
6.5" 4.5" 12.6 P110S Hyd563 13096 8167 5091 21263 5145
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Matt Smith
Chris Brillon Contact Email:matt.smith2@cop.com
Wells Engineering Manager Contact Phone:907-263-4324
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Perforation Depth MD (ft): Perforation Depth TVD (ft):
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Authorized Name:
Authorized Title:
Authorized Signature:
Commission Use Only
See cover letter for other
requirements.
Intermediate
Production
Liner
Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
Surface
Conductor/Structural
Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Casing Length Size Cement Volume MD
Total Depth MD (ft): Total Depth TVD (ft):
860sks 10.7ppg, 280sks 15.8ppg
740sks 15.3ppg
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 3S-617
10 yds
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
Torok Oil Pool
2748' FSL, 4155' FWL, SENE S18 T12N R8E ADL380107 / ADL380106 / ADL025528 / ADL393883
(including stage data)
1498' FSL, 4809' FWL, NESE S12 T12N R7E LONS 01-013
3362' FSL, 3110' FWL, NESW S35 T13N R7E 2448 / 2437 / 2560 / 5759
GL / BF Elevation above MSL (ft):
2301 1786
18. Casing Program:
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 9:24 am, Oct 06, 2023
X
97
92
50-103-20864-00-00
Alaska, Inc.
Diverter variance request granted per 20 AAC 20.035(h)(2), based on CPAI offset analysis of 3S-611,
3S-612, and 3S-18. -A.Dewhurst 29SEP23
KRU
DSR-10/9/23
Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig
Annular preventer test to 2500 psig
Waiver for CPAI Rotary BOPE Test Frequency applies according to order OTH-21-018 extension attached
Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available
223-085
A.Dewhurst 10OCT23VTL 10/16/2023
97
*&:JLC 10/17/2023
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.10.17 21:10:42 -06'00'10/17/23
10/17/23
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: 21276 TVD:5149
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
10/6/2023
Total Depth:9. Acres in Property:14. Distance to Nearest Property:
3361' to ADL025528
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 66.7 15. Distance to Nearest Well Open
Surface: x-5993884.16 y- 476134.88 Zone- 4 27.7 to Same Pool: 2745' to 3S-611
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 89.4 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 94 H-40 Welded 81 39 39 120 120
13.5" 10.75" 45.5 L-80 Hyd563 2744 39 39 2783 2566
9.875" 7.625" 29.7 L80 Hyd563 7401 39 39 7440 4806
9.875" 7.625" 33.7 P110S Hyd563 800 7440 4806 8240 5163
6.5" 4.5" 12.6 P110S Hyd563 13186 8090 5091 21276 5149
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Matt Smith
on behalf of Chris Brillon Contact Email:matt.smith2@cop.com
Wells Engineering Manager Contact Phone:907-263-4324
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Perforation Depth MD (ft): Perforation Depth TVD (ft):
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Authorized Name:
Authorized Title:
Authorized Signature:
Commission Use Only
See cover letter for other
requirements.
Intermediate
Production
Liner
Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
Surface
Conductor/Structural
Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Casing Length Size Cement Volume MD
Total Depth MD (ft): Total Depth TVD (ft):
870sks 10.7ppg, 280sks 15.8ppg
730sks 15.3ppg
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 3S-617
10 yds
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
Torok Oil Pool
2748' FSL, 4155' FWL, SENE S18 T12N R8E ADL380107 / ADL380106 / ADL025528 / ADL393883
(including stage data)
1419' FSL, 4855' FWL, NESE S12 T12N R7E LONS 01-013
3362' FSL, 3110' FWL, NESW S35 T13N R7E 2448 / 2437 / 2560 / 5759
GL / BF Elevation above MSL (ft):
2162 1648
18. Casing Program:
Stratigraphic Test
Nooo Mud log req'd: Yes No o
No Directional svy req'd: Yes Nooo
Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements
BOP SketchDrillingProgram Time v. Depth PlotShallow HazardAnalysis
Single Well
GasHydrates
Noooo Inclination-only svy req'd: Yes No ooo
Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal
Noooo
sNo
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 10:43 am, Sep 15, 2023
50-103-20864-00-00
-A.Dewhurst 21SEP23
92
x: 476134.88
y: 5993884.16
Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig
Annular preventer test to 2500 psig
BOP test to 3000 psig approved while drilling the Int1 section
The alternate BOP configuration attached while drilling the Int 1 is approved
Waiver for CPAI Rotary BOPE Test Frequency applies according to order OTH-21-018 extension attached
Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available.
Alaska, Inc.
Diverter variance request granted per 20 AAC 20.035(h)(2), based on CPAI offset analysis of 3S-611,
3S-612, and 3S-18. -A.Dewhurst 29SEP23
X
-A.Dewhurst 29SEP232302
1125' FEL SFD
KRU
1788
5143
223-085
DSR-9/15/23
Superceded by ammended 10-401
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
March 2, 2023
Mr. Luke Lawrence
Wells Manager
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Re: Docket Number: OTH-21-018
CPAI Rotary Rig BOPE Test Frequency
Dear Mr. Lawrence:
By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of
the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test
blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas
Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope.
OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25,
2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6,
2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance
Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on
February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of
the CPAI-operated rigs during 2022 in considering the requested continuance.1
During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate
in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21-
day intervals.2
CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is
approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions:
- The pilot test duration is for ONE year from the approval date of this letter, subject to
potential extension and expansion to include other CPAI operated rigs with at least 3
months of continuous rig work and AOGCC review of a rig’s BOPE system reliability.
1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the
interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for
allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of
component failures during BOPE testing by replacing components that indicate suspect integrity before those
components fail during testing.
2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre-
determined time intervals while drilling specific sections in an ultra-extended reach well.
Docket Number: OTH-21-018
March 2, 2023
Page 2 of 2
- CPAI must continue to implement the BWM program as approved by AOGCC.
- Development drilling wells only are included in this approval.
- The initial test after rigging up BOPE to drill a well must be to the rated working pressure
as provided in API Standard 53.
- CPAI is encouraged to take advantage of opportunities to test.
- CPAI must adhere to original equipment manufacturer recommendations and replacement
parts for BOPE.
- Requests for extensions beyond 21 days must include justification with supporting
information demonstrating the additional time is necessary for well control purposes or to
mitigate a stuck drill string.
- 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to
witness.
If you have questions regarding this, please contact Jim Regg at (907) 793-1236.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
cc: Greg Hobbs (CPAI)
Mike Kneale (CPAI)
Victoria Loepp (AOGCC)
AOGCC Inspectors (email)
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.02 11:09:23
-09'00'
<Zhϯ^Ͳϲϭϳ
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
October 4, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Updated Application for Permit to Drill 3S-617
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. recently applied for a Permit to Drill an onshore Moraine Injector well from the 3S drilling pad,
well 3S-617. The updated spud date for this well is 10/29/2023.
At the time of the original PTD submission, we did not have a final surface hole location, in which to base our directional plans
on, due to ongoing SIMOPS on the pad, namely the final P&A of the original slots wellbore. It was requested that we submit
the PTD with the estimated surface hole location, and then re-submit a corrected 10-401, directional plan, and wellbore
schematic, to allow for sufficient review time.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
3. Updated wellbore schematic
If you have any questions or require further information, please contact Matt Smith at 907-263-4324
(matt.smith2@conocophillips.com) or Chris Brillon at 907-265-6120.
Sincerely, cc:
3S-617 Well File / Jenna Taylor ATO 1560
David Lee ATO 1552
Matt Smith Chris Brillon ATO 1548
Drilling Engineer Roland Kirschner ATO 636
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
September 15, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill 3S-617
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine Injector well from the 3S drilling pad.
The intended spud date for this well is 10/6/2023. It is intended that Doyon 142 be used to drill the well.
3S-617 will utilize a 13 1/2” surface hole drilled to TD and 10 3/4” casing will be set and cemented to surface. The 9 7/8”
intermediate hole will be drilled and topset the Moraine reservoir. A 7 5/8” casing string will be set and cemented from TD to
secure the shoe and cover 500’MD or 250’TVD above any hydrocarbon-bearing zones (Coyote).
The production interval will be comprised of a 6 1/2” horizontal hole that will be landed and geo-steered in the Moraine
formation. The well will be completed as an uncemented, fracture stimulated Injector with 4 1/2” liner, frac sleeves and swell
packers. The upper completion will include a production packer with GLM’s and tied back to surface.
It is requested that a variance of the diverter requirement under 20AAC 25.035(h)(2) is granted for well 3S-617. At 3S, there
has not been a significant indication of shallow gas hydrates though the surface hole interval.
The surface location is not final. An updated 10-401, final directional plan, and wellbore schematic will be provided once
available, for final approval.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC
25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Matt Smith at 907-263-4324
(matt.smith2@conocophillips.com) or Chris Brillon at 907-265-6120.
Sincerely, cc:
3S-617 Well File / Jenna Taylor ATO 1560
David Lee ATO 1552
On behalf of Matt Smith Chris Brillon ATO 1548
Drilling Engineer Roland Kirschner ATO 636
n uncemented, fracture stimulated Injector
The surface location is not final. A
Application for Permit to Drill, 3S-617
Saved: 15-Sep-23
3S-617 PTD
Page 1 of 10
Printed: 15-Sep-23
3S-617
Application for Permit to Drill Document
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................................ 2
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................................................................... 2
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) ........................................................................ 4
4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) ............................................................. 4
5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) ..................................................................................... 4
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) ................................................................................ 5
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) ............................ 6
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ........................................................... 6
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................................................................. 6
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ........................................ 7
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ................................................................................... 7
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................................................... 7
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ............................................................................. 7
14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) ......... 7
15. Drilling Hazards Summary ................................................................................................................................. 8
16. Proposed Completion Schematic ..................................................................................................................... 10
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as 3S-617
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface 2748‘ FSL, 4155‘ FWL, SENE S18 T12N R8E, UM
NAD 1927
Northings: 5993884
Eastings: 476135
RKB Elevation 66.7’AMSL
Pad Elevation 27.7’AMSL
Top of Productive Horizon
(Heel)
1419‘ FSL, 4855‘ FWL , NESE S12 T12N R7E, UM
NAD 1927
Northings: 5997848
Eastings: 472043
Measured Depth, RKB:
8305’
Total Vertical Depth, RKB: 5,163’
Total Vertical Depth, SS: 5,096’
Total Depth (Toe) 3362‘ FSL, 3110‘ FWL, NESW S35 T13N R7E, UM
NAD 1927
Northings: 6010363
Eastings: 468762
Measured Depth, RKB: 21,276 ’
Total Vertical Depth, RKB: 5,149
Total Vertical Depth, SS: 5,082 ’
Pad Layout
476135
472043
468762
5997848
-A.Dewhurst 21SEP23
5993884
6010363
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13))
The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic.
1. MIRU Doyon 142 onto 3S-617.
2. Rig up and test riser, dewater cellar as needed.
3. Drill 13 1/2” hole to the surface casing point as per the directional plan.
4. Run and cement 10 3/4” surface casing to surface.
5. Install BOPE and MPD equipment.
6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr regulatory notice).
7. Pick up and run in hole with 9 7/8” drilling BHA to drill the intermediate hole section.
8. Chart casing pressure test to 3000 psi for 30 minutes.
9.Drill out 20’ of new hole and perform LOT. Maximum LOT to 16 ppg. Minimum LOT required to drill ahead is 11.5
ppg EMW.
10. Drill 9 7/8” hole to section TD, setting pipe ~20’ TVD above the Moraine Reservoir. (LWD Program: GR/RES).
11. Run 7 5/8” casing and cement to a minimum of 500’ MD or 250’ TVD above any hydrocarbon bearing zones
(cementing schematic attached). Chart casing pressure test on plug bump to 4,000 psi for 30 minutes.
12. Test BOPE to 250 psi low / 4,000 psi high (24-48 Regulatory notice).
13. Pick up and run in hole with 6 1/2” drilling BHA. Log top of cement with sonic tool in recorded mode.
14. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 14.5 ppg. Minimum required leak-
off value is 11.5 ppg EMW.
15. Drill 6 1/2” hole to section TD (LWD Program: GR/RES/Den/Neu).
16. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC.
17. Run 4 1/2” liner with toe-valve, frac sleeves and swell packers and liner hanger to TD.
18. Run 4 1/2” upper completion with production packer, landing nipple, ball seat, gas lift mandrel(s), and downhole
gauge. Space out and land tubing hanger with pre-installed and pre-tested BPV.
19. Pressure test hanger seals to 3,850 psi.
20. Drop ball and rod to set production packer, test tubing to 4,550 psi, chart test.
21.Bleed tubing pressure to 2200 psi and test IA to 3,850 psi, chart test.
22. Install HP-BPV and test to 2500 psi.
23. Nipple down BOP.
24. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
25. Freeze protect down tubing and annulus.
26.Secure well. Rig down and move out.
Please note – This well will be frac’d
4.Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3))
Please reference BOP schematics on file for Doyon 142.
5. Diverter System (Requirements of 20 AAC 25.005(c)(7))
It is requested that a variance of the diverter requirement under 20 AAC 25.035(h)(2) is granted. At 3S, there has not been
significant indication of shallow gas or gas hydrates through the surface hole interval. There is one previously drilled well
(3S-612) within 500’ of the proposed 3S-617 surface shoe location and one well (3S-18) just greater than 500’ from the
proposed 3S-617 surface shoe location. Neither of these wells encountered any significant indication of shallow gas or gas
hydrates.
a variance of the diverter requirement u
d MPD equipment.
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4))
The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well:
Casing
Size (in)
Csg Setting Depth
MD/TVD(ft)
Fracture
Gradient (ppg)
Pore pressure
(psi)
ASP Drilling
(psi)
20 120 / 120 10.9 54 56
10 3/4 2783 / 2566 12.5 1147 1411
7 5/8 8240 / 5,143 13.5 2300 1788
4 1/2 21,276 / 5,149 13.0 2302 n/a
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the
surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows:
1) ASP = [(FG x 0.052) - 0.1]*D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb./gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP – (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
FPP = 0.4525 x TVD
1. ASP CALCULATIONS
1. Drilling below 20” conductor
ASP = [(FG x 0.052) – 0.1] D
= [(10.9 x 0.052) – 0.1] x 120 = 56 psi
OR
ASP = FPP – (0.1 x D)
= 1147 – (0.1 x 2566) = 890 psi
2. Drilling below 10 3/4” surface casing
ASP = [(FG x 0.052) – 0.1] D
= [(12.5 x 0.052) – 0.1] x 2,566 = 1411 psi
OR
ASP = FPP – (0.1 x D)
= 2300 – (0.1 x 5143) = 1786 psi
3. Drilling below 7 5/8” intermediate casing
ASP = [(FG x 0.052) – 0.1] D
= [(13.5 x 0.052) – 0.1] x 5,143 = 3096 psi
OR
ASP = FPP – (0.1 x D)
= 2302– (0.1 x 5,149 )= 1788 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any shallow gas zones.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones,
and zones that have a propensity for differential sticking;
Please see Drilling Hazards Summary
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5))
Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file with
the Commission.
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing and Cementing Program
Csg/Tbg
OD (in)
Hole Size
(in)
Weight
(lb/ft) Grade Conn. Cement Program
20 42 94 H-40 Welded Cemented to surface with 10 yds slurry
10 3/4 13 1/2 45.50 L-80 Hyd563 Cement to Surface
7 5/8 9 7/8 29.70
33.70
L80
P110S
Hyd563
Hyd563
250’ TVD or 500’ MD, whichever is greater, above upper
most producing zone (Coyote)
4 1/2 6 1/2 12.60 P110S Hyd563 Cemented liner with frac sleeves
Cementing Calculations
10 3/4” Surface Casing run to 2,783 ’ MD / 2,566 ’ TVD
Cement from 2,783’ MD to 2,283' (500’ of tail) with Class G + Add's @ 15.8 PPG, and from 2,283' to surface with 10.7
ppg Arctic Lite Crete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost
(1742.78’ MD), zero excess in 20” conductor.
Lead slurry from 2,283’ MD to surface with Arctic Lite Crete @ 10.7 ppg
Total Volume = 2,528 ft3 => 866 sx of 10.7 ppg Class G + Add's @ 2.92 ft3 /sk
Tail slurry from 2,783 ’ MD to 2,283’ MD with 15.8 ppg Class G + Add's
Total Volume = 316 ft3 => 273 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk
7 5/8” Intermediate Casing run to 8240’ MD / 5,143 ’ TVD
Top of slurry is designed to be at 5361’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest
hydrocarbon bearing zone, Coyote. If a shallower hydrocarbon zone of producible volumes, is encountered while
drilling, a 2-stage cement job will be performed to isolate this zone. Assume 40% excess annular volume.
Tail slurry from 8240’ MD to 5,361’ MD with 15.3 ppg Class G + Add's
Total Volume = 887 ft3 => 722 sx of 15.3 ppg Class G + Add’s @ 1.23 ft3/sk
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in. 13 1/2 9 7/8 6 1/2
Casing Size in. 10 3/4 7 5/8 4 1/2
Density PPG 9.0 – 10.5 9.0 – 9.8 9.0 – 10.0
PV cP 20-50 8-15 7-12
YP lb./100 ft2 30 - 80 20 - 30 15 - 25
Funnel Viscosity s/qt.
250 – 300 to
base perm
200-300 to TD
40-60 35-50
Initial Gels lb./100 ft2 30 - 50 8 - 15 5- 10
10 Minute Gels lb./100 ft2 50 - 70 <20 7 - 15
API Fluid Loss cc/30 min. N.C. – 15.0 < 10.0 < 6.0
HPHT Fluid Loss cc/30 min. N/A N/A < 10.0
pH 9.0 – 10.0 9.0 – 10.0 9.5 – 10.5
Surface Hole:
A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to maintain
proper specifications The mud weight will be maintained at 10.5 ppg by use of solids control system and dilutions
where necessary.
Intermediate:
Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular
velocity. Maintain mud weight at or below 9.8 ppg for formation stability and be prepared to add loss circulation
material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)
will all be important. The mud will be weighted up to 9.8 ppg before pulling out of the hole.
Production Hole:
The horizontal production interval will be drilled with a water-based mud drill-in fluid (KlaShield) weighted to 9.0 – 10.0
ppg. MPD will be available for adding backpressure during connections if necessary.
Diagram of Doyon 142 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11))
N/A - Application is not for an offshore well.
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC
25.005 (c)(14))
Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II
disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind
and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored,
tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in
accordance with a permit from the State of Alaska.
15. Drilling Hazards Summary
13 1/2" Hole / 10 3/4” Casing Interval
Event Risk Level Mitigation Strategy
Conductor Broach Low Monitor cellar continuously during interval.
Well Collision Low Follow real time surveys very closely, gyro survey as
needed to ensure survey accuracy.
Gas Hydrates Low If observed – control drill, reduce pump rates and
circulating time, reduce mud temperatures
Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),
pumping out
Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times
when possible
Running sands and gravels Low Maintain planned mud properties, increase mud
weight, use weighted sweeps
9 7/8” Hole /7 5/8” Casing Interval
Event Risk Level Mitigation Strategy
Sloughing shale / Tight hole /
Stuck Pipe
Low Good hole cleaning, pre-treatment with LCM, stabilized
BHA, maintain planned mud weights and adjust as
needed, real time equivalent circulating density (ECD)
monitoring
Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time ECD
monitoring, mud rheology, add lost circulation material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper
hole filling, pump out of hole, real time ECD monitoring,
Liner will be in place at TD
Abnormal Reservoir Pressure
(Coyote / K3)
Low Well control drills, check for flow during connections,
increase mud weight if necessary
6 1/2” Hole / 4 1/2” Liner - Horizontal Production Hole
Event Risk Level Mitigation Strategy
Lost circulation Moderate Reduce pump rates, real time ECD monitoring,
maintain mud rheology, add lost circulation material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper
hole filling, pump out of hole, real time ECD monitoring
Abnormal Reservoir Pressure Low Well control drills, check for flow during connections,
increased mud weight, LCM on location
Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe
moving, control mud weight
Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA, perform
clean out run if necessary, utilize super sliders for
weight transfer if needed, monitor T&D real time
Well Proximity Risks:
3S is a multi-well pad, containing an original 26 wells. Directional drilling / collision avoidance information as required by
AOGCC 20 ACC 25.050 (b) is provided in the following attachments.
Drilling Area Risks:
(Coyote / K3)
Reservoir Pressure: Offset production and injection has the potential to increase or decrease reservoir pressure above or below
normally pressured. Although this is unlikely, the rig will be prepared to weight up if required.
Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate
section.
Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost
circulation if needed.
Good drilling practices will be stressed to minimize the potential of taking swabbed kicks.
Top Coyote@ 5,930' MD / 4,097' TVD
3S-617 Wellbore Schematic
Grassroots Horizontal Moraine Injector
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
2,778’ MD / 2,562' TVD
Conductor: 97'
Production Liner: 4-½" 12.6#, P110S, Hydril 563
@ 21,263' MD / 5,145' TVD, 90° Inc
Tubing: 4-½”12.6#, L-80, Hydril 5639-;" Intermediate Hole
6-1/2" Production Hole
13-½" Surface Hole
Intermediate Casing: 7-<" 29.7#, L80, Hydril 563 /
800' 33.7#, P110S, Hyd563 Heavy Heel @ 8,317'
MD / 5,139' TVD
Updated: 10/04/23
by M. Smith
4-½” x 5.8" OD Swell Packer Frac sleeve (ball drop)
Sp
u
d
M
u
d
3.562", DB Nipple
FlexLock/ZXP, Liner Top Packer, Hanger 8,090' MD / 5,091’ TVD
4-½” x 7-< " TNT Packer
TOC @ 5,375’ MD / 3847’ TVD (250' TVD above hydrocarbon bearing zone)
Downhole Gauge
Top Torok Oil Pool (Moraine) @ 8,384 MD / 5,159' TVD
Gas Lift Mandrel, 4-½” x 1”
Wellbore Isolation Valve /
Alpha Sleeve
Gas Lift Mandrel, 4-½” x 1”
6-½” Production Section TD
@ 21,263' MD / 5,145' TVD, 90° Inc
16. Proposed Completion Schematic
Top Coyote@ 5,905' MD / 4,101' TVD
3S-617 Wellbore Schematic
Grassroots Horizontal Moraine Injector
Surface Casing: 10-¾" 45.5#, L-80, Hydril 563 @
2,783’ MD / 2,566' TVD
Conductor: TBD
Production Liner: 4-½" 12.6#, P110S, Hydril 563
@ 21,276' MD / 5,149' TVD, 90° Inc
Tubing: 4-½”12.6#, L-80, Hydril 5639-и" Intermediate Hole
6-1/2" Production Hole
13-½" Surface Hole
Intermediate Casing: 7-з" 29.7#, L80, Hydril 563 /
800' 33.7#, P110S, Hyd563 Heavy Heel @ 8,240'
MD / 5,143' TVD
Updated: 09/13/23
by M. Smith
4-½” x 5.8" OD Swell Packer Frac sleeve (ball drop)
Sp
u
d
M
u
d
3.562", DB Nipple
FlexLock/ZXP, Liner Top Packer, Hanger 8,090' MD / 5,091’ TVD
4-½” x 7-з " TNT Packer
TOC @ 5,361’ MD / 3851’ TVD (250' TVD above hydrocarbon bearing zone)
Downhole Gauge 12,452’ MD / 5,042’ TVD
Top Torok Oil Pool (Moraine) @ 8,305 MD / 5,163' TVD
Gas Lift Mandrel, 4-½” x 1”
Wellbore Isolation Valve /
Alpha Sleeve
Gas Lift Mandrel, 4-½” x 1”
6-½” Production Section TD
@ 21,276' MD / 5,149' TVD, 90° Inc
Superceded by ammended schematic
39 400
400 600
600 900
900 1200
1200 1500
1500 2000
2000 2500
2500 3000
3000 5000
5000 8000
8000 1200
1200 17000
17000 21264
3S-617 wp07 Plan Summary
0
3
Do
g
l
e
g
S
e
v
e
r
i
t
y
0 3000 6000 9000 12000 15000 18000 21000
Measured Depth
10-3/4" Surface Casing 7-5/8" Intermediate Casing
4-1/2" Production Liner
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
57107157207257307357407457506556
606
3S-14
57107157207257307356406456506556606656706756
806
856
906
3S-15
57107157207
257307357407456506556606655705754804853902950999
10473S-16
57107157207257307356406456506557607657708758809859
3S-17
57107157207257307356406456506557607657708758809859
57107157207257
307357407457507557608658708
7588093S-18 57
107157207257307357407457508558608
3S-19
10931142
119212421292134113911441149115401590
16401689173917891839188919393S-612
53103153203253303352402452501
551
600
648
697
745
793
3S-615
61
111161
211261311361411461511562612662
3S-620
4797147197247297346396446496545595645694
3S-714 wp02
4797147197247297346396447497546596645
693
741
788
835
3S-718 wp03
4797147197247297346396447
497547598648698748798
3S-719 wp03
4797147197247297346396446496546595645695745794844894943
993
1043
1093
1143
3S-723 wp01
2750
Tr
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V
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D
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0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 335.71°
10-3/4" Surface Casing
7-5/8" Intermediate Casing 4-1/2" Production Liner
15
30
Ce
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C
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p
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0 400 800 1200 1600 2000 2400 2800
Measured Depth
Equivalent Magnetic Distance
DDI
7.099
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.00 1800.00 3S-617 wp07 (3S-617) SDI_URSA1_I4
1800.00 2770.00 3S-617 wp07 (3S-617) MWD+IFR2+SAG+MS
2770.00 8310.00 3S-617 wp07 (3S-617) MWD+IFR2+SAG+MS
8310.00 21263.86 3S-617 wp07 (3S-617) MWD+IFR2+SAG+MS
Ground / 24.30
CASING DETAILS
TVD MD Name2562.30 2778.46 10-3/4" Surface Casing5139.30 8318.16 7-5/8" Intermediate Casing5145.12 21263.86 4-1/2" Production Liner
Mag Model & Date: BGGM2023 01-Nov-23
Magnetic North is 14.48° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.65° 57230.46nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 600.00 3.00 316.00 599.91 3.77 -3.64 1.50 316.00 4.93 Start Build 1.75
4 800.00 6.50 316.00 799.19 15.68 -15.14 1.75 0.00 20.52 Start Build 2.00
5 1525.82 21.02 316.00 1502.30 139.52 -134.73 2.00 0.00 182.59 Start 107.13 hold at 1525.82 MD
6 1632.94 21.02 316.00 1602.30 167.15 -161.42 0.00 0.00 218.75 Start Build 2.00
7 2778.46 43.93 316.00 2562.30 606.61 -585.80 2.00 0.00 793.87
8 2798.46 43.93 316.00 2576.70 616.59 -595.43 0.00 0.00 806.93
9 3576.80 63.23 312.91 3036.71 1051.57 -1041.75 2.50 -8.30 1387.00
10 7834.95 63.23 312.91 4954.62 3640.19 -3826.08 0.00 0.00 4891.77
11 9079.62 87.00 343.00 5279.06 4648.79 -4436.48 3.00 55.62 6062.17
12 9279.62 87.00 343.00 5289.53 4839.79 -4494.87 0.00 0.00 6260.28 3S-617 [Harriman] T1 072723
13 9299.62 87.00 343.00 5290.58 4858.89 -4500.71 0.00 0.00 6280.10
14 9882.72 91.59 346.60 5297.75 5421.31 -4653.53 1.00 38.11 6855.58
1510644.49 91.59 346.60 5276.60 6162.04 -4830.05 0.00 0.00 7603.37
1610700.87 91.45 346.05 5275.10 6216.81 -4843.37 1.00 -104.48 7658.76 3S-617 [Harriman] T2 072723
1710755.14 91.96 345.86 5273.49 6269.43 -4856.54 1.00 -20.19 7712.15
1812406.69 91.96 345.86 5217.02 7870.02 -5259.69 0.00 0.00 9336.89
1912452.68 91.50 345.84 5215.63 7914.60 -5270.93 1.00 -177.19 9382.14 3S-617 [Harriman] T3 061923
2012496.19 91.07 345.83 5214.66 7956.78 -5281.57 1.00 -178.11 9424.97
2114443.83 91.07 345.83 5178.45 9844.80 -5758.42 0.00 0.0011342.01
2214480.35 90.70 345.83 5177.89 9880.19 -5767.35 1.00 179.3211377.95 3S-617 [Harriman] T3 072723
2314521.33 90.29 345.84 5177.54 9919.93 -5777.38 1.00 178.2111418.29
2418335.78 90.29 345.84 5158.21 13618.48 -6710.32 0.00 0.0015173.22
2518336.86 90.28 345.84 5158.20 13619.52 -6710.58 1.00 -164.7815174.28 3S-617 [Harriman] T4 072723
2618339.31 90.26 345.83 5158.19 13621.90 -6711.18 1.00 -167.8915176.69
27 21263.86 90.26 345.83 5145.12 16457.50 -7426.86 0.00 0.0018055.68 3S-617 [Harriman] T5 072723
FORMATION TOP DETAILS
TVDPath Formation
1366.30 Top Ugnu C
1631.30 Top Ugnu B
1700.30 Base Permafrost
1742.30 Top Ugnu A
2022.30 Top West Sak
2441.30 Base West Sak
2612.30 C-80
3347.30 C-50
3944.30 C-35
4097.30 Top Coyote
4450.30 Base Coyote
5159.30 Top Torok
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by Accepted by Approved by
Plan 24.3+39 @ 63.30usft (D142)
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0 400 800 1200 1600 2000 2400
Partial Measured Depth
3S
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3S
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3S
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3S
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Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
-24.30 1736.70 3S-617 wp07 (3S-617) SDI_URSA1_I4
1736.70 2706.70 3S-617 wp07 (3S-617) MWD+IFR2+SAG+MS
2706.70 8246.70 3S-617 wp07 (3S-617) MWD+IFR2+SAG+MS
8246.70 21200.56 3S-617 wp07 (3S-617) MWD+IFR2+SAG+MS
11:59, October 04 2023
CASING DETAILS
TVD MD Name
2499.00 2715.16 10-3/4" Surface Casing
5076.00 8254.86 7-5/8" Intermediate Casing
5081.82 21200.56 4-1/2" Production Liner
42 403
403 603
603 903
903 1203
1203 1503
1503 2003
2003 2503
2503 3003
3003 5003
5003 8003
8003 1203
1203 17003
17003 21267
3S-617 wp07 TC View
30
30
60
60
90
90
120
120
150
150
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
60
110160210260310360410
4583S-08
60
110160210260310360410
4583S-08A
60
110160210260310360410
4583S-08B
61
111161211261311361411
4593S-08C
61
111161211261311361411
4593S-08CL1
61
111161211261311361411
4593S-08CL1PB1
601101602102603103604104585073S-09
60
1101602102603103604104595085576066557033S-10
61111161211261311361411460510559609
658
708
757
806
856
905
954
1003
1053
1102
1151
3S-14
60110160210260310360410459509559609659709759809
859
909
960
1010
1060
1110
1160
1211
1261
1312
1362
1413
1463
3S-15
60110160210
26031036041046051056060965970875880785690595410021050
1099
1146
1194
1241
1287
1334
1379
1424
3S-16
601101602102603103604104605105606106617117618128629139641015106511161167121812691320137114223S-17
601101602102603103604104605105606106617117618128629139641015106511161167121812691320137114223S-17A
60110160210260
310360410460511561611661712
762812862913963101410641114116512151266131613663S-18
61
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409
459
508
557
606
655
702
750
796
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1117
1166
1216
1266
1315
13643S-22
61
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511
561
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461
511
561
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511
561
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509560611662713763814864
915
964
1014
1063
1112
1160
1208
1256
1303
1350
1396
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509560611662713763814864
915
964
1014
1063
1112
1160
1208
1256
1303
1350
1396
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4253103153203253303
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1486
1536
1585
1634
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1536
1585
1634
168417351785183618871938198920402091214221932244229523462398244925012552260426553S-611PB1
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353403452502551600650699748797846896945994104310921141119012401289133813881437
1486
1536
1585
1634
1684173517861836188719381989204020912142219322452296234723982450250125532605265727103S-611A wp04
4253103153
203253303353403452502551601650700749798848898947
9971047
10961146
119612451295134513941444149415441593
1643169317421792184218921943199320432094214421952245229723482399245125023S-612
4252102152202252302352402452501550599
648
697
745
793
841
889
937
984
1031
1078
1125
1171
1217
1263
1307
3S-613
4256106156206256306356406455505554
603
652
700
748
796
843
890
937
983
1028
1074
1119
11643S-615
64
114164
214264314364414465515565615665715765816866916966101610651115
1165
1214
1263
1312
1361
1410
1458
1506
1555
3S-620
4356106156206256306356406457508559
610
660
710
7603S-625
50100150200250300350400449498547596645694743792840889937986103410831131118012281276132513731421147015181567161716661714176218101858190619532000
2048
2096
2143
2190
2237
2284
2330
23773S-610 wp05
5010015020025030035040045150255360465570675880986091296410151067111911711222127413261378
1431
1483
1535
15843S-624 wp06
50100150200250300350400450499549598648697747
796
846
895
944
994
1043
1092
1141
1190
1239
1288
13363S-714 wp02
50100150200250300350400450500550599648
697
745
792
838
883
927
970
1012
3S-718 wp03
50100150200250300350400450
500551601651701752802852902952100210521102115212021252130113513S-719 wp03
501001502002503003504004505015516026537037548048559059561006105711071157120812581308135814081458150815583S-721 wp03
50100150200250300350400450501551601651700
749
797
845
891
937
982
1026
1068
1110
11503S-722 wp03
50100150200250300350400450499549599649698748798847897947997
1047
1096
1146
1196
1246
1296
1346
1396
1447
1497
1547
1595
1644
1694
3143
3185
3224
3261
3296
3330
3361
3390
3417
3S-723 wp01
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
From To Tool
42.40 1803.40 SDI_URSA1_I4
1803.40 2773.40 MWD+IFR2+SAG+MS
2773.40 8313.40 MWD+IFR2+SAG+MS
8313.40 21267.26 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2565.70 2781.86 10-3/4" Surface Casing5142.70 8321.56 7-5/8" Intermediate Casing5148.52 21267.26 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 42.40 0.00 0.00 42.40 0.00 0.00 0.00 0.00 0.00
2 403.40 0.00 0.00 403.40 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 603.40 3.00 316.00 603.31 3.77 -3.64 1.50 316.00 4.93 Start Build 1.75
4 803.40 6.50 316.00 802.59 15.68 -15.14 1.75 0.00 20.52 Start Build 2.00
5 1529.22 21.02 316.00 1505.70 139.52 -134.73 2.00 0.00 182.59 Start 107.13 hold at 1525.82 MD
6 1636.34 21.02 316.00 1605.70 167.15 -161.42 0.00 0.00 218.75 Start Build 2.00
7 2781.86 43.93 316.00 2565.70 606.61 -585.80 2.00 0.00 793.87
8 2801.86 43.93 316.00 2580.10 616.59 -595.43 0.00 0.00 806.93
9 3580.20 63.23 312.91 3040.11 1051.57 -1041.75 2.50 -8.30 1387.00
10 7838.35 63.23 312.91 4958.02 3640.19 -3826.08 0.00 0.00 4891.77
11 9083.02 87.00 343.00 5282.46 4648.79 -4436.48 3.00 55.62 6062.17
12 9283.02 87.00 343.00 5292.93 4839.79 -4494.87 0.00 0.00 6260.28 3S-617 [Harriman] T1 072723
13 9303.02 87.00 343.00 5293.98 4858.89 -4500.71 0.00 0.00 6280.10
14 9886.12 91.59 346.60 5301.15 5421.31 -4653.53 1.00 38.11 6855.58
1510647.89 91.59 346.60 5280.00 6162.04 -4830.05 0.00 0.00 7603.37
1610704.27 91.45 346.05 5278.50 6216.81 -4843.37 1.00 -104.48 7658.76 3S-617 [Harriman] T2 072723
1710758.54 91.96 345.86 5276.89 6269.43 -4856.54 1.00 -20.19 7712.15
1812410.09 91.96 345.86 5220.42 7870.02 -5259.69 0.00 0.00 9336.89
1912456.08 91.50 345.84 5219.03 7914.60 -5270.93 1.00 -177.19 9382.14 3S-617 [Harriman] T3 061923
2012499.59 91.07 345.83 5218.06 7956.78 -5281.57 1.00 -178.11 9424.97
21 14447.23 91.07 345.83 5181.85 9844.80 -5758.42 0.00 0.0011342.01
2214483.75 90.70 345.83 5181.29 9880.19 -5767.35 1.00 179.3211377.95 3S-617 [Harriman] T3 072723
2314524.73 90.29 345.84 5180.94 9919.93 -5777.38 1.00 178.2111418.29
2418339.18 90.29 345.84 5161.61 13618.48 -6710.32 0.00 0.0015173.22
2518340.26 90.28 345.84 5161.60 13619.52 -6710.58 1.00 -164.7815174.28 3S-617 [Harriman] T4 072723
2618342.71 90.26 345.83 5161.59 13621.90 -6711.18 1.00 -167.8915176.69
27 21267.26 90.26 345.83 5148.52 16457.50 -7426.86 0.00 0.0018055.68 3S-617 [Harriman] T5 072723
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35404550
3S-18
35
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3S-19
35
40
45
50
3S-21
35404550
3S-22
35
40
45
50
3S-
2
3
35
40
45
5 0
3S-23
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35
40
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5 0
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2
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35
40
45
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35
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6
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Ea
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1
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35
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35
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3S-08C
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1
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3S-
0
9
35
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3
5
4
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4
5
5
0
3S-
1
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3
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4
0
4
5
5
0
3S-15
354 0455 0
3S-16
35
40
45
50
3S-17
35
40
45
5 0
3S-17
A
35
40
45
50
3S-
1
8
35
40
45
50
3S-19
3S-21
35
4 0
45
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3S-
2
2
35
3S-
2
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35
4 0
45
5 0
3S-23
A
3S-
2
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3S-
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A
3S-24
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35
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3S-
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35
40
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L
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1
35
40
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35
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8
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Northing (300 usft/in)
Ea
s
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(
3
0
0
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1 5
17
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2
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15
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19
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3S-
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17
19
21
23
25
27
29
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A
15
17
19
21
23
25
27
29
31
33
35
37
39
41
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3S-18
15
17
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23
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3S-21
1 5
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Ea
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400 600
600 900
900 1200
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1500 2000
2000 2500
2500 3000
3000 5000
5000 8000
8000 12000
12000 17000
17000 21276
3S-617 wp06 Plan Summary
0
3
Do
g
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S
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0 3000 6000 9000 12000 15000 18000 21000
Measured Depth
10-3/4" Surface Casing 7-5/8" Intermediate Casing
4-1/2" Production Liner
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
3961111161211261311361411460510559
609
3S-14
3960110160210260310360410459509559609659709759
809
859
909
3S-15
3960110160210
260310360410460510559609659708758807856905954
1002
1050 3S-16
3960110160210260310360410460510560610661711761812862
3S-17
3960110160210260310360410460510560610661711761812862
3960110160210260
310360410460511561611661712
762812
3S-18
3961111161211261311361410461511561612
3S-19
1096
1146
119512451295134513941444149415431593
16431692174217921842189219421992
3S-612
4256106156206256306356406455505
554
603
652
700
748
3S-615
39
64114164
214264314364414465515565615665
3S-620
50100150200250300350400449499549598648697747
3S-714 wp02
50100150200250300350400450500550599
648
697
745
792
838 3S-718 wp03
50100150200250300350400450
500551601651701752802
3S-719 wp03
50100150200250300350400450499549599648698748798847897947
997
1046
1096
1146
3S-723 wp01
2750
Tr
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D
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0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 335.71°
10-3/4" Surface Casing
7-5/8" Intermediate Casing
4-1/2" Production Liner
0
18
35
Ce
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C
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0 400 800 1200 1600 2000 2400 2800
Measured Depth
Equivalent Magnetic Distance
DDI
7.115
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.00 1800.00 3S-617 wp06 (3S-617) SDI_URSA1_I4
1800.00 2660.00 3S-617 wp06 (3S-617) MWD OWSG
1800.00 2660.00 3S-617 wp06 (3S-617) MWD+IFR2+SAG+MS
2660.00 3660.00 3S-617 wp06 (3S-617) MWD OWSG
2660.00 9270.00 3S-617 wp06 (3S-617) MWD+IFR2+SAG+MS
9270.00 10270.00 3S-617 wp06 (3S-617) MWD OWSG
9270.00 21276.32 3S-617 wp06 (3S-617) MWD+IFR2+SAG+MS
Ground / 27.70
CASING DETAILS
TVD MD Name
2565.70 2782.91 10-3/4" Surface Casing
5142.70 8239.15 7-5/8" Intermediate Casing
5148.52 21276.32 4-1/2" Production Liner
Mag Model & Date: BGGM2023 01-Nov-23
Magnetic North is 14.48° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.65° 57230.43nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 600.00 3.00 316.00 599.91 3.77 -3.64 1.50 316.00 4.93 Start Build 1.75
4 800.00 6.50 316.00 799.19 15.68 -15.14 1.75 0.00 20.52 Start Build 2.00
5 1529.46 21.09 316.00 1505.70 140.46 -135.64 2.00 0.00 183.82 Start 107.18 hold at 1529.46 MD
6 1636.64 21.09 316.00 1605.70 168.20 -162.43 0.00 0.00 220.12 Start Build 2.00
7 2664.59 41.65 316.00 2478.70 551.05 -532.14 2.00 0.00 721.17 Start 20.00 hold at 2664.59 MD
8 2684.59 41.65 316.00 2493.64 560.61 -541.38 0.00 0.00 733.68 Start DLS 2.50 TFO -8.06
9 3530.72 62.65 312.73 3010.03 1023.12 -1018.11 2.50 -8.06 1351.35 Start 4255.51 hold at 3530.72 MD
10 7786.23 62.65 312.73 4965.20 3588.10 -3794.35 0.00 0.00 4831.29 Start DLS 3.00 TFO 52.89
11 9092.58 89.00 343.00 5289.44 4647.99 -4436.66 3.00 52.89 6061.57 Start 200.00 hold at 9092.58 MD
12 9292.58 89.00 343.00 5292.93 4839.22 -4495.12 0.00 0.00 6259.92 3S-617 [Harriman] T1 072723 Start 20.00 hold at 9292.58 MD
13 9312.58 89.00 343.00 5293.28 4858.35 -4500.97 0.00 0.00 6279.76 Start DLS 1.00 TFO 60.79
14 9688.84 90.84 346.28 5293.81 5221.10 -4600.60 1.00 60.79 6651.38 Start 958.88 hold at 9688.84 MD
15 10647.72 90.84 346.28 5279.81 6152.54 -4827.94 0.00 0.00 7593.88 Start DLS 1.00 TFO -20.87
16 10713.33 91.45 346.05 5278.50 6216.24 -4843.63 1.00 -20.87 7658.39 3S-617 [Harriman] T2 072723 Start DLS 1.00 TFO -20.19
1710767.61 91.96 345.86 5276.89 6268.86 -4856.79 1.00 -20.19 7711.78 Start 1651.55 hold at 10767.61 MD
1812419.15 91.96 345.86 5220.42 7869.45 -5259.94 0.00 0.00 9336.51 Start DLS 1.00 TFO -177.19
19 12465.14 91.50 345.84 5219.03 7914.03 -5271.18 1.00 -177.19 9381.76 3S-617 [Harriman] T3 061923 Start DLS 1.00 TFO -178.11
2012508.66 91.07 345.83 5218.06 7956.21 -5281.82 1.00 -178.11 9424.59 Start 1947.64 hold at 12508.66 MD
21 14456.30 91.07 345.83 5181.85 9844.23 -5758.67 0.00 0.0011341.62 Start DLS 1.00 TFO 179.32
2214492.81 90.70 345.83 5181.29 9879.62 -5767.61 1.00 179.3211377.56 3S-617 [Harriman] T3 072723 Start DLS 1.00 TFO 178.21
2314533.79 90.29 345.84 5180.94 9919.36 -5777.63 1.00 178.2111417.91 Start 3814.45 hold at 14533.79 MD
2418348.25 90.29 345.84 5161.61 13617.91 -6710.57 0.00 0.0015172.82 Start DLS 1.00 TFO -164.77
2518349.32 90.28 345.84 5161.60 13618.95 -6710.83 1.00 -164.7715173.87 3S-617 [Harriman] T4 072723 Start DLS 1.00 TFO 90.19
2618351.77 90.26 345.83 5161.59 13621.33 -6711.43 1.00 -167.8915176.29
27 21276.32 90.26 345.83 5148.52 16456.93 -7427.11 0.00 0.0018055.26 3S-617 [Harriman] T5 072723
FORMATION TOP DETAILS
TVDPath Formation
1369.70 Top Ugnu C
1634.70 Top Ugnu B
1703.70 Base Permafrost
1745.70 Top Ugnu A
2025.70 Top West Sak
2444.70 Base West Sak
2615.70 C-80
3350.70 C-50
3947.70 C-35
4100.70 Top Coyote, K3
4453.70 Base Coyote
5162.70 Top Torok (Moraine)
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by Accepted by Approved by
Plan 27.7+39 @ 66.70usft (Doyon 142)
Superceded by updated directional plan
-2500
0
2500
5000
7500
Tr
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0 2500 5000 7500 10000 12500 15000 17500
Vertical Section at 335.71°
10-3/4" Surface Casing
7-5/8" Intermediate Casing
4-1/2" Production Liner
1 0 0 0
2 0 0 0
3 0 0 0
4000
5000
6000
7000
8000
9000
10000
110
0
0
1
20
0
0
1300
0
14
00
0
15000
16000
17000
18000
19000
20000
21000
21276
0°
3 0 °
60°
63°
89°
90°
91°
9
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91
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90°
90°
3S-617
wp06
Top Ugnu C
Base Permafrost
Top Ugnu B
Top Ugnu A
Top West Sak
Base West Sak
C-80 C-50
C-35 Top Coyote (Top Nanushuk), K3
Base Coyote (Base Nanushuk)
Top Torok (Moraine)
3S-617 wp06
14:49, September 13 2023Section View
Superceded by updated directional plan
0
3000
6000
9000
12000
15000
So
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(
-
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-15000 -12000 -9000 -6000 -3000 0 3000 6000
West(-)/East(+)
3S-617 [Harriman] T4 072723
3S-617 [Harriman] T1 072723
3S-617 [Harriman] T2 072723
3S-617 [Harriman] T5 072723
3S-617 [Harriman] T3 061923
3S-617 [Harriman] T3 072723
10-3/4" Surface Casing
7-5/8" Intermediate Casing
4-1/2" Production Liner
3 S -6 1 7 w p 0 6
3S-617 wp06
While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.
13:44, September 13 20233ODQ9LHZ
Superceded by updated directional plan
Superceded by updated directional plan
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Superceded by updated directional plan
Superceded by updated directional plan
Superceded by updated directional plan
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Superceded by updated directional plan
Superceded by updated directional plan
Superceded by updated directional plan
Superceded by updated directional plan
Superceded by updated directional plan
0
30
60
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
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0450900135018002250
Partial Measured Depth
3S-14
3S-15
3S-16
3S-17
3S-17A
3S-18
3S-19
3S-612
3S-615
3S-620
3S-714
wp02
3S-718
wp03
3S-719
wp03
3S-723
wp01
Equivalent Magnetic Distance
3S-617 wp06 Ladder View
0
150
300
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 3000 6000 9000 12000 15000 18000 21000
Measured Depth
NDST-02PB1
3S-03
3S-06
3S-06A
3S-07
3S-08
3S-08A
3S-08B
3S-08C
3S-08CL1
3S-08CL1PB1
3S-09
3S-10
3S-14
3S-15
3S-16
3S-17
3S-17A
3S-18
3S-19
3S-21
3S-22
3S-23
3S-23A
3S-24
3S-24A
3S-24B
3S-26
PALM
1
3S-611
3S-611PB1
3S-611A
wp04
3S-612
3S-613
3S-615
3S-620
3S-625
3S-701
3S-701A
3S-704
3S-602
wp04
3S-605
wp04
3S-606 wp05
3S-610 wp05
3S-624
wp06
3S-626
wp04
3S-714
wp02
3S-718
wp03
3S-719
wp03
3S-721
wp03
3S-722
wp03
3S-723
wp01
Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
39.00 1800.00 3S-617 wp06 (3S-617) SDI_URSA1_I4
1800.00 2660.00 3S-617 wp06 (3S-617) MWD OWSG
1800.00 2660.00 3S-617 wp06 (3S-617) MWD+IFR2+SAG+MS
2660.00 3660.00 3S-617 wp06 (3S-617) MWD OWSG
2660.00 9270.00 3S-617 wp06 (3S-617) MWD+IFR2+SAG+MS
9270.0010270.00 3S-617 wp06 (3S-617) MWD OWSG
9270.00 21276.32 3S-617 wp06 (3S-617) MWD+IFR2+SAG+MS
14:42, September 13 2023
CASING DETAILS
TVD MD Name
2565.70 2782.91 10-3/4" Surface Casing
5142.70 8239.15 7-5/8" Intermediate Casing
5148.52 21276.32 4-1/2" Production Liner
Superceded by updated directional plan
39 400
400 600
600 900
900 1200
1200 1500
1500 2000
2000 2500
2500 3000
3000 5000
5000 8000
8000 12000
12000 17000
17000 21276
3S-617 wp06 TC View
30
30
60
60
90
90
120
120
150
150
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
39
60110160210260310360410458
3S-08
39
60110160210260310360410458
39
60110160210260310360410458
39
61111161211261311361411
459
39
61111161211261311361411
459
39
61111161211261311361411
459
3960110160210260310360410458507
3S-09
39
60110160210260310360410459508557606655703
3S-10
3961111161211261311361411460510559609
658
708
757
806
856
905
954
1003
1052
1102
1151
3S-14
3960110160210260310360410459509559609659709759809
859
909
960
1010
1060
1110
1160
1210
1261
1311
1362
1413
1463
3S-15
3960110160210
26031036041046051055960965970875880785690595410021050
1098
1146
1193
1240
1287
1333
1379
1424
3S-16
39601101602102603103604104605105606106617117618128629139641015106511161167121812691320137114223S-17
3960110160210260310360410460510560610661711761812862913964101510651116116712181269132013711422
3960110160210260
310360410460511561611661712
762812862913963101410641114116512151266131613663S-18
3961111161211261311361410461511561612662713
7638138649149651015106511151165
3S-19
3960110160210260310359
409
459
508
557
606
655
702
750
796
842
3S-21
3960110160210260310360410460511562612663714764814865915966101610661116
1166
1216
1266
1315
1364
3S-22
39
61111
161211261311361411462513564615666717768819
3S-23
39
59109
159209259309359409460511561612663714765816
3961111161
211261310360410
461
511
561
3S-24
3961111161
211261310360410
461
511
561
3961111161
211261311361411
461
511
561
509560611662713763814864915
964
1014
1063
1112
1160
1208
1256
1303
1349
1395
1441
3S-26
509560611662713763814864
915
964
1014
1063
1112
1160
1208
1256
1303
1349
1395
PALM 1
4253103153203253303
353403452502551600649699748797846895944994104310921141119012391289133813871437
1486
1535
1585
1634
168417341785183618871938198920392090214221932244229523462398244925012552260426562708
3S-611
4253103153203253303
353403452502551600649699748797846895944994104310921141119012391289133813871437
1486
1535
1585
1634
16841734178518361887193819892039209021412192224422952346239724482500255126032654
3S-611PB1
53103153203253303
353403452502551600649699748797846895945994104310921141119012391289133813871437
1486
1535
1585
1634
168417351785183618871938198920402091214221932244229523462398244925012552260426562708
4253103153
203253303353403452502551601650699749798848898947
99710461096
1146
119512451295134513941444149415431593
164316921742179218421892194219922043209321442194224522962347239924502501
3S-612
4252102152202252302352402451501550599
648
696
745
793
841
889
936
984
1031
1078
1124
1171
1217
1262
1307
3S-613
4256106156206256306356406455505554
603
652
700
748
796
843
890
937
983
1028
1074
1118
3S-615
39
64114164
21426431436441446551556561566571576581586691696610161065
1115
1164
1214
1263
1312
1361
1409
1458
1506
1555
3S-620
4356106156206256306356406457508559
610
660
710
760
3S-625
3950100150200250300350400449498547596645694743792840889937986103410831131117912281276132513731421146915171567161716661714176218101857190519532000
2048
2095
2142
2189
2236
2283
2330
3S-610 wp05
39501001502002503003504004515025536046557067588098609129641015106711191171122212741326137814301483
1535
15843S-624 wp06
50100150200250300350400449499549598648697747
796
846
895
944
993
1043
1092
1141
1190
1239
1287
1336
3S-714 wp02
50100150200250300350400450500550599648
697
745
792
838
883
927
970
1012
3S-718 wp03
50100150200250300350400450
50055160165170175280285290295210021052110211521202125213011351
3S-719 wp03
50100150200250300350400450501551602653703754804855905956100610561107115712071258130813581408145815081557
3S-721 wp03
3950100150200250300350400450501551601651700
749
797
845
891
937
982
1025
1068
1110
1150
3S-722 wp03
501001502002503003504004504995495996486987487988478979479971046
1096
1146
1196
1246
1296
1346
1396
1446
1497
1547
1595
1644
1694
3142
3183
3222
3258
3293
3326
3357
3386
3413
3S-723 wp01
SURVEY PROGRAM
Date: 2021-02-19T00:00:00 Validated: Yes Version:
From To Tool
39.00 1800.00 SDI_URSA1_I4
1800.00 2660.00 MWD OWSG
1800.00 2660.00 MWD+IFR2+SAG+MS
2660.00 3660.00 MWD OWSG
2660.00 9270.00 MWD+IFR2+SAG+MS
9270.00 10270.00 MWD OWSG
9270.00 21276.32 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2565.70 2782.91 10-3/4" Surface Casing5142.70 8239.15 7-5/8" Intermediate Casing
5148.52 21276.32 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 600.00 3.00 316.00 599.91 3.77 -3.64 1.50 316.00 4.93 Start Build 1.75
4 800.00 6.50 316.00 799.19 15.68 -15.14 1.75 0.00 20.52 Start Build 2.00
5 1529.46 21.09 316.00 1505.70 140.46 -135.64 2.00 0.00 183.82 Start 107.18 hold at 1529.46 MD
6 1636.64 21.09 316.00 1605.70 168.20 -162.43 0.00 0.00 220.12 Start Build 2.00
7 2664.59 41.65 316.00 2478.70 551.05 -532.14 2.00 0.00 721.17 Start 20.00 hold at 2664.59 MD
8 2684.59 41.65 316.00 2493.64 560.61 -541.38 0.00 0.00 733.68 Start DLS 2.50 TFO -8.06
9 3530.72 62.65 312.73 3010.03 1023.12 -1018.11 2.50 -8.06 1351.35 Start 4255.51 hold at 3530.72 MD
10 7786.23 62.65 312.73 4965.20 3588.10 -3794.35 0.00 0.00 4831.29 Start DLS 3.00 TFO 52.89
11 9092.58 89.00 343.00 5289.44 4647.99 -4436.66 3.00 52.89 6061.57 Start 200.00 hold at 9092.58 MD
12 9292.58 89.00 343.00 5292.93 4839.22 -4495.12 0.00 0.00 6259.92 3S-617 [Harriman] T1 072723 Start 20.00 hold at 9292.58 MD
13 9312.58 89.00 343.00 5293.28 4858.35 -4500.97 0.00 0.00 6279.76 Start DLS 1.00 TFO 60.79
14 9688.84 90.84 346.28 5293.81 5221.10 -4600.60 1.00 60.79 6651.38 Start 958.88 hold at 9688.84 MD
15 10647.72 90.84 346.28 5279.81 6152.54 -4827.94 0.00 0.00 7593.88 Start DLS 1.00 TFO -20.87
16 10713.33 91.45 346.05 5278.50 6216.24 -4843.63 1.00 -20.87 7658.39 3S-617 [Harriman] T2 072723 Start DLS 1.00 TFO -20.19
1710767.61 91.96 345.86 5276.89 6268.86 -4856.79 1.00 -20.19 7711.78 Start 1651.55 hold at 10767.61 MD
1812419.15 91.96 345.86 5220.42 7869.45 -5259.94 0.00 0.00 9336.51 Start DLS 1.00 TFO -177.19
19 12465.14 91.50 345.84 5219.03 7914.03 -5271.18 1.00 -177.19 9381.76 3S-617 [Harriman] T3 061923 Start DLS 1.00 TFO -178.11
2012508.66 91.07 345.83 5218.06 7956.21 -5281.82 1.00 -178.11 9424.59 Start 1947.64 hold at 12508.66 MD
21 14456.30 91.07 345.83 5181.85 9844.23 -5758.67 0.00 0.0011341.62 Start DLS 1.00 TFO 179.32
2214492.81 90.70 345.83 5181.29 9879.62 -5767.61 1.00 179.3211377.56 3S-617 [Harriman] T3 072723 Start DLS 1.00 TFO 178.21
2314533.79 90.29 345.84 5180.94 9919.36 -5777.63 1.00 178.2111417.91 Start 3814.45 hold at 14533.79 MD
2418348.25 90.29 345.84 5161.61 13617.91 -6710.57 0.00 0.0015172.82 Start DLS 1.00 TFO -164.77
2518349.32 90.28 345.84 5161.60 13618.95 -6710.83 1.00 -164.7715173.87 3S-617 [Harriman] T4 072723 Start DLS 1.00 TFO 90.19
2618351.77 90.26 345.83 5161.59 13621.33 -6711.43 1.00 -167.8915176.29
27 21276.32 90.26 345.83 5148.52 16456.93 -7427.11 0.00 0.0018055.26 3S-617 [Harriman] T5 072723
Superceded by updated directional plan
3SͲ617wp06 ACFlipbook
SURVEY PROGRAM
Depth From Depth To Tool
39.00 1800.00 SDI_URSA1_I4
1800.00 2660.00 MWD OWSG
1800.00 2660.00 MWD+IFR2+SAG+MS
2660.00 3660.00 MWD OWSG
2660.00 9270.00 MWD+IFR2+SAG+MS
9270.00 10270.00 MWD OWSG
9270.00 21276.32 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2565.70 2782.91 10-3/4" Surface Casing
5142.70 8239.15 7-5/8" Intermediate Casing
5148.52 21276.32 4-1/2" Production Liner
10
10
20
20
30
30
40
40
50
50
60
60
70
70
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]
111161211261311
361
411
460
510
559
609
3S-14
110160210260
310
360
410
459
509
559
609
659
709
759
809
859
909
3S-15
110160210
260310360410460510559
609
659
708
758
807
856
905
954
1002
1050 3S-16
110160210
260
310
360
410
460
510
560
610
661
711
761
812
862
913
3S-17
110160210
260
310
360
410
460
510
560
610
661
711
761
812
862
913
110160210260
310360410460511561611661712
762812
3S-18
111
161211261311361411461511561612
3S-19
1096
1146
119512451295134513941444149415431593
16431692174217921842189219421992
3S-612
106156206256306
356
406
455
505
554
603
652
700
748
796
3S-615
114
164
214264314
364
414
465
515
565
615
665
3S-620
100150200250300350400449499
549
598
648
697
747
3S-714 wp02
100150200250300350400450500
550
599
648
697
745
792
838 3S-718 wp03
100150200250300350400450
500551601651701752802
3S-719 wp03
100150200250300350400450499549599648
698
748
798
847
897
947
997
1046
1096
1146
3S-723 wp01
39 400
400 600
600 900
900 1200
1200 1500
1500 2000
2000 2500
2500 3000
3000 5000
5000 8000
8000 12000
12000 17000
17000 21276
From Colour To MD
36.00To 2800.00
MD Azi TFace
39.00 0.00 0.00
400.00 0.00 0.00
600.00 316.00 316.00
800.00 316.00 0.00
1529.46 316.00 0.00
1636.64 316.00 0.00
2664.59 316.00 0.00
2684.59 316.00 0.00
3530.72 312.73 -8.06
7786.23 312.73 0.00
9092.58 343.00 52.89
9292.58 343.00 0.00
9312.58 343.00 0.00
9688.84 346.28 60.79
10647.72 346.28 0.00
10713.33 346.05 -20.87
10767.61 345.86 -20.19
12419.15 345.86 0.00
12465.14 345.84 -177.19
12508.66 345.83 -178.11
14456.30 345.83 0.00
14492.81 345.83 179.32
14533.79 345.84 178.21
18348.25 345.84 0.00
18349.32 345.84 -164.77
18351.77 345.83 -167.89
21276.32 345.83 0.00
Superceded by updated directional plan
3SͲ617wp06 ACFlipbook
SURVEY PROGRAM
Depth From Depth To Tool
39.00 1800.00 SDI_URSA1_I4
1800.00 2660.00 MWD OWSG
1800.00 2660.00 MWD+IFR2+SAG+MS
2660.00 3660.00 MWD OWSG
2660.00 9270.00 MWD+IFR2+SAG+MS
9270.00 10270.00 MWD OWSG
9270.00 21276.32 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2499.00 2782.91 10-3/4" Surface Casing
5076.00 8239.15 7-5/8" Intermediate Casing
5081.82 21276.32 4-1/2" Production Liner
10
10
20
20
30
30
40
40
50
50
60
60
70
70
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]
3961111161211261311
361
411
460
510
559
609
3S-14
3960110160210260
310
360
410
459
509
559
609
659
709
759
809
859
909
3S-15
3960110160210
260310360410460510559
609
659
708
758
807
856
905
954
1002
1050 3S-16
3960110160210
260
310
360
410
460
510
560
610
661
711
761
812
862
913
3S-17
3960110160210
260
310
360
410
460
510
560
610
661
711
761
812
862
913
3960110160210260
310360410460511561611661712
762812
3S-18
3961111161211261311361411461511561612
3S-19
1096
1146
119512451295134513941444149415431593
16431692174217921842189219421992
3S-612
4256106156206256306
356
406
455
505
554
603
652
700
748
796
3S-615
39
64114164
214264314
364
414
465
515
565
615
665
3S-620
50100150200250300350400449499
549
598
648
697
747
3S-714 wp02
50100150200250300350400450500
550
599
648
697
745
792
838 3S-718 wp03
50100150200250300350400450
500551601651701752802
3S-719 wp03
50100150200250300350400450499549599648
698
748
798
847
897
947
997
1046
1096
1146
3S-723 wp01
39 400
400 600
600 900
900 1200
1200 1500
1500 2000
2000 2500
2500 3000
3000 5000
5000 8000
8000 12000
12000 17000
17000 21276
From Colour To MD
39.00To 2800.00
MD Azi TFace
39.00 0.00 0.00
400.00 0.00 0.00
600.00 316.00 316.00
800.00 316.00 0.00
1529.46 316.00 0.00
1636.64 316.00 0.00
2664.59 316.00 0.00
2684.59 316.00 0.00
3530.72 312.73 -8.06
7786.23 312.73 0.00
9092.58 343.00 52.89
9292.58 343.00 0.00
9312.58 343.00 0.00
9688.84 346.28 60.79
10647.72 346.28 0.00
10713.33 346.05 -20.87
10767.61 345.86 -20.19
12419.15 345.86 0.00
12465.14 345.84 -177.19
12508.66 345.83 -178.11
14456.30 345.83 0.00
14492.81 345.83 179.32
14533.79 345.84 178.21
18348.25 345.84 0.00
18349.32 345.84 -164.77
18351.77 345.83 -167.89
21276.32 345.83 0.00
Superceded by updated directional plan
3SͲ617wp06 ACFlipbook
SURVEY PROGRAM
Depth From Depth To Tool
39.00 1800.00 SDI_URSA1_I4
1800.00 2660.00 MWD OWSG
1800.00 2660.00 MWD+IFR2+SAG+MS
2660.00 3660.00 MWD OWSG
2660.00 9270.00 MWD+IFR2+SAG+MS
9270.00 10270.00 MWD OWSG
9270.00 21276.32 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2565.70 2782.91 10-3/4" Surface Casing
5142.70 8239.15 7-5/8" Intermediate Casing
5148.52 21276.32 4-1/2" Production Liner
50
50
100
100
150
150
200
200
250
250
300
300
350
350
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in]
20658
20689
20719
20750
20780
20811
20842
20873
20904
20934
20965
NDST-02PB1
39 400
400 600
600 900
900 1200
1200 1500
1500 2000
2000 2500
2500 3000
3000 5000
5000 8000
8000 12000
12000 17000
17000 21276
From Colour To MD
8200.00To 21277.00
MD Azi TFace
39.00 0.00 0.00
400.00 0.00 0.00
600.00 316.00 316.00
800.00 316.00 0.00
1529.46 316.00 0.00
1636.64 316.00 0.00
2664.59 316.00 0.00
2684.59 316.00 0.00
3530.72 312.73 -8.06
7786.23 312.73 0.00
9092.58 343.00 52.89
9292.58 343.00 0.00
9312.58 343.00 0.00
9688.84 346.28 60.79
10647.72 346.28 0.00
10713.33 346.05 -20.87
10767.61 345.86 -20.19
12419.15 345.86 0.00
12465.14 345.84 -177.19
12508.66 345.83 -178.11
14456.30 345.83 0.00
14492.81 345.83 179.32
14533.79 345.84 178.21
18348.25 345.84 0.00
18349.32 345.84 -164.77
18351.77 345.83 -167.89
21276.32 345.83 0.00
Superceded by updated directional plan
3S-617 wp06 Spider Plot
15:14, September 13 2023
39.00 To 21276.32
No
r
t
h
i
n
g
(
5
5
0
0
u
s
f
t
/
i
n
)
Easting (5500 usft/in)
4648
5 0
5 2
NDST-02
46485052
NDS
T-02PB1
4
64
85
05
23S-03
4 6485052
3S-06
4 6485052
3S-06A
4
6
4
8
5
0
5
2
3S-07
46485052
3S-08
46485052
3S-08A 464850523S-08B
46485052
3S-08C
464850523S-08CL1
464850523S-08CL1PB1
4
6
4
8
5
0
52
3S-09
46485052
3S-10
4 64850523S-14464850523S-15
4
64
8
5
0
5
23S-16
464850523S-17
46
4
8
5
0
5
23S-17A
464850523S-18
46485052
3S-19
46485052
3S-21
4
64
85
05
23S-22
4
6
4
8
5
0
5
23S-23 4
64
8
5
0
5
2
3S-23A
4648
505
2
3S-24
4648
5052
3S-24A
4 6483S-24B
4
6
4
8
5
0
5
2
3S-26
46485052
PALM 1
46485052
3S-611
3S-611PB1
46485052
3S-611A wp04
46485052
3S-612
464850
5 2
3S-613
46485052
3S-615
46485052
3S-620
46
4850
5 2
3S-625
4 6483S-701
3S-701A
3S-704
46485052
3S-605 wp04
4 6485052
3S-606 wp05
46485052
3S-610 wp05
4 6485052
3S-624 wp06
46485052
3S-626 wp04
3S-714 wp02
3S-718 wp03
3S-719 wp03
3S-721 wp03
3S-722 wp03
3S-723 wp01
4 6485052
3S-617 wp06
Superceded by updated directional plan
3S-617 wp06 Spider Plot
15:08, September 13 2023
39.00 To 21276.32
No
r
t
h
i
n
g
(
1
5
0
0
u
s
f
t
/
i
n
)
Easting (1500 usft/in)
3S-03
3 6
3 8
4 0
4 2
4 4
4 6
48
50
5 2
3S-06
3 6
3 8
4 0
4 2
4 4
4 6
48
50
52
3S-06A
3
6
3
8
4
0
4
2
4
4
4
6
4
8
5
0
5
2
3S-07
3S-083638
4042
4446485052
3S-08A 363 8
4042
4446485052
3S-08B
3S-08C
3S-08CL1
3S-08CL1PB1
36
38
40
4
2
4
4
4
6
4
8
5
0
52
3S-09
36
38
40
42
44
46
48
50
52
3S-10
3 63840424446485052
3S-14
3 638404244464850523S-15
3
63
84
04
24
44
6
4
8
5
05
23S-16
363840424446485052
3S-17
363840424446
4
85
05
2
3S-17A
3638404244464850523S-18
36
3840
424446485052
3S-19
3S-21
3
63
84
04
24
44
64
85
05
23S-22
3S-233
63
84
04
24
4
3S-23A
3S-24
3S-24A
3S-24B
3
6
3
8
4
0
4
2
4
4
4
6
4
8
5
0
5
2
3S-26
363840424446485052PALM 1
36
38
40
42
44
46
48
5 0
5 2
3S-611
3S-611PB1
36
38
40
42
44
46
48
50
3S-611A wp04
36
38
40
42
44
463S-612
36384042444648
5 0
5 2
3S-613
363840424446
3S-615
3638404244464850
5 2
3S-620
36
3840
42
44
46
3S-625
3
6
3
8
40424446483S-701
3S-701A
3S-704
36
38
40
42
44
46
48
5 0
5 2
3S-605 wp04
3 6384042444648
50
5 2
3S-606 wp05
36
38
40
42
44
46
48
50
5 2
3S-610 wp05
3 638404244464850
5 2
3S
-624 wp06
36
38
40
42
44
46
4850
5 2
3S-626 wp04
3
6
38
40
4 2
3S-714 wp02
3S-718 wp03
3
6
3840
3S-719 wp03
3S-721 wp03
3
6
3
8
40
42
3S-722 wp03
3638
40
42
3S-723 wp01
36
3 8
4 0
4 2
44
46
4 85052
3S-617 wp06
Superceded by updated directional plan
3S-617 wp06 Spider Plot
15:14, September 13 2023
39.00 To 21276.32
No
r
t
h
i
n
g
(
6
0
0
u
s
f
t
/
i
n
)
Easting (600 usft/in)
3S-03
3 0
3 2
3 4
3 6
3 8
4 0
4 2
3S-06
3 0
3 2
3 4
3 6
3 8
4 0
4 2
3S-06A
3
0
3
2
3
4
3
6
3
8
4
0
3S-07
3S-08
3S-08A
3S-08B
3S-08C
3S-08CL1
3S-08CL1PB1
3S-09
30
32
34
36
38
3S-10
3 0
3 2
3 4
3 6
3 8
4 0
4 2
4 4
4 6
4 8
5 0
5 2
3S-14
3 0
3 2
3 4
3 6
3 8
4 0
4 2
3S
-15
3 032
3
43
63
84
04
24
44
6
4
85
05
2
3S-16
30
32
34
36
38
40
42
44
46
48
503S-17
30
32
34
36
38
40
42
4446
4
8
5
03S-17A
3032343638404244464850523S-18
30323436
38
3S-19
3S-21
3
03
23
43
63
84
04
24
44
64
85
03S-22
3S-23
3S-23A
3S-24
3S-24A
3S-24B
3
0
3
2
3
4
3
6
3
8
4
0
4
2
3S-26
30
32
34363840424446485052PALM 1
30
32
34
36
3S-611
3S-611PB1
30
32
34
36
38
3S-611A wp04
30
32
34
36
3S-612
30
32343638
3S-613
3234
3S-615
303234363840
3S-620
3S-625
3S-701
3S-701A
3S-704
30
32
34
36
38
40
42
3S-605 wp04
3 0
3 2
3 4
3 6
3 8
4 0
4 2
4 4
4 6 3S-606 wp05
30
32
34
36
38
40
42
44
46
3S-610 wp05
3 0
3 2
3 4
3 6
3 8
4 0
4 2
4 4
4 6
4 8
3S
-624 wp06
30
32
34
36
38
40
3S-626 wp04
30
3
2
3
4
3
6
38
40
4 2
3S-714 wp02
3S-718 wp03
3
0
3S-719 wp03
3S-721 wp03 3S-722 wp03
3
03
2
34
36
38
40
42
3S-723 wp01
3 0
3 2
3 4
3 6
38
40
42
44
46
48
3S-617 wp06
Superceded by updated directional plan
3S-617 wp06 Spider Plot
15:16, September 13 2023
39.00 To 21276.32
No
r
t
h
i
n
g
(
1
0
0
u
s
f
t
/
i
n
)
Easting (100 usft/in)
1
43S-03
1 4
16
1 8
20
3S-06
1 4
16
1 8
20
24
3S-0824
3S-08A
24
3S-08B24
3S-08C
24
3S-08CL124
3S-08CL1PB1
2
4
6
3S-09
2
4
6
8
3S-10
24
6
8
1 0
1 2
1 4
1 6
3S-14
2
4
6
8
1 0
1 2
1 4
1 6
3S-15
2 4681 01214
161820222426
2 8
3 0
32
3
4
3
6
3
8
4
0
42
44
4
6
3S-16
2
4
6
8
10
12
14
16
18
3S-17
2
4
6
8
10
12
14
16
18
2
46
8
10
12
14
16
18
20
3S-18
246
8
10121416
183S-19
2
4
6
8
3S-21
24
6
8
1012
1
41
61
82
0
3S-22
2
4
6
8
10
1
2
1
4
1
6
3S-23
2
4
6
8
10
1
2
1
4
1
6
2
4
6
8
3S-24
2
4
6
8
3S-24A
2
4
6
8
3S-24B
2468101214
16
182022242628
3
0
3
2
3
4
3S-26
2468101214
16
1820222426
2
8
30
32
34363840PALM 1
2
46
8
1 0
12
1 4
1 6
1 8
2 0
3S-611
2
46
8
1 0
12
1 4
1 6
1 8
2 0
3S-611PB1
2
46
8
1 0
12
1 4
1 6
1 8
2 03S-611A wp04
246
8
10
12
14
16
18
20
22
3S-612
24
6
8
1
0
1
2
1
4
1
6
1
83S-613
24
6
8
1
0
1
2
1
4
3S-615
2 4
6
810121416
18
20
22
3S-620
24
6
8
10
12
3S-625
1
2
1
4
1
6
1
8
2
0
2
2
3S-701
1
2
1
4
1
6
1
8
2
0
2
2
3S-701A
1
0
1
2
1
4
1
6
3S-704
1 2
1 4
1 6
1 8
2 0
3S-606 wp05
2468
10
12
14
16
18
20
22
24
26
3S-610 wp05
246
8
1 0
1 2
1 4
1 6
1 8
3S-624 wp06
2
468101214
16
18
20
3S-626 wp04
0246
8
1 0
1 2
1 4
1 6
3S-714 wp02
024 6
8
10
12
3S-718 wp03
02
468
1012
14
16
18
20
3S-719 wp03
024
68
10
12
14
16
18
20
22
3S-721 wp03
24 6
8
10
12
14
3S-722 wp03
0246
8
1 0
1 2
14
16
1 8
3S-723 wp01
2468
1 0
1 2
1 4
1 6
1 8
2 0
2 2
3S
-617 wp06
Superceded by updated directional plan
Superceded by updated directional plan
0.1!/< =
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Superceded by updated directional plan
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Superceded by updated directional plan
Superceded by updated directional plan
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Superceded by updated directional plan
3S-617 wp06
NDST-02PB1
3S-06
3S-15
3S-17
3S-611
3S-611A wp04
3S-612
3S-613
3S-615
3S-620
3S-625
3S-605 wp04
3S-606 wp05
3S-610 wp05
3S-624 wp06
3S-626 wp04
3S-718 wp03
3S-719 wp03
3S-721 wp03
3-D View3S-617 wp06 15:24, September 13 2023
Superceded by updated directional plan
3S-617 wp06NDST-02PB1
3S-03
3S-063S-06A
3S-14 3S-15
3S-17
3S-17A
3S-18
3S-193S-22
PALM 1
3S-611
3S-611A wp04
3S-612
3S-613
3S-615
3S-620
3S-625
3S-605 wp04
3S-606 wp05
3S-610 wp05
3S-624 wp06
3S-626 wp04
3S-719 wp03
3S-721 wp03
3-D View3S-617 wp06 15:24, September 13 2023
Superceded by updated directional plan
5000
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5100515052005250
NDST-02PB1
5 1 0 0515052005250
3 S -0 6
5100515052005250
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5100
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3S-17
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3 S -6 2 4 w p 0 6
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3 S -6 2 6 w p 0 4
3 S -7 1 8 w p 0 3
3S-719 w p 0 3
3S -721 w p 0 3
3 S -7 2 2 w p 0 3
5 1 0 0515052005250
3 S -6 1 7 w p 0 6
3S-617 wp06
Quarter Mile View
15:29, September 13 2023 WELLBORE TARGET DETAILS (MAP CO-ORDINATES)
Name TVD Shape
3S-617 [Harriman] T1 072723 5292.93 Circle (Radius: 100.00)
3S-617 [Harriman] T2 072723 5278.50 Circle (Radius: 100.00)
3S-617 [Harriman] T3 061923 5219.03 Circle (Radius: 100.00)
3S-617 [Harriman] T3 072723 5181.29 Circle (Radius: 100.00)
3S-617 [Harriman] T4 072723 5161.60 Circle (Radius: 100.00)
3S-617 [Harriman] T5 072723 5148.52 Circle (Radius: 100.00)
3S-617 T01 QM 5292.93 Circle (Radius: 1320.00)
3S-617 T03 QM 5181.29 Circle (Radius: 1320.00)
3S-617 T05 QM 5148.52 Circle (Radius: 1320.00)
Superceded by updated directional plan
5000
7500
10000
12500
15000
17500
So
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(
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NDST-02PB1
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5 2 5 0
3 S -6 1 0 w p 0 5
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3S -62 4 w p 06
5 1 0 0515052005250
3 S -6 1 7 w p 0 6
3S-617 wp06
Quarter Mile View
15:30, September 13 2023 WELLBORE TARGET DETAILS (MAP CO-ORDINATES)
Name TVD Shape
3S-617 [Harriman] T1 072723 5292.93 Circle (Radius: 100.00)
3S-617 [Harriman] T2 072723 5278.50 Circle (Radius: 100.00)
3S-617 [Harriman] T3 061923 5219.03 Circle (Radius: 100.00)
3S-617 [Harriman] T3 072723 5181.29 Circle (Radius: 100.00)
3S-617 [Harriman] T4 072723 5161.60 Circle (Radius: 100.00)
3S-617 [Harriman] T5 072723 5148.52 Circle (Radius: 100.00)
3S-617 T01 QM 5292.93 Circle (Radius: 1320.00)
3S-617 T03 QM 5181.29 Circle (Radius: 1320.00)
3S-617 T05 QM 5148.52 Circle (Radius: 1320.00)
Superceded by updated directional plan
3S-617wp06 Surface Location
3S-617wp06 Surface Location
#SchlumbergerͲConfidential
Superceded by updated directional plan
3S-617wp06 Surface Casing
3S-617wp06 Surface Casing
#SchlumbergerͲConfidential
Superceded by updated directional plan
3S-617wp06 Intermediate 1 Csg
3S-617wp06 Intermediate 1 Csg
#SchlumbergerͲConfidential
Superceded by updated directional plan
3S-617wp06 Top Torok (Moraine)
3S-617wp06 Top Torok (Moraine)
#SchlumbergerͲConfidential
Superceded by updated directional plan
3S-617wp06 TD
3S-617wp06 TD
#SchlumbergerͲConfidential
Superceded by updated directional plan
Superceded by updated survey
Superceded by updated survey
Certificate Of Completion
Envelope Id: D20F3283919246E782013A57661E6C86 Status: Completed
Subject: Complete with DocuSign: 3S-617 Updated PTD Submission.pdf
Source Envelope:
Document Pages: 53 Signatures: 2 Envelope Originator:
Certificate Pages: 5 Initials: 0 Matt Smith
AutoNav: Enabled
EnvelopeId Stamping: Disabled
Time Zone: (UTC-06:00) Central Time (US & Canada)
600 N Dairy Ashford Rd
Houston, TX 77079-1100
Matt.Smith2@conocophillips.com
IP Address: 138.32.8.5
Record Tracking
Status: Original
10/4/2023 6:05:59 PM
Holder: Matt Smith
Matt.Smith2@conocophillips.com
Location: DocuSign
Signer Events Signature Timestamp
Chris Brillon
chris.l.brillon@cop.com
Security Level: Email, Account Authentication
(None)
Signature Adoption: Uploaded Signature Image
Using IP Address: 138.32.8.5
Sent: 10/4/2023 6:10:02 PM
Viewed: 10/5/2023 2:02:22 PM
Signed: 10/5/2023 5:49:38 PM
Electronic Record and Signature Disclosure:
Accepted: 10/5/2023 2:02:22 PM
ID: 59e4001b-15b8-43a6-8f62-29ab01c0f365
Matt Smith
matt.smith2@conocophillips.com
ConocoPhillips
Security Level: Email, Account Authentication
(None)Signature Adoption: Drawn on Device
Using IP Address: 138.32.8.5
Sent: 10/4/2023 6:10:01 PM
Viewed: 10/4/2023 6:10:13 PM
Signed: 10/4/2023 6:10:20 PM
Electronic Record and Signature Disclosure:
Accepted: 7/19/2021 1:20:17 PM
ID: f6bd13a1-d6f1-46e0-9474-5f45090fce43
In Person Signer Events Signature Timestamp
Editor Delivery Events Status Timestamp
Agent Delivery Events Status Timestamp
Intermediary Delivery Events Status Timestamp
Certified Delivery Events Status Timestamp
Carbon Copy Events Status Timestamp
Witness Events Signature Timestamp
Notary Events Signature Timestamp
Envelope Summary Events Status Timestamps
Envelope Sent Hashed/Encrypted 10/4/2023 6:10:02 PM
Certified Delivered Security Checked 10/4/2023 6:10:13 PM
Envelope Summary Events Status Timestamps
Signing Complete Security Checked 10/4/2023 6:10:20 PM
Completed Security Checked 10/5/2023 5:49:38 PM
Payment Events Status Timestamps
Electronic Record and Signature Disclosure
Certificate Of Completion
Envelope Id: 99C0B9CC6F8D46CA8FE46E57077AAA78 Status: Completed
Subject: Complete with DocuSign: 3S-617 APD.pdf
Source Envelope:
Document Pages: 62 Signatures: 2 Envelope Originator:
Certificate Pages: 5 Initials: 0 Shane McCracken
AutoNav: Enabled
EnvelopeId Stamping: Disabled
Time Zone: (UTC-06:00) Central Time (US & Canada)
600 N Dairy Ashford Rd
Houston, TX 77079-1100
Shane.M.McCracken@conocophillips.com
IP Address: 138.32.8.5
Record Tracking
Status: Original
9/15/2023 12:47:39 PM
Holder: Shane McCracken
Shane.M.McCracken@conocophillips.com
Location: DocuSign
Signer Events Signature Timestamp
Mike Redburn
mike.redburn@conocophillips.com
X
Security Level: Email, Account Authentication
(None)Signature Adoption: Drawn on Device
Using IP Address: 24.237.215.105
Sent: 9/15/2023 12:51:04 PM
Viewed: 9/15/2023 1:04:59 PM
Signed: 9/15/2023 1:05:35 PM
Electronic Record and Signature Disclosure:
Accepted: 9/15/2023 1:04:59 PM
ID: 73b97e7f-1b6b-4a5c-9051-bdc91c5cdc4e
Shane McCracken
shane.m.mccracken@conocophillips.com
ConocoPhillips
Security Level: Email, Account Authentication
(None)Signature Adoption: Drawn on Device
Using IP Address: 138.32.8.5
Sent: 9/15/2023 12:51:04 PM
Viewed: 9/15/2023 12:51:15 PM
Signed: 9/15/2023 12:51:22 PM
Electronic Record and Signature Disclosure:
Accepted: 2/3/2022 4:20:37 PM
ID: 82d298e5-30b6-45b0-a6de-77aca64ab885
In Person Signer Events Signature Timestamp
Editor Delivery Events Status Timestamp
Agent Delivery Events Status Timestamp
Intermediary Delivery Events Status Timestamp
Certified Delivery Events Status Timestamp
Carbon Copy Events Status Timestamp
Chris Brillon
chris.l.brillon@conocophillips.com
Wells Engineering Manager
Security Level: Email, Account Authentication
(None)
Sent: 9/15/2023 12:51:05 PM
Electronic Record and Signature Disclosure:
Accepted: 9/7/2023 6:36:46 PM
ID: 79b286ca-fa56-45bb-8afe-12951a2fcc40
Carbon Copy Events Status Timestamp
Matt Smith
Matt.Smith2@conocophillips.com
ConocoPhillips
Security Level: Email, Account Authentication
(None)
Sent: 9/15/2023 12:51:05 PM
Viewed: 9/15/2023 12:53:35 PM
Electronic Record and Signature Disclosure:
Accepted: 7/19/2021 1:20:17 PM
ID: f6bd13a1-d6f1-46e0-9474-5f45090fce43
Witness Events Signature Timestamp
Notary Events Signature Timestamp
Envelope Summary Events Status Timestamps
Envelope Sent Hashed/Encrypted 9/15/2023 12:51:05 PM
Certified Delivered Security Checked 9/15/2023 12:51:15 PM
Signing Complete Security Checked 9/15/2023 12:51:22 PM
Completed Security Checked 9/15/2023 1:05:35 PM
Payment Events Status Timestamps
Electronic Record and Signature Disclosure
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Unless you tell us otherwise in accordance with the procedures described herein, we will provide
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exclusively through electronic means all notices, disclosures, authorizations,
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1
Dewhurst, Andrew D (OGC)
From:Smith, Matt <Matt.Smith2@conocophillips.com>
Sent:Tuesday, October 10, 2023 06:45
To:Dewhurst, Andrew D (OGC); Warren, Abby; McCracken, Shane M
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC); Roby, David S (OGC)
Subject:RE: [EXTERNAL]RE: KRU 3S-617 (PTD 223-085) - Questions
HiAndrew,
PleaseseethecurrentschemaƟcoftheNDSTͲ02andNDSTͲ02PB1.ThewelliscurrentlyshutinawaiƟngaspring2024
RWOtopulltubinginpreparaƟonforabandonment.Withourupcoming3Tdevelopment,theplanistoabandonthe
NDSTͲ02/PB1duetoitsproximitytoplannednewwells,notduetoitsmechanicalissues.
IfyouhaveanyotherquesƟonspleaseletmeknow.
Thanks,
Matt Smith
Drilling Engineer – Kuparuk
700 G ST ANCHORAGE ALASKA, ATO-1566
OFFICE: +1.907.263.4324
You don't often get email from matt.smith2@conocophillips.com. Learn why this is important
2
CELL: +1.432.269.6432
MATT.SMITH2@COP.COM
From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Sent:Monday,October9,20233:23PM
To:Smith,Matt<Matt.Smith2@conocophillips.com>;Warren,Abby<Abby.Warren@conocophillips.com>;McCracken,
ShaneM<Shane.M.McCracken@conocophillips.com>
Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,
VictoriaT(OGC)<victoria.loepp@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>
Subject:[EXTERNAL]RE:KRU3SͲ617(PTD223Ͳ085)ͲQuestions
MaƩ,
IseeintheupdateddocumentaƟonthattheNDSTͲ02(and02PB1)wellwasidenƟĮedinthequarterͲmileareaofreview.
WouldyoupleaseprovideasummaryofthemechanicalcondiƟonforthosewells?
Thanks,
Andy
From:Smith,Matt<Matt.Smith2@conocophillips.com>
Sent:Tuesday,September26,202315:06
To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>;Warren,Abby<Abby.Warren@conocophillips.com>;
McCracken,ShaneM<Shane.M.McCracken@conocophillips.com>
Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,
VictoriaT(OGC)<victoria.loepp@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>
Subject:RE:[EXTERNAL]KRU3SͲ617(PTD223Ͳ085)ͲQuestions
HeyAndrew,IgotbackfromvacaƟontoday.We’recurrentlydrivingourconductoraswespeak,soonceIhavetheĮnal
AsBuiltforthatsurfaceholelocaƟon,I’llbereͲsubmiƫngthedirecƟonaland10Ͳ401,asdiscussed.
Pleaseseebelow.
LetmeknowifyouhaveanyfurtherquesƟons.Thanks,
Matt Smith
Drilling Engineer – Kuparuk
700 G ST ANCHORAGE ALASKA, ATO-1566
OFFICE: +1.907.263.4324
CELL: +1.432.269.6432
MATT.SMITH2@COP.COM
From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Sent:Monday,September25,202310:22AM
To:Smith,Matt<Matt.Smith2@conocophillips.com>;Warren,Abby<Abby.Warren@conocophillips.com>;McCracken,
ShaneM<Shane.M.McCracken@conocophillips.com>
You don't often get email from matt.smith2@conocophillips.com. Learn why this is important
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
3
Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,
VictoriaT(OGC)<victoria.loepp@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>
Subject:[EXTERNAL]KRU3SͲ617(PTD223Ͳ085)ͲQuestions
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
ShaneandAbby,
IunderstandthatMaƩisoutoftheoĸce.IamcompleƟngmyreviewoftheKRU3SͲ617andhaveafewquesƟonsand
clariĮcaƟons:
x WouldyoupleaseconĮrmthattheNAD27StatePlanecoordinateswereswappedonthe10Ͳ401pageand
SecƟon2LocaƟonSummary(asshowncorrectedbelow):
correct–thesewillbeupdatedwithAsBuilt
coordinatesonnew10Ͳ401.
x IunderstandthatthereissƟllsomeuncertaintyonthesurfacelocaƟonforthiswell.Whichslotonthe6Spad
areyoucurrentlyplanningtouse?Slot17,justslidtotheEast~5feet.Similarto3SͲ615,whichwasaslot
recoveryof3SͲ15,andmoved~5’eastaswellfromtheoriginalwellbore.
x ThereisnomenƟonofH2SintheapplicaƟon.WouldyouconĮrmtherecordingof100+ppmofH2Sat3SͲ615,3SͲ
625,and3SͲ704in2023?
ConĮrmedwithourproducƟonengineer
615Ͳ160ppmon3/10/23
625–200ppmon01/01/23
704–100ppmon05/13/23
x DoyouplanonpreͲproducingthiswellbeforeinjecƟon?Yes,for~10days
x PleaseconĮrmthefollowingMD/TVDdiscrepancyatbaseof7Ͳ5/8”casing:
4
correct–willbeupdatedaswellwithnewdirecƟonalplan
x WouldyoupleaseconĮrmtheMASPvalues.It’snotclearthenumbersonthe10Ͳ401pagealignwiththosein
SecƟon6(MASPCalculaƟons).ConĮrmedandmatchnow,2302psiporepressure,1788psiASP.
x Regardingtherequestforvarianceonthediverter,wouldyouconĮrmthatthe3SͲ611wellalsofallsinsidethe
500’radiusoftheplannedsurfaceshoelocaƟon.Andifso,wouldyoupleaseprovideabriefsummaryofany
shallowgasorhashydratesecountered?
IconĮrmedand3SͲ611doesfallwithinthe500’boundary.ReadingthroughtheWellviewdailyreports,Iseeno
menƟonofhydratesorgasreadings.WehadsigniĮcanttroublesrunningsurfacecasingonthatwell,butno
issueofhydratesthatIsee.
Thanks,
Andy
AndrewDewhurst
SeniorPetroleumGeologist
AlaskaOilandGasConservaƟonCommission
333W.7thAve,Anchorage,AK99501
andrew.dewhurst@alaska.gov
Direct:(907)793Ͳ1254
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
X
KUPARUK RIVER
223-085
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c
t
i
o
n
.
36
Da
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
Se
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
Se
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
Co
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
10
/
1
0
/
2
0
2
3
Ap
p
r
VT
L
Da
t
e
10
/
1
6
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
9/
2
2
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
*&
:
JL
C
1
0
/
1
7
/
2
0
2
3
