Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout214-0611. 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: Temp plug & N2
Development Exploratory
3. Address: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 10,547 feet 10,045 feet
true vertical 9,969 feet N/A feet
Effective Depth measured 10,045 feet 5,607 feet
true vertical 9,467 feet 5,255 feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A
5,607 MD
Packers and SSSV (type, measured and true vertical depth)5" Swell Pkr 5,255 TVD SSSV: NA
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
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:Contact Name:
Contact Email:
Authorized Title:Contact Phone:
5,340psi
10,500psi
5,210psi
9,470psi
9,910psi
1,511'1,467'
Burst Collapse
2,480psi
Production
Liner
6,108'
10,547'
Casing
Structural
5,718'
9,969'
6,108'
10,547'
130'Conductor
Surface
Intermediate
16"
10-3/4"
130'
1,511'
measured
TVD
7-5/8"
5"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
214-061
50-133-20630-00-00
3800 Centerpoint Drive, Suite 1400
Anchorage, Alaska 99503
Hilcorp Alaska, LLC
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
Hilcorp Fee (Formerly A028142)
Kenai / Beluga-Up Tyonek Gas & Tyk Gas #1
Kenai Beluga Unit (KBU) 23-05
Plugs
Junk measured
Length
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)
0
Gas-Mcf
MD
0
Size
130'
6 0754
0 354
30
Chad Helgeson, Operations Engineer
323-458
Sr Pet Eng:Sr Pet Geo:Sr Res Eng:
WINJ WAG
944
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Noel Nocas, Operations Manager 907-564-5278
chelgeson@hilcorp.com
907-777-8405
N/A
p
k
ft
t
Fra
O
s
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 8:20 am, Mar 13, 2024
Digitally signed by Noel
Nocas (4361)
DN: cn=Noel Nocas (4361)
Date: 2024.03.12 18:24:58 -
08'00'
Noel Nocas
(4361)
DSR-3/14/24
RBDMS JSB 031424
Rig Start Date End Date
9/8/23 2/16/24
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
KBU 23-05 50-133-20630-00-00 214-061
Daily Operations:
Travel to KGF office. AK E-Line PJSM & permit. Travel to location. Night Pad Ops had well pressured up overnight against
WRP to 2000 PSI. Rig back on to well. PT 250 / 4000 PSI. Test good. RIH w/ gun ONE 3-3/8 x 14 to shoot D-1 Tyonek
sands at 9492 to 9506. CCL to TS = 2.6 / CCL to be at 9489.4 to place TS at 9492. Position Gun ONE. Fire Gun ONE. POOH.
No change in PSI from 2000 in 15 minutes. OOH. Lay down Gun ONE. P/U Gun TWO. RIH w/ gun TWO 3-3/8 x29 to shoot
D-1 Tyonek sands at 9463' to 9492'. CCL to TS = 4.3 / CCL to be at 9458.7 to place TS at 9463. Position Gun TWO. Fire Gun
TWO. POOH. No change in PSI from 2050 in 15 minutes. (Production installed Krystal gauge for monitoring. Current PSI
2082.). OOH. Lay down Gun TWO. P/U Gun THREE. RIH w/ gun THREE 3-3/8 x29 to shoot D-1 Tyonek sands at 9434' to
9463'. CCL to TS = 4.3 / CCL to be at 9429.7 to place TS at 9434'. Position Gun THREE. Fire Gun THREE. POOH. By Krystal
gauge Start PSI 2074 / 5 Min 2076 / 10 Min 2075 / 15 Min 2073. OOH. Lay down Gun THREE. P/U Gun FOUR. RIH w/ gun
FOUR 3-3/8 x29 to shoot D-1 Tyonek sands at 9375' to 9404'. CCL to TS = 4.3 / CCL to be at 9370.7' to place TS at 9375'.
Position Gun FOUR. Fire Gun FOUR. POOH. By Krystal gauge Start PSI 2058 / 5 Min 2059 / 10 Min 2057 / 15 Min 2055.
OOH. Lay down Gun FOUR. P/U Gun FIVE. RIH w/ gun FIVE 3-3/8 x 13 to shoot D-1 Tyonek sands at 9362' to 9375'. CCL to
TS = 4.3 / CCL to be at 9357.7' to place TS at 9362'. Position Gun FIVE. Fire Gun FIVE. POOH. PSI start: 2028 / 5 Min 2022 /
10 Min 2023/ 15 Min 2019. OOH. RDMO AK E-Line. Turn well over to production.
All perf guns are 3-3/8 OD Geo Charges. 22.7 gram. 6 shots per foot.
09/08/2023- Friday
Travel from KBU 43-07Y to KBU 23-05. MIRU AK E-Line. Attempt PT but triplex is down. Pad Op delivered replacement.
PT surface equipment 250 / 4000 PSI. Test good. RIH w/ GPT. Target depth for WRP set is 9522'. Ran GPT to 9580'. No
fluid detected. POOH. Lay down GPT. P/U 4.14" OD WRP. RIH w/ 4.14" OD WRP. Made correlation pass. Sent log to town.
Town approved. Position WRP. Target depth 9522'. CCL to top of WRP 12.3' / CCL to be at 9509.7' to place WRP at 9522'.
Fired setting tool. Good weight drop. Pick up 20'. Go back down & tag WRP at 9522'. POOH. Rig down AK E-Line to side.
MIRU PW Slickline. RIH w/ Catcher Sub (3.75" OD x 5.22' OAL) on 4-1/2" GS running tool. Set catcher sub on top of WRP
at 9528' SLM. POOH. RDMO PW Slickline. Night Pad Ops to apply 2000 PSI gas on top of WRP / Catcher Sub tonight.
Plan forward: Begin perforating in morning.
09/09/2023 - Saturday
Rig Start Date End Date
9/8/23 2/16/24
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
KBU 23-05 50-133-20630-00-00 214-061
Daily Operations:
09/10/2023 - Sunday
ARRIVE KGF MEET WITH PRODUCTION & REVIEW PERMIT
ARRIVE ON LOCATION SPOT IN & RIG UP
PRESSURE TEST LUBRICATOR 2000 PSI- FAILED, CHANGE OUT O RINGS RETEST TO 2000 PSI- PASS
RUN IN HOLE WITH 3.75" LIB TO 9420' SLM TAG FLUID, CONTINUE TO 9520' NO SPANG ACTION
PULL OUT OF HOLE TO INSPECT LIB (FISHING NECK & PERF DEBRIS ON LIB)
RUN IN HOLE WITH 3" STEM WITH KNUCKLE JOINT 2.5" X 7' PUMP BAILER TO 9530' NO SPANG ACTION. PULL OUT OF
HOLE (PERF GUN DEBRIS)
RUN IN HOLE WITH 4-1/2" GR TO 9530' SLM LATCH WITH TOOL FREE
PULL OUT OF HOLE WITH CATCHER ( MUD & PERF DEBRIS IN CATCHER)
RUN IN HOLE WITH 3.875" LIB TO 9531' HIT ONCE
PULL OUT OF HOLE TO INSPECT (SAND & MUD ON BLOCK)
RUN IN HOLE WITH 2.5" X 6' DD BAILER TO 9533 SLM WITH TOOLS
PULL OUT OF HOLE WITH BAILER 1/4 FULL OF SOLIDS
LAY DOWN LUBRICATOR & SECURE WELL
09/11/2023 - Monday
PJSM @ KGF OFFICE, DISCUSS DAILY OPERATIONS.
DRIVE TO LOCATION
PICK UP & RIG UP LUBRICATOR
PICK UP & MAKE UP 3-1/2" X 7' DD BAILER, RUN TO 9531' SLM WITH TOOL TO 9533'
PULL OUT OF HOLE & CHECK BAILER (2 CUPS MUD & SMALL METAL DEBRIS)
PICK UP & MAKE UP 3" X 7' PUMP BAILER WITH 3-1/2" BALL BOTTOM, RUN TO 9533' SLM WITH TOOLS
PULL OUT OF HOLE & CHECK BAILER (2 CUPS MUD & METAL DEBRIS). PRESSURE UP PRODUCTION CASING TO 500 PSI
PICK UP & MAKE UP 3" PUMP BAILER WITH 3-1/2" BAIL BOTTOM RUN TO 9533' SLM WITH TOOL
PULL OUT OF HOLE & CHECK BAILER (3 CUPS OF SAND)
RUN IN HOLE WITH 3" PUMP BAILER WITH 3-1/2" BAIL BOTTOM RUN TO 9533' SLM WITH TOOL
PULL OUT OF HOLE & CHECK BAILER (EMPTY)
PICK UP & MAKE UP 4.5" GR WITH WEATHERFORD RETRIEVAL TOOL RUN TO 9533'
LATCH ONTO PLUG
BEAT DOWN LOSING 10 PSI ON CASING. JAR UP 3 TIMES WITH 600 LBS TOOL DISENGAGED
PULL OUT OF HOLE AND INSPECT RETRIEVAL TOOL
REDRESS TOOL (NO DAMAGE)
RERUN RETRIEVAL TOOL TO 9533'
BEAT DOWN 40 TIMES JAR UP 4 TIMES WITH 1800 LBS TOOL DISENGAGED
PULL OUT OF HOLE
LAY DOWN LUBRICATOR & SECURE WELL
Rig Start Date End Date
9/8/23 2/16/24
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
KBU 23-05 50-133-20630-00-00 214-061
Daily Operations:
09/14/2023 - Thursday
Complete JSA, Start tubing pressure 850 psi
Start SL bailing with 3" 10ft pump bailer, RIH to 9522 SLM, POOH and no solids, fluid only
Change to a hydrostatic bailer with 3-1/2" ball bottom to 9533'. POOH w/ 4 cups of mud
Run hydrostatic again, recovered 1 cup of mud. Pressure started changing from 160 psi and slowly climbing
RIH w/ 4-1/2" GR w/ Weatherford pulling tool to 9533' SLM, latch w 4 licks and come free, POOH with GR pin sheared
RIH w/ 4-1/2" GS to 9533' SLM w/ tool jar lick for 1hrs @ 1800lb, would not come free. Shear off, POOH and RD 0.125
wire, move wellhouse and rig up 0.160 wire
Finish pressure 220 psi
02/16/2024 - Friday
Decision agreed with Dave Roby (Reservoir Engineer) w/ AOGCC, that production data insufficient to split rates from
commingled production, and all gas cold be allocated to Tyonek Pool, even though zones were commingled. Project
complete.
10/10/2023 - Tuesday
Ak Eline checked in at office, completed PTW & JSA
RU Eline and PT lubricator to 250/2500
RIH with 3.64" JBGR, bobbled through 9387' tagged bottom at 9857'. Overpulled 400# to get off bottom and sticky for
100'. Tools covered in grey sand.
PU PLT tools and RIH per logging program from Engineer.
Make passes across open perfs at multiple speeds. Spinner stopped working on last pass.
POOH and spinner full of sand & RD.
09/13/2023 - Wednesday
Complete JSA, change tool strings w/ 2ea 18" x 13' stem long stroke oil jars. TP start 1800 psi
RIH w/ 4-1/2" GR w/ weatherford pulling tool to 9533' SLM, beat down for 1.5hrs, 600lb overpull comes free, POOH w/
GR. Pulling tool left in hole
RIH w/ 4-1/2" GS to 9532 SLM, latch tool, 8 jar licks w 800lb overpull, comes free, POOH. RIH w/ 3" pump bailer w/ 3-
1/2" ball bottom to 9533' SLM, POOH w/ 1 cup of mud
RIH to same 3 more times, pulling a total of 5 cups of mud out.
Lay down lubricator, secure well, End tubing pressure 1000 psi.
Turn in permit.
09/15/2023 - Friday
Complete PTW and conduct TGSM
Rig up & RIH w/ 4-12/" PR-GS to 9591'KB. Pull plug free w/ 1 jar lick. Truck engine broke down. Able to shear off plug,&
get out of the hole.
Get new truck, RU on well. RIH w/ 4-1/2" PR/GS to 9373', latch plug, jar up 2x, pull free, POOH.
lay down WRP. Rig down. depart KGF.
_____________________________________________________________________________________
Updated by CAH 03-12-24
SCHEMATIC
Kenai Gas Field
Well: KBU 23-05
Last Completed: 07/19/14
PTD: 214-061
OPEN HOLE / CEMENT DETAIL
10-3/4”90 BBLs of 12.5 ppg Lead and 66.5 BBLs of 15.2ppg tail cement in 13.5” Hole.
62 BBLs of cement returns to Surface
7-5/8"153 bbls of 10.5 ppg lead with 25 bbls of 13.5 ppg tail cement. Lost 16.3
bbls during pump job. 13+ PH in final 5 bbls of returns. Est TOC near surface
5”145BBL’s of 15.7 ppg Class G cement in 6-3/4” Hole. SCMT log TOC @ 3,260’
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm
16"Conductor 109 / X-56 / Weld 16”Surf 130'
10-3/4”Surface 45.5 /L-80 / BTC 9.950 Surf 1,511'
7-5/8"Intermediate 29.7 / P-110 / BTC 6.875 Surf 6,108'
5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,547’
JEWELRY DETAIL
No Depth Item
1 5,607’5” Swell Packer
2 7,116’RA Marker with 5’ Pup
3 7,444’RA Marker with 5’ Pup
4 9,029’RA Marker with 5’ Pup
5 10,045’CIBP
PERFORATION DETAIL
Sand Top (MD)Btm (MD)Top (TVD)Btm (TVD)SPF Ft Date Status
D1 9,362’9,404’8,808’8,850’6 42 09/09/23 Open
9,434’9,506’8,880’8,952’6 72 09/09/23 Open
D2 9,525’9,534’8,947’8,956’6 9 10/13/21 Open
D3A
9,808’9,818’9,230’9,240’6 10 07/01/14 Open
9,806’9,816’9,228’9,238’6 10 12/01/16 Open
9,814’9,824’9,236’9,246’6 10 03/06/19 Open
D3B
9,847’9,854’9,269’9,276’6 7 07/19/14 Open
9,854’9,870’9,276’9,292’6 16 07/01/14 Open
9,851’9,881’9,283’9,303’6 20 12/01/16 Open
9,870’9,880’9,292’9,302’6 10 07/19/14 Open
D5 10,072’10,087’9,494’9,509’6 15’06/26/14 Isolated 7/10/14
D6 10,133’10,153’9,555’9,575’6 20’06/25/14 Isolated 7/10/14
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 1/12/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20240112
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL
END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF
KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF
KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF
KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF
KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT
KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF
KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF
KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL
KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT
KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF
MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF
PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF
PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL
PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF
SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF
SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF
SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT
SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF
SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT
SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF
SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL
Please include current contact information if different from above.
T38273
T38275
T38277
T38278
T38279
T38280
T38280
T38281
T38282
T38283
T38284
T38285
T38286
T38287
T38288
T38288
T38289
T38289
T38289
T38290
T38290
1/18/2024
KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.01.18
11:52:00 -09'00'
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 10/17/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20231017
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
BRU 212-26 50283201820000 220058 9/2/2023 AK E-LINE Perf
KBU 14-6Y 50133205720000 207149 9/18/2023 AK E-LINE GPT/Plug
KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf
MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey
MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf
MPU M-22 50029236450000 219111 9/20/2023 AK E-LINE
Mechanical
Cutter
Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE
Tubing
Punch/RCT
PBU 06-16B 50029204600200 223072 10/7/2023 HALLIBURTON RBT
PBU D-18B 50029206940200 215001 9/14/2023 BAKER RPM
PBU J-19 50029216290000 186135 9/26/2023 AK E-LINE TTBP/Cement
PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN
PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN
PBU P1-02A 50029217790100 202065 9/11/2023 BAKER SPN
PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF
PBU R-12A 50029209210100 211055 9/7/2023 BAKER SPN
Please include current contact information if different from above.
T38062
T38063
T38065
T38064
T38066
T38067
T38068
T38069
T38070
T38071
T38072
T38073
T38074
T38075
T38076
10/20/2023
KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.10.20
08:34:04 -08'00'
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: Temp plug & N2
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
10,547'NA
Casing Collapse
Structural
Conductor
Surface 2,480psi
Intermediate 5,340psi
Production 10,500psi
Liner
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:
Contact Email:
Contact Phone:
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
chelgeson@hilcorp.com
907-777-8405
Noel Nocas, Operations Manager 907-564-5278
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
Chad Helgeson, Operations Engineer
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
Subsequent Form Required:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
FEE FEDA028142
214-061
50-133-20630-00-00
Hilcorp Alaska, LLC
Proposed Pools:
N/A
TVD Burst
N/A
9,910psi
1,467'
Size
130'
7-5/8"6,108'
1,511'
MD
See Schematic
9,470psi
5,210psi
130'
5,718'
130'
1,511'
August 24, 2023
N/A
10,547'
Perforation Depth MD (ft):
6,108'
3800 Centerpoint Drive, Suite 1400
Anchorage, Alaska 99503
Kenai Beluga Unit (KBU) 23-05CO 510B
Bel/Up Tyk Gas & Tyk Gas #1
9,969'5"
3,391
10,574'
10,045'
Length
5" Swell Packer ; N/A 5,607' MD / 5,255' TVD ; N/A
9,969' 10,445' 9,467'
Kenai Kenai Tyonek Gas Pool 1
16"
10-3/4"
See Schematic
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 1:41 pm, Aug 14, 2023
323-458
Digitally signed by Noel
Nocas (4361)
DN: cn=Noel Nocas (4361)
Date: 2023.08.11 11:26:29 -
08'00'
Noel Nocas
(4361)
SFD 8/21/2023BJM 9/6/23
Bel/Up Tyk Gas &
Perforate New Pool
DSR-8/14/23*&:
09/06/23
Brett W.
Huber, Sr.
Digitally signed by
Brett W. Huber, Sr.
Date: 2023.09.06
16:05:38 -08'00'
404
RBDMS JSB 090823
Well Prognosis
Well: KBU 23-05
Date: 08/10/23
Well Name:KBU 23-05 API Number:50-133-20630-00
Current Status:Producing Gas Well Permit to Drill Number:214-061
Regulatory Contact:Donna Ambruz 777-8305
First Call Engineer:Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C)
Second Call Engineer:Jake Flora (907) 777-8442 (O) (720) 988-5375 (C)
Maximum Expected BHP:~ 4,267 psi @ 8,762’ TVD (Based on RFT data in 43-07Y)
Max. Predicted Surface Pressure:~ 3,391 psi (0.10 psi/ft gas gradient)
Brief Well Summary
KBU 23-05 was drilled and completed June 2014. It was initially completed in the D6 and D5 sands, however
these were found to be unproductive and were plugged back. The well is currently completed in the Tyonek
D3A, D3B and D 2 sands, currently flowing ~1 mmscfd.
The purpose of this work/sundry is to temporarily isolate the Tyonek Gas Pool 1 and add the Tyonek D-1 sand
which is the bottom sand in the Beluga/Upper Tyonek Gas Pool and add rate to the well. Pending the results of
the testing on Tyonek D-1 sand, the plan is to pull the plug and commingle the Tyonek Gas Pool 1 and
Beluga/Upper Tyonek Gas Pool per CO 510B.
Notes Regarding Wellbore Condition
x Monobore 5” completion
x SL tagged fill @ 9,924’ & fluid level at 9,682’
x Max predicted pressure based on 3 wells where pressures were collected in same sand with RFT tools
while drilling in 2017 (KU 11-07X, KBU 32-06, & KBU 43-07Y) Other pressures across proposed perfs
range from 1,228 psi – 4,267 psi
Pool Tops in KBU 23-05 based on KU 41-18 reference well in CO 510B
- Tyonek Gas Pool 1: 9,508’ MD; 8,929’ TVD
E-Line Procedure
1. SI well (allow to build for at least 24hrs prior to Eline)
2. MIRU E-line, PT lubricator to 250 psi low and 4,000 psi high
3. Set WRP @ 9522’ (there is a collar is at 9,518’)
a. SL to set catcher basket above WRP to collect any perf debris
4. MIRU N2 Unit, test flowline to 3,000 psi
5. Pressure up well with N2 to 2,500psi
6. Perforate the proposed sands with 3-3/8” 6 SPF 60 deg phased perf guns.
Proposed Perforated Intervals
Pool Sands Top (MD) Btm (MD) Total
Top (TVD) Bottom
(TVD)
Beluga/Upper Tyk D1 ±9,362’ ±9,404’±42’±8,808’ ±8,850’
Beluga/Upper Tyk D1 ±9,433’ ±9,506’±73’’±8,879’ ±8,952’
a. Proposed perfs also shown on the proposed schematic in red font.
Well Prognosis
Well: KBU 23-05
Date: 08/10/23
b. Send the correlation pass to the Reservoir Engineer (Reid Edwards), and Geologist (Daniel
Yancey) for confirmation.
c. Verify PTs are open to SCADA before perforating. Record tubing pressures at 5, 10 and 15
minutes after each perforating run.
d. These sands are in the Beluga/Upper Tyonek Gas Pool per CO 510B.
7. RDMO e-line
8. Turn well over to production
9. Operations to test well. Once enough data is collected or pressures are low enough to commingle
10. SL will pull catcher basket and WRP
11. Operations will flow well with both Pools commingled
12. A production survey will be run within 30 days of commingling production as per CO 510B for allocation
purposes.
Attachments:
1. Current Wellbore Schematic
2. Proposed Wellbore Schematic
3. Standard Nitrogen Procedure
e Beluga/Upper Tyonek Gas Pool per CO 510B.
_____________________________________________________________________________________
Updated by JLL 11/11/21
SCHEMATIC
Kenai Gas Field
Well: KBU 23-05
Last Completed: 07/19/14
PTD: 214-061
OPEN HOLE / CEMENT DETAIL
10-3/4” 156BBL’s of cement in 13.5” Hole. Returns to Surface
7-5/8" 178BBL’s of cement in 9-7/8” Hole. Est TOC @ 1,500’
5” 145BBL’s of cement in 6-3/4” Hole. Est TOC @ 3,500’
TD =10,547’(MD) / 9,969’(TVD)
16”
RKB: MSL = 18.6’
5”
3
4
10-3/4”
7-5/8”
1
2
Tyonek
D2-D6
PBTD =10,461’(MD) / 9,883’(TVD)
5
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm
16" Conductor 109 / X-56 / Weld 16” Surf 130'
10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7 / P-110 / BTC 6.875 Surf 6,108'
5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,547’
JEWELRY DETAIL
No Depth Item
1 5,607’ 5” Swell Packer
2 7,116’ RA Marker with 5’ Pup
3 7,444’ RA Marker with 5’ Pup
4 9,029’ RA Marker with 5’ Pup
5 10,045’ CIBP
PERFORATION DETAIL
Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Ft Date Status
D2 9,525’ 9,534’ 8,947’ 8,956’ 6 9 10/13/21 Open
D3A
9,808’ 9,818’ 9,230’ 9,240’ 6 10 07/01/14 Open
9,806’ 9,816’ 9,228’ 9,238’ 6 10 12/01/16 Open
9,814’ 9,824’ 9,236’ 9,246’ 6 10 03/06/19 Open
D3B
9,847’ 9,854’ 9,269’ 9,276’ 6 7 07/19/14 Open
9,854’ 9,870’ 9,276’ 9,292’ 6 16 07/01/14 Open
9,851’ 9,881’ 9,283’ 9,303’ 6 20 12/01/16 Open
9,870’ 9,880’ 9,292’ 9,302’ 6 10 07/19/14 Open
D5 10,072’ 10,087’ 9,494’ 9,509’ 6 15’ 06/26/14 Isolated
(7/10/2014)D6 10,133’ 10,153’ 9,555’ 9,575’ 6 20’ 06/25/14
_____________________________________________________________________________________
Updated by CAH 8/3/23
PROPOSED
Kenai Gas Field
Well: KBU 23-05
Last Completed: 07/19/14
PTD: 214-061
OPEN HOLE / CEMENT DETAIL
10-3/4” 156BBL’s of cement in 13.5” Hole. Returns to Surface
7-5/8" 178BBL’s of cement in 9-7/8” Hole. Est TOC @ 1,500’
5” 145BBL’s of cement in 6-3/4” Hole. Est TOC @ 3,500’
TD =10,547’(MD) / 9,969’(TVD)
16”
RKB: MSL = 18.6’
5”
3
4
10-3/4”
7-5/8”
1
2
Tyonek
D2-D6
PBTD =10,461’(MD) / 9,883’(TVD)
5
Tyonek D1
4A
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm
16" Conductor 109 / X-56 / Weld 16” Surf 130'
10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7 / P-110 / BTC 6.875 Surf 6,108'
5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,547’
JEWELRY DETAIL
No Depth Item
1 5,607’ 5” Swell Packer
2 7,116’ RA Marker with 5’ Pup
3 7,444’ RA Marker with 5’ Pup
4 9,029’ RA Marker with 5’ Pup
4A ±9,515’ WRP
5 10,045’ CIBP
PERFORATION DETAIL
Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Ft Date Status
D1 ±9,362’ ±9,404’ ±8,808’ ±8,850’ 6 42 TBD Proposed
D1 ±9,433’ ±9,506’ ±8,879’ ±8,952’ 6 73 TBD Proposed
D2 9,525’ 9,534’ 8,947’ 8,956’ 6 9 10/13/21 Open
D3A
9,808’ 9,818’ 9,230’ 9,240’ 6 10 07/01/14 Open
9,806’ 9,816’ 9,228’ 9,238’ 6 10 12/01/16 Open
9,814’ 9,824’ 9,236’ 9,246’ 6 10 03/06/19 Open
D3B
9,847’ 9,854’ 9,269’ 9,276’ 6 7 07/19/14 Open
9,854’ 9,870’ 9,276’ 9,292’ 6 16 07/01/14 Open
9,851’ 9,881’ 9,283’ 9,303’ 6 20 12/01/16 Open
9,870’ 9,880’ 9,292’ 9,302’ 6 10 07/19/14 Open
D5 10,072’ 10,087’ 9,494’ 9,509’ 6 15’ 06/26/14 Isolated
(7/10/2014)D6 10,133’ 10,153’ 9,555’ 9,575’ 6 20’ 06/25/14
STANDARD WELL PROCEDURE
NITROGEN OPERATIONS
12/08/2015 FINAL v1 Page 1 of 1
1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport.
2.) Notify Pad Operator of upcoming Nitrogen operations.
3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and
appropriate Safety Data Sheets (formerly MSDS).
4.) Document hazards and mitigation measures and confirm flow paths. Include review on
asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate
routing of flowlines, adequate venting and atmospheric monitoring.
5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport.
6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip
checks.
7.) Place signs and placards warning of high pressure and nitrogen operations at areas where
Nitrogen may accumulate or be released.
8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing
and casing pressures.
9.) Place pressure gauges upstream and downstream of any check valves.
10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct.
11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to
detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as
well that measures O2 levels.
12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential
Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank)
to 1,500 psi. Perform visual inspection for any leaks.
13.) Bleed off test pressure and prepare for pumping nitrogen.
14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns
are to be routed to the returns tank.
15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and
bleed down lines between well and Nitrogen Pumping Unit.
16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has
accumulated begin rig down of lines from the Nitrogen Pumping Unit.
17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned
and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport.
18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport.
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well
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 10,547 feet 10,045 feet
true vertical 9,969 feet N/A feet
Effective Depth measured 10,045 feet 5,607 feet
true vertical 9,467 feet 5,255 feet
Perforation depth Measured depth 9,525 - 9,880 feet
True Vertical depth 8,947 - 9,302 feet
Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A
5,607 MD
Packers and SSSV (type, measured and true vertical depth)5" Swell Pkr 5,255 TVD SSSV: NA
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Prior to well operation:
Subsequent to operation:
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:
Contact Name:
Contact Email:
Authorized Title:Contact Phone:
5,340psi
10,500psi
5,210psi
9,470psi
9,910psi
Burst Collapse
2,480psi
130'
1,467'
5,718'
9,969'
6,108'
10,547'5"
measuredPlugs
Junk measured
N/A
Length
130'
1,511'
Size
Conductor
Surface
Intermediate
16"
10-3/4"
7-5/8"
Production
Liner
6,108'
10,547'
Casing
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
214-061
50-133-20630-00-00
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
Hilcorp Fee (Formerly A028142)
Kenai Gas Field / Tyonek Gas Pool
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
Kenai Beluga Unit (KBU) 23-05
Hilcorp Alaska, LLC
Other: ______________________
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
501,015
0 37
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
0
Gas-Mcf
MD
130'
1,511'
N/A
0
Structural
TVD
321-496
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
Authorized Name and
Digital Signature with Date:
WINJ WAG
912
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
2
36
Chad Helgeson
chelgeson@hilcorp.com
(907) 777-8405Dan Marlowe - Operations Manager
L
G
Form 10-404 Revised 10/2021 Submit Within 30 days of Operations
By Meredith Guhl at 8:00 am, Nov 12, 2021
Digitally signed by Dan Marlowe
(1267)
DN: cn=Dan Marlowe (1267),
ou=Users
Date: 2021.11.11 14:55:42 -09'00'
Dan Marlowe
(1267)
SFD 11/15/2021
RBDMS HEW 11/12/2021
BJM 11/15/21 DSR-11/12/21
_____________________________________________________________________________________
Updated by JLL 11/11/21
SCHEMATIC
Kenai Gas Field
Well: KBU 23-05
Last Completed: 07/19/14
PTD: 214-061
OPEN HOLE / CEMENT DETAIL
10-3/4” 156BBL’s of cement in 13.5” Hole. Returns to Surface
7-5/8" 178BBL’s of cement in 9-7/8” Hole. Est TOC @ 1,500’
5” 145BBL’s of cement in 6-3/4” Hole. Est TOC @ 3,500’
TD =10,547’(MD) / 9,969’(TVD)
16”
RKB: MSL = 18.6’
5”
3
4
10-3/4”
7-5/8”
1
2
Tyonek
D2-D6
PBTD =10,461’(MD) / 9,883’(TVD)
5
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm
16" Conductor 109 / X-56 / Weld 16” Surf 130'
10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7 / P-110 / BTC 6.875 Surf 6,108'
5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,547’
JEWELRY DETAIL
No Depth Item
1 5,607’ 5” Swell Packer
2 7,116’ RA Marker with 5’ Pup
3 7,444’ RA Marker with 5’ Pup
4 9,029’ RA Marker with 5’ Pup
5 10,045’ CIBP
PERFORATION DETAIL
Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Ft Date Status
D2 9,525’ 9,534’ 8,947’ 8,956’ 6 9 10/13/21 Open
D3A
9,808’ 9,818’ 9,230’ 9,240’ 6 10 07/01/14 Open
9,806’ 9,816’ 9,228’ 9,238’ 6 10 12/01/16 Open
9,814’ 9,824’ 9,236’ 9,246’ 6 10 03/06/19 Open
D3B
9,847’ 9,854’ 9,269’ 9,276’ 6 7 07/19/14 Open
9,854’ 9,870’ 9,276’ 9,292’ 6 16 07/01/14 Open
9,851’ 9,881’ 9,283’ 9,303’ 6 20 12/01/16 Open
9,870’ 9,880’ 9,292’ 9,302’ 6 10 07/19/14 Open
D5 10,072’ 10,087’ 9,494’ 9,509’ 6 15’ 06/26/14 Isolated
(7/10/2014)D6 10,133’ 10,153’ 9,555’ 9,575’ 6 20’ 06/25/14
D2 9,525’ 9,534’ 8,947’ 8,956’ 6 9 10/13/21 Open
Rig Start Date End Date
E-Line 10/13/21 10/13/21
10/13/2021 - Wednesday
Crew arrives at facility and obtains permit. MIRU e-line and pressure test lubricator to 250 psi low and 3,500 psi high. RIH
with 2-7/8" HC guns and correlate to open hole logs. Perforated Tyonek D2 from 9,525'-9,534' with well flowing 940 mcf
@ 35 psi. 5 minutes: 1,061 mcf @ 41.8 psi. 10 minutes: 1,117 mcf @ 43.4 psi. 15 minutes: 1,165 mcf @ 45 psi. POOH all
shots fired. RDMO e-line and spot equipment for KDU-9.
Daily Operations:
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit NumberWell Name
KBU 23-05 50-133-20630-00-00 314-377
Perforated Tyonek D2 from 9,525'-9,534' w
Kaitlyn Barcelona Hilcorp North Slope, LLC
GeoTechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: kaitlyn.barcelona@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal
Received By: Date:
DATE: 11/09/2021
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
KBU 23-05 (PTD 214-061)
Plug 10/13/2021
Please include current contact information if different from above.
37'
(6HW
Received By:
11/09/2021
By Abby Bell at 4:42 pm, Nov 09, 2021
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:
W hat Regulation or Conservation Order governs well spacing in this pool?
W ill planned perforations require a spacing exception?Yes No
9.Property Designation (Lease Number):10. Field/Pool(s):
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
Casing Collapse
Structural
Conductor
Surface 2,480psi
Intermediate 5,340psi
Production 10,500psi
Liner
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.W ell Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16.Verbal Approval:Date:GAS WAG GSTOR SPLUG
Commission Representative: GINJ Op Shutdown Abandoned
Taylor Wellman 777-8449 Contact Name: Todd Sidoti
Operations Manager Contact Email:
Contact Phone: 777-8443
Date:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by:COMMISSIONER THE COMMISSION Date:
Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Authorized Title:
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Signature:
October 6, 2021
N/A
10,547'
Perforation Depth MD (ft):
6,108'
See Attached Schematic
10,574' 9,969'5"
16"
10-3/4"
130'
7-5/8"6,108'
1,511'5,210psi
130'
1,467'
5,718'
130'
1,511'
N/A
TVD Burst
N/A
9,910psi
MD
9,470psi
Length Size
CO 510
Hilcorp Alaska, LLC
3800 Centerpoint Dr, Suite 1400
Anchorage Alaska 99503
PRESENT WELL CONDITION SUMMARY
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Hilcorp Fee (Formerly A028142)
214-061
50-133-20630-00-00
Kenai Beluga Unit (KBU) 23-05
Kenai Gas Field / Tyonek Gas Pool
COMMISSION USE ONLY
Authorized Name:
Tubing Grade: Tubing MD (ft):
See Attached Schematic
todd.sidoti@hilcorp.com
3,197
5" Swell Packer ; N/A 5,607' MD / 5,255' TVD ; N/A
Perforation Depth TVD (ft): Tubing Size:
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 8:12 am, Sep 22, 2021
321-496
Digitally signed by Taylor
Wellman (2143)
DN: cn=Taylor Wellman (2143),
ou=Users
Date: 2021.09.21 16:43:10 -08'00'
Taylor Wellman
(2143)
CO 510B
10,547'
SFD 9/26/2021
DSR-9/22/21
10-404
BJM 9/24/21
SFD 9/26/2021
9,969'
SFD 9/26/2021
dts 9/28/2021 JLC 9/28/2021
Jeremy Price Digitally signed by Jeremy Price
Date: 2021.09.28 11:13:43 -08'00'
RBDMS HEW 9/28/2021
Well Prognosis
Well: KBU 23-05
Date: 09/21/2021
Well Name: KBU 23-05 API Number: 50-133-20630-00
Current Status: Producing Gas Well Leg: N/A
Estimated Start Date: October 5, 2021 Rig: E-line
Reg. Approval Req’d? 10-403 Date Reg. Approval Rec’vd:
Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-061
First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C)
Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C)
AFE Number:
Maximum Expected BHP: ~ 4,137 psi @ 9,403’ TVD (Based on normal gradient)
Max. Predicted Surface Pressure: ~ 3,197 psi (0.10 psi/ft gas gradient)
Brief Well Summary
KBU 23-05 was drilled and completed June 2014. It was initially completed in the D6 and D5 sands, however
these were found to be unproductive and were plugged back. The well is currently completed in the D3A and
D3B sands.
The purpose of this work/sundry is to add the D-4A and D2 sands.
E-Line Procedure
1. MIRU E-line, PT lubricator to 250 psi low and 3500 psi high.
2. Perforate the Tyonek sands with 2-7/8” 6 SPF 60 deg phased perf guns with the well flowing.
Gross Proposed Perforated Intervals
Pool Sands Top (MD) Btm (MD) Total Top (TVD) Bottom
(TVD)
Tyonek D2 ±9,525’ ±9,534’ ±9’ ±8,947’ ±8,956’
Tyonek D4A ±9,982’ ±9,996’ ±14’ ±9,403’ ±9,417’
a. Send the correlation pass to the Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks)
for confirmation.
b. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing
pressures at 5, 10 and 15 minutes after each perforating run.
3. RDMO e-line.
4. Turn well over to production.
Attachments:
1. Current Wellbore Schematic
2. Proposed Wellbore Schematic
add the D-4A and D2 sands.
well is currently completed in the D3A and
D3B sands.
-00
_____________________________________________________________________________________
Updated by DMA 03-12-19
SCHEMATIC
Kenai Gas Field
Well: KBU 23-05
Last Completed: 07/19/14
PTD: 214-061
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm
16" Conductor 109 / X-56 / Weld 16” Surf 130'
10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7 / P-110 / BTC 6.875 Surf 6,108'
5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,547’
JEWELRY DETAIL
No Depth Item
1 5,607’ 5” Swell Packer
2 7,116’ RA Marker with 5’ Pup
3 7,444’ RA Marker with 5’ Pup
4 9,029’ RA Marker with 5’ Pup
5 10,045’ CIBP
OPEN HOLE / CEMENT DETAIL
10-3/4” 156BBL’s of cement in 13.5” Hole. Returns to Surface
7-5/8" 178BBL’s of cement in 9-7/8” Hole. Est TOC @ 1,500’
5” 145BBL’s of cement in 6-3/4” Hole. Est TOC @ 3,500’
PERFORATION DETAIL
Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Ft Date Status
D3A 9,808’ 9,818’ 9,230’ 9,240’ 6 10 07/01/14 Open
9,806’ 9,816’ 9,228’ 9,238’ 6 10 12/01/16 Open
D3A 9,814’ 9,824’ 9,236’ 9,246’ 6 10 03/06/19 Open
D3B
9,847’ 9,854’ 9,269’ 9,276’ 6 7 07/19/14 Open
9,854’ 9,870’ 9,276’ 9,292’ 6 16 07/01/14 Open
9,851’ 9,881’ 9,283’ 9,303’ 6 20 12/01/16 Open
9,870’ 9,880’ 9,292’ 9,302’ 6 10 07/19/14 Open
D5 10,072’ 10,087’ 9,494’ 9,509’ 6 15’ 06/26/14 Isolated
D6 10,133’ 10,153’ 9,555’ 9,575’ 6 20’ 06/25/14 Isolated
_____________________________________________________________________________________
Updated by TCS 09-21-21
PROPOSED SCHEMATIC
Kenai Gas Field
Well: KBU 23-05
Last Completed: 07/19/14
PTD: 214-061
OPEN HOLE / CEMENT DETAIL
10-3/4” 156BBL’s of cement in 13.5” Hole. Returns to Surface
7-5/8" 178BBL’s of cement in 9-7/8” Hole. Est TOC @ 1,500’
5” 145BBL’s of cement in 6-3/4” Hole. Est TOC @ 3,500’
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm
16" Conductor 109 / X-56 / Weld 16” Surf 130'
10-3/4” Surface 45.5 /L-80 / BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7 / P-110 / BTC 6.875 Surf 6,108'
5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 10,547’
JEWELRY DETAIL
No Depth Item
1 5,607’ 5” Swell Packer
2 7,116’ RA Marker with 5’ Pup
3 7,444’ RA Marker with 5’ Pup
4 9,029’ RA Marker with 5’ Pup
5 10,045’ CIBP
PERFORATION DETAIL
Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Ft Date Status
D2 ~9,525’ ~9,534’ ~8,947’ ~8,956’ 6 9
D3A
9,808’ 9,818’ 9,230’ 9,240’ 6 10 07/01/14 Open
9,806’ 9,816’ 9,228’ 9,238’ 6 10 12/01/16 Open
9,814’ 9,824’ 9,236’ 9,246’ 6 10 03/06/19 Open
D3B
9,847’ 9,854’ 9,269’ 9,276’ 6 7 07/19/14 Open
9,854’ 9,870’ 9,276’ 9,292’ 6 16 07/01/14 Open
9,851’ 9,881’ 9,283’ 9,303’ 6 20 12/01/16 Open
9,870’ 9,880’ 9,292’ 9,302’ 6 10 07/19/14 Open
D4A ~9,982’ ~9,996’ ~9,403’ 9,417’ 6 14’
D5 10,072’ 10,087’ 9,494’ 9,509’ 6 15’ 06/26/14 Isolated
(7/10/2014) D6 10,133’ 10,153’ 9,555’ 9,575’ 6 20’ 06/25/14
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
MAR 18 2019
1. Operations Abandon Plug Perforations
LJ Fracture Stimulate LJ
Pull Tubing Li Operations shutdown Li
Performed: Suspend ❑ Perforate
Other Stimulate ❑
Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ erforate New Pool
❑ Repair Well ❑
Re-enter Susp Well ❑ Other: ❑
2. Operator
Hilcorp Alaska, LLC
4. Well Class Before Work:
5. Permit to Drill Number:
Name:
Development ❑✓
Stratigraphic❑
Exploratory ❑
Service ❑
214-061
3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage,
6. API Number:
AK 99503
50-133-20630-00
7. Property Designation (Lease Number):
8. Well Name and Number:
Hilcorp Fee (Formerly A028142)
KBU 23-05
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10. Field/Pool(s):
N/A
Kenai Field / Beluga Upper Tyonek and Tyonek Pool
11. Present Well Condition Summary:
Total Depth measured 10,547
feet Plugs
measured 10,045 feet
true vertical 9,969
feet Junk
measured N/A feet
Effective Depth measured 10,461
feet Packer
measured 5,607 feet
true vertical 9,883
feet
true vertical 5,255 feet
Casing Length Size
MD
TVD Burst Collapse
Structural
Conductor 130' 16"
130'
130'
Surface 1,511' 10-3/4"
1,511'
1,467' 5,210psi 2,489psi
Intermediate 6,108' 7-5/8"
6,108'
5,718' 9,470psi 5,340psi
Production 10,547' 5"
10,547'
9,969' 9,91 Ops! 10,500psi
Liner
Perforation depth Measured depth See Attached Schematic
True Vertical depth See Attached Schematic
Tubing (size, grade, measured and true vertical depth)
N/A
N/A N/A N/A
Packers and SSSV (type, measured and true vertical depth)
5" Swell Pkr; N/A
5,607' MD 5,255' ND N/A; N/A
12. Stimulation or cement squeeze summary:
N/A
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure: N/A
13.
Representative Daily Average Production or Injection Data
Oil -Bbl
Gas-Mcf
Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0
894
0 0 32
Subsequent to operation: 0
4394
0 0 732
14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283)
15. Well Class after work:
Daily Report of Well Operations Q
Exploratory[]
Development Q Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work:
Oil Gas ✓ WDSPL
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Sundry Number or N/A if C.O. Exempt:
319-095
Authorized Name: Bo York 777-8345
Contact Name: Ted Kramer
Authorized Title: Operations Manager
Contact Email: 1kMmeKrdh1lc0ro.0 m
Authorized Signature:
Date: 1 -v&, Zl t \ Contact Phone: 777-8420
2 1
Form 10-404 Revised 4/2017 �`� 3' RBDMS!*�MAR 19 2019 Submit Original Only
Hilcorp Alaska, LLC
Well Operations Summary
Well Name
Rig
API Number Well Permit Number
Start Date
End Date
KBU 23-05
E -Line
50-133-20630-00-00 1 314-377
3/3/19
3/6/19
Daily Operations:
03/03/2019 -Sunday
MOB FROM KU - 31-05. RIG UP W/L - PT LUB - GOOD. RIH W/ 3.7" GAUGE RING TO 9,871'KB - POOH. RIH W/ 3" X 11.5'
DD BAILER (DRIFT FOR PERF GUNS) TO 9,883'KB TAG - POOH. RIG DOWN W/L. DEPART FIELD FOR PWL SHOP.
03/06/2019- Wednesday
Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. Well
flowing. RIH w/ 2-7/8" x 10' Razor HC, 6 spf, 60 deg phase and tie into Halliburton log sent from town. Get ok to perf
from 9,814' to 9,824'. Spotted and fired gun with well flowing 947K at 38 psi. 5 min - 269 psi, 10 min 428 psi, 15 min 530
psi at 2,82 million, 685 psi, flow 4 million with choke on 55%. Still building pressure. Up in lubricator with perf gun and
have 834 psi on tubing. All shots fired, gun was some what wet. In high. pressure system flowing 4.39 million at 825 psi.
Rig down lubricator and equipment and turn well back over to field.
16'
Kenai Gas Field
SCHEMATIC Well: KBU 23-05
Last Completed: 07/19/14
Hilimm Ahake, LLC PTD: 214-061
7-5{E"
RKL' MSL=18.9
l Tym
03130E
TD=10,54r(MD) / 9,969'(iVD)
PBTD =10,461'(MO) / 9,883'(TVD)
CASING
Size
Type
Wt/Grade/Conn
ID
Top
Btm
16"
Conductor
109/X-56/Weld
16"
Surf
130'
SO -3/4"
Surface
45.5/L-80/BTC
9.950
Surf
1,511-
,511'29.7/P-110/BTC
9,806'
29.7 / P-110 / BTC
6.875
Surf
6,108-
,108'18/L-80/DWC/C-HT
10
12/01/16
18 / L-80 / DWC/C-HT
4.276
Surf
10,547'
JEWELRY DETAIL
em
Top (MD)
Btm (MD)
" Swell PackerA
Btm (TVD)
M5,607'
Marker with 5' PupA
Date
Status
Marker with 5' PuA
9'808
9,818
Marker with 5' PupBP
9,240'
6
10
PERFORATION DETAII
Sand
Top (MD)
Btm (MD)
Top (TVD)
Btm (TVD)
SPF
Ft
Date
Status
D3A
9'808
9,818
9,230'
9,240'
6
10
07/01/14
Open
9,806'
9,816'
9,228'
9,238'
6
10
12/01/16
Open
D3A
9,814'
9,824'
9,236'
9,246'
6
10
03/06/19
Open
9,847'
9,854'
9,269'
9,276'
6
7
07/19/14
Open
D38
9'854
9,870'
9,276'
9,292'
6
16
07/01/14
Open
9,851'
9,881'
9,283'
9,303'
6
20
12/01/16
Open
9,870'
9,880'
9,292'
9,302'
6
10
07/19/14
Open
D5
10,072'
10,087'
9,494'
9,509'
6
15'
06/26/14
Isolated
D6
10,133' 1
10,153'
9,555'
9,575'
6 1
20' 1
06/25/14
Isolated
OPEN HOLE / CEMENT DETAIL
10-3/4" 15666L's of cement in 13.5" Hale. Returns to Surface
7-5/8" 1786BL's of cement in 9-7/8" Hole. Est TOC @ 1,500'
5" 145BBL's of cement in 6-3/4" Hole. Est TOC @ 3,500'
Updated by DMA 03-12-19
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Bo Tork
Operations Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Alaska Oil and Gas
Conservation Commission
Re: Kenai Field, Beluga Upper Tyonek and Tyonek Gas Pools, KBU 23-05
Permit to Drill Number: 214-061
Sundry Number: 319-095
Dear Mr. York:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
w .aogcc.alaska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
-49p��
Daniel T. Seamount, Jr.
Commissioner
DATED this S day of March, 2019.
RBDMB—P''/MRR 0 5 2019
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
flOa1_[Wb'irYlrl
GEDVED
FEB 2 7 2010
A rN -" s>
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate Q 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:
Hilcorp Alaska, LLC
Exploratory ❑ Development ❑r
Stratigraphic ❑ Service ❑
214-061
3. Address: 3800 Centerpoint Dr, Suite 1400
6. API Number:
Anchorage Alaska 99503
50-133-20630-00-00
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? C0510
�
Will planned perforations require a spacing exception? Yes ❑ No ❑✓
KBU 23-05
9. Property Designation (Lease Number): Fop a
10. Field/Pool(s): a
Hilcorp Fee (Formerly A028142)
Kenai Field / Beluga Upper Tyonek and Tyonek Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:
MPSP (psi):
Plugs (MD): Junk (MD):
10,547' 9,969 10,461' 9,883'
-1,988psi
10,045' N/A
Casing Length Size MD
TVD
Burst Collapse
Structural
Conductor 130' 16" 130'
130'
Surface 1,511' 10-3/4" 1,511'
1,467'
5,210psi 2,480psi
Intermediate 6,108' 7-5/8" 6,108'
5,718'
9,470psi 5,340psi
Production 10,547' S" 10,547'
9,969'
9,910psi 10,500psi
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
See Attached Schematic
See Attached Schematic
N/A
N/A
N/A
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
5" Swell Packer and N/A
5,607(MD) 15,255 (TVD) and N/A
12. Attachments: Proposal Summary r Wellbore schematic Q
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: March 7, 2019
OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑
GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer
Authorized Title: Operations Manager Contact Email: tkramer(rDhilcorp.com
i Contact Phone: 777-8420
.2�
Authorized Signature: Date: 1
I
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 Oq A5 -
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes ❑ No ❑ ��9
R 5 2
Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0—,/,),-( RBDMCJ` MAR
APPROVED BY
// q
Approved by: COMMISSIONER THE COMMISSION Date: -3L /
,/s//7
3 ` I' Submit Form and
Form 10-403 Revisetl 42017 Approv application is v W �m�t1 N t� to of approval. `�Attachments ��AnAD, Duplicate
,; K 1�.f� I �L �1.. U nW/
H
Hileora Alaska, LL'
Well Prognosis
Well: KBU 23-05
Date: 2/27/2019
Well Name:
KBU 23-05
API Number:
50-133-20630-00
Current Status:
Producing
Leg:
N/A
Estimated Start Date:
March 7, 2019
Rig:
Reg. Approval Req'd?
10-403
Date Reg. Approval Rec'vd:
D -3A
Regulatory Contact:
Donna Ambruz 777-8305
Permit to Drill Number:
214-061
First Call Engineer:
Ted Kramer
(907) 777-8420 (0)
(985) 867-0665 (C)
Second Call Engineer:
Bo York
(907) 777-8345 (0)
(907) 727-9247 (C)
AFE Number:
Maximum Expected BHP:
Max. Predicted Surface Pressure:
Brief Well Summary
— 2,908 psi @ 9,202' TVD (PBU on 04/21/16)
— 1,988 psi (0.10 psi/ft gas gradient)
KBU 23-05 was drilled and completed June 2014. It was initially completed in the D6 and D5 sands, however
these were found to be unproductive and were plugged back. The well is currently completed in the D3A and
D36 sands.
The purpose of this work/sundry is to add a section in the D -3A sand.
E -Line Procedure
1. MIRU E -line, PT lubricator to 3,000 psi Hi 250 Low.
2. If necessary, bleed pressure down or add pressure as requested by the RE to establish a drawdown on
the formation.
3. Perforate the Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns. All intervals are planned for 12
SPF so each zone may be shot twice. Send the correlation pass to the Operations Engineer, Reservoir
Engineer, and Geologist for confirmation.
Gross Proposed Perforated Intervals
4. POOH.
5. RD a -line.
6. Turn well over to production.
Attachments:
1. Current and Proposed Wellbore Schematic
Sands
Top (MD)
Btm (MD)
Top (TVD)
Bottom
FT
(TVD)
Tyonek
D -3A
±9,814,
1 ±9,824'
±9,151'
±9,161'
±10
4. POOH.
5. RD a -line.
6. Turn well over to production.
Attachments:
1. Current and Proposed Wellbore Schematic
Kenai Gas Field
SCHEMATIC Well: KBU 23-05
Last Completed: 07/19/14
corn Alaska, LLC PTD: 214-061
RKB: MSL=18.6
163/4"
CASING DETAIL
Size
Type
Wt/Grade/Conn
ID
Top
Btm
16"
Conductor
109/X-56/Weld
16"
Surf
130'
10-3/4"
Surface
45.5/L-80/BTC
9.950
Surf
1,511'
7-5/8"
Intermediate
29.7/P-110/BTC
6.875
Surf
6,108-
,108'5"
5..
Production
18 / L-80 / DWC/C-HT
4.276
Surf
10,547'
JEWELRY DETAIL
No
Depth
Item
1
5,607'
5" Swell Packer
2
7,116'
RA Marker with 5' Pup
3
7,444'
RA Marker with 5' Pup
4
9,029'
RA Marker with 5' Pup
5
10,045'
CIBP
PERFORATION DETAIL
Sand
Top (MD)
Btm (MD)
Top (TVD)
8tm (TVD)
SPF
Ft
Date
Status
9.808'
9,818'
9,230'
9,240'
6
10
07/01/14
Open
D3A
9,806'
9,816'
9,228'
9,238'
6
10
12/01/16
Open
9,847'
9,854'
9,269'
9,276'
6
7
07/19/14
Open
9854'
9,870'
9,276'
9,292'
6
16
07/01/14
Open
D38
9,851'
9,881'
9,283'
9,303'
6
20
12/01/16
Open
9,870'
9,880'
9,292'
9,302'
6
10
07/19/14
Open
DS
10,072'
10,087'
9,494'
9,509'
6
15'
06/26/14
Isolated
D6
10,133'
10,153'
9,555'
9,575'
fi
20'
06/25/14
Isolated
OPEN HOLE / CEMENT DETAIL
30-3/4" 15688L's of cement in 13.5" Hole. Returns to Surface
7-5/8" 178BBL's of cement in 9-7/8" Hole. Est TOC @ 1,500'
7.5/3" I Il 1 5" 1 145BBUS of cement in 6-3/4" Hole. Est TOC @ 3,500'
Tymek
. 0.'AD6
s 1
TO=10,547'(MD) / 9,969'(TVD)
PB l)=10,461'(MD)/ 9,8V(TVD)
Updated by DMA 01-12-17
H
mra A".. LLC
REL MSL=18.6'
16'
10-3/4•
PROPOSED SCHEMATIC
CASING DETAIL
Kenai Gas Field
Well: KBU 23-05
Last Completed: 07/19/14
PTD: 214-061
Size
Type
Wt/Grade/Conn
ID
Top
Btm
16"
Conductor
109/X-56/Weld
16"
Surf
130'
10-3/4"
Surface
45.5/L-80/BTC
9.950
Surf
1,S11-
7-5/8"
Intermediate
29.7/P-110/BTC
6.875
Surf
6,108'
5"
Production
18/L-80/DWC/C-HT
4.276
Surf
10,547'
JEWELRY DETAIL
No Depth Item
1
5,607'
5" Swell Packer
Btm (TVD)
2
7,116'
RA Marker with
5' Pup
3
7,444'
RA Marker with
5' Pu
4
9,029'
RA Marker with
5' Pup
5
10,045'
CIBP
9,816'
PERFORATION DETAIL
Sand
Top (MD)
Btm (MD)
Top (TVD)
Btm (TVD)
SPF
Ft
Date
Status
9,818'
9,230'
9,240'
6
10
07/01/14
Open
D3A
N08
9,816'
9,228'
9,238'
6
10
12/01/16
Open
D3A
±9,814'
±9,824'
±9,236'
59,246'
-
±10
Proposed
TBD
9,847'
9,854'
9,269'
9,276'
6
7
07/19/14
Open
9.854'
9,870'
9,276'
9,292'
6
16
07/01/14
Open
D3B
9,851'
9,881'
9,283'
9,303'
6
20
12/01/16
Open
9,870'
9,880'
9,292'
9,302'
6
30
07/19/14
Open
D5
10,072'
10,087'
9,494'
9,509'
6
15'
06/26/14Isolated
D6
10,133'
10,153'
9,555'
9,575'
6
20'
06/25/14
Isolated
OPEN HOLE/ CEMENT DETAIL
10-3/4" 156BBL's of cement in 13.5" Hole. Returns to Surface
? 7-5/8" 178BBL's of cement in 9-7/8" Hale. Es[ TOC
2-5/Ir " 5" 1 145BBL's of cement in 6-3/4" Hale. Est TOC
rymek
MIC'm
i
TD=10547'(MD) / 9,969'(TVD)
PBFD=10,461'(MDI / 9,883'(TVD)
Updated by DMA 02-27-19
STATE OF ALASKA
"`S E FIVE
AIL OIL AND GAS CONSERVATION COM SIGN
JAN 1 3 2017
REPORT OF SUNDRY WELL OPERATIONS
OG
1.0 Operations Abandon PlugPerforations
p U U Fracture Stimulate U Pull Tubing U Operations shutdown U
Performed: Suspend ❑ Perforate ❑, Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑
2.Operator 4.Well Class Before Work: 5.Permit to Drill Number:
Name: Hilcorp Alaska,LLC
Development E Exploratory ❑ 214-061
3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number:
Anchorage,AK 99503 50-133-20630-00
7.Property Designation(Lease Number): 8.Well Name and Number:
Hilcorp Fee(Formerly A028142) KBU 23-05
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
N/A Kenai Field/Beluga Upper Tyonek and Tyonek Pool
11.Present Well Condition Summary:
Total Depth measured 10,547 feet Plugs measured 10,045 feet
true vertical 9,969 feet Junk measured N/A feet
Effective Depth measured 10,461 feet Packer measured 5,607 feet
true vertical 9,883 feet true vertical 5,255 feet
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 130' 16" 130' 130'
Surface 1,511' 10-3/4" 1,511' 1,467' 5,210psi 2,489psi
Intermediate 6,108' 7-5/8" 6,108' 5,718' 9,470psi 5,340psi
Production 10,547' 5" 10,547' 9,969' 9,910psi 10,500psi
Liner
Perforation depth Measured depth See Attached Schematic
SCAN
�bA,KN �� QAPR A iLi:.
True Vertical depth See Attached Schematic
Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A
Packers and SSSV(type,measured and true vertical depth) 6"Swell Pkr;N/A 5,607'MD 5,255'ND N/A;N/A
12.Stimulation or cement squeeze summary: N/A
Intervals treated(measured):
N/A ,
Treatment descriptions including volumes used and final pressure: N/A
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 0 3655 1 0 322
Subsequent to operation: 0 3360 3 0 228
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations 0Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑
Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
316-579
Contact Taylor Nasse-777-8354 Email tnasse(a)hilcorp.com
Printed Name Chad Helgeson Title Operations Manager
Signature �`;�,' Phone 907-777-8405 Date C/j2X 7
Form 10-404 Revised 5/2015 ./x�/ E3®�S �� 1f1�1 1 5 2017 Submit Original Only
• 410
Hilcorp Alaska, LLC
Well Operations Summary
Well Name Rig API Number Well Permit Number Start Date End Date
KBU 23-05 E-Line 50-133-20630-00-00 314-377 11/30/16 12/1/16
Daily Operations:
11/30/2016-Wednesday
PTW and JSA. Mobe to location and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high. TP 1,500 psi. RIH w/
2-7/8" x 30' Connex HC, 6 spf, 60 deg phase perf gun and tie into SLB RST Log dated 17-Jun-2014.Tagged fill at 9,921.5'.
Ran correlation log and send to town. Correlation log was 2' deep from proposed depth (Proposed depth 9,883' to
9,853'). Spotted shot from 9,851'to 9,881' (Per Jason E.). Bled tubing down from 1,900 psi to 915 psi and fired gun.
POOH and just the top 10'fired. Troubleshoot gun as much as they could on location. Decided to take gun back to shop
and reload with new explosives and meet back in the morning. Rig down lubricator and secure well.
12/01/2016-Thursday
PTW and JSA. Mobe to location and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high.TP 1,445 psi.
Change out batteries in crane truck. RIH w/2-7/8" x 20' Connex HC, 6 spf, 60 deg phase perf gun and tie into SLB RST Log
dated 17-Jun-2014. Tagged fill at 9,921.5'. Ran correlation log and send to town. Correlation log was 2' deep from
proposed depth (Proposed depth 9,883' to 9,863'). Spotted shot from 9,861'to 9,881' (Per Jason E.). Bled tubing down
from 1,850 psi to 906 psi and fired gun. POOH.All shots fired. Note: Tubing pressure stayed around 1,450 psi until gun
got across perfs and pressure built from 1,446 psi to 1,761 psi (38 min) while we tagged fill and ran correlation log.
When we fired gun it rocked the truck like there was no or very little fluid in hole. RIH w/2-7/8"x 10' Connex HC, 6 spf,
60 deg phase perf gun and tie into SLB RST Log dated 17-Jun-2014. Tagged fill at 9,921.5'. Ran correlation log and send to
town. Get ok to perf from 9,806' to 9,816'. Spot and fire gun with 1,432.3 psi on tubing. After 5 min pressure was 1,439.3
psi. POOH.All shots fired. Gun was dry. Rig down lubricator and equipment.Turn well over to field.
12/02/2016- Friday
No activity to report.
12/03/2016-Saturday
No activity to report.
12/04/2016-Sunday
No activity to report.
12/05/2016- Monday
No activity to report.
12/06/2016-Tuesday
No activity to report.
. 11
• . Kenai Gas Field
SCHEMATIC Well: KBU 23-05
Last Completed: 07/19/14
Hilcorp Alaska,LL€ PTD: 214-061
CASING DETAIL
RKB:MSL=18.6'
Size Type Wt/Grade/Conn ID Top Btm
16" Conductor 109/X-56/Weld 16" Surf 130'
10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7/P-110/BTC 6.875 Surf 6,108'
16" 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,547'
JEWELRY DETAIL
10-3/4" • No Depth Item
a I
1 5,607' 5"Swell Packer
2 7,116' RA Marker with 5'Pup
3 7,444' RA Marker with 5'Pup
•
4 9,029' RA Marker with 5'Pup
5 10,045' CIBP
PERFORATION DETAIL
. Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Date Status
'‘,: D3A 9,808' 9,818' 9,230' 9,240' 6 10 07/01/14 Open
• 9,806' 9,816' 9,228' 9,238' 6 10 12/01/16 , Open
9,847' 9,854' 9,269' 9,276' 6 7 07/19/14 Open
D3B 9,854' 9,870' 9,276' 9,292' 6 16 07/01/14 Open
9,851' 9,881' 9,283' 9,303' 6 20 12/01/16 Open
9,870' 9,880' 9,292' 9,302' 6 10 07/19/14 Open
• 05 10,072' 10,087' 9,494' 9,509' 6 15' 06/26/14 Isolated
D6 10,133' 10,153' 9,555' 9,575' 6 20' 06/25/14 Isolated
s.
t•
1 OPEN HOLE/CEMENT DETAIL
10-3/4" 156BBL's of cement in 13.5"Hole.Returns to Surface
' 7-5/8" 178BBL's of cement in 9-7/8"Hole.Est TOC @ 1,500'
7-5/8 A IL 5" 145BBL's of cement in 6-3/4"Hole. Est TOC @ 3,500'
02
33
34
Tyanek
D3D-D6
5 I: 3.-
5" a &'
TD=10,547'(MD)/9,969'(TVD)
PBTD=10,461'(MD)/9,883'(TVD)
Updated by DMA 01-12-17
• •
oFTit
0 \ Iy7:.4N THE STATE Alaska Oil and Gas
0 T AS�
Conservation Commission
ti ►.. ���a fjLl l
Sr��= 333 West Seventh Avenue
Anchorage, Alaska 99501-3572
�^R, GOVERNOR BILL WALKER g
Main: 907.279.1433
ALAS Fax: 907.276.7542
www.aogcc.alaska.gov
Chad Helgeson
Operations Manager e' r;,
Hilcorp Alaska, LLC s tiNED iRt' a 20!`
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: Kenai Field, Beluga Upper Tyonek and Tyonek Pool, KBU 23-05
Permit to Drill Number: 214-061
Sundry Number: 316-579
Dear Mr. Helgeson:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
/4
Daniel T. Seamount, Jr.
Commissioner
DATED this /7 day of November, 2016.
RBDMS o- NOV 2 8 2816
• 0
RECEIVED
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 8 2016
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280 �-�+
1.Type of Request: Abandon 111 Plug Perforations❑ Fracture Stimulate El Repair Well ❑ e iib s utdown❑
Suspend ❑ r'-Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑
2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number:
Exploratory ❑ Development E . 214-061 '
3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number:
Anchorage,Alaska 99503 50-133-20630-00 •
7.If perforating: 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? CO 510 4-l-rr1-4-*'
•
Will planned perforations require a spacing exception? Yes ❑ No E KBU 23-05
9.Property Designation(Lease Number): 10.Field/Pool(s):
Hilcorp Fee(Formerly A028142) ' Kenai Field/Beluga Upper Tyonek and Tyonek Pool •
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD):
10,547' , 9,969' • 10,461' 9,883' 1,988 psi 10,045' N/A
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 130' 16" 130' 130'
Surface 1,511' 10-3/4" 1,511' 1,467' 5,210psi 2,480psi
Intermediate 6,108' 7-5/8" 6,108' 5,718' 9,470psi 5,340psi
Production 10,547' 5" 10,547' 9,969' 9,910psi 10,500psi
Liner
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
See Attached Schematic See Attached Schematic N/A N/A N/A
Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft):
5"Swell Packer and N/A 5,607(MD)/5,255(ND)and N/A
12.Attachments: Proposal Summary Q Wellbore schematic U 13.Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E Service ❑
14.Estimated Date for 15.Well Status after proposed work:
Commencing Operations: November 21,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑
16.Verbal Approval: Date: GAS LI. WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. I hereby certify that the foregoing is true and the procedure approved
herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354
Email tnassea,hilcorp.com
Printed Name Chad HelgesonesTitle Operations Manager
Signature ( �Z/d /� Phone 907-777-8405 Date J//]// (p
/// COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
V- 'I 114 k
Post Initial Injection MIT Req'd? Yes ❑ No IT
Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6:LI V Y
illRBDMS i NOV 2 9 20.16
APPROVED BY f
Approved by: COMMISSIONER THE COMMISSION Date: 1/ 7t/�
/(41.1(9
Submit Form and
Form 10-403 Revised /2015Rpil00 ti i valid for 12 months from the date ofapproval.` Attachments in Duplicate
0 Ea� I/:/0_ %w
.11 • •
Well Prognosis
Well: KBU 23-05
Hilcory Alaska,LL Date:11/07/2016
Well Name: KBU 23-05 API Number: 50-133-20630-00
Current Status: Producing Leg: N/A
Estimated Start Date: November 21st,2016 Rig:
Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd:
Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-061
First Call Engineer: Taylor Nasse (907)777-8354(0) (907)903-0341(C)
Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(C)
AFE Number:
Maximum Expected BHP: —2,908 psi @ 9,202'TVD (PBU on 04/21/16)
Max. Predicted Surface Pressure: — 1,988 psi (0.10 psi/ft gas gradient)
Brief Well Summary
KBU 23-05 was drilled and completed June 2014. It was initially completed in the D6 and D5 sands, however
these were found to be unproductive and were plugged back.The well is currently completed in the D3A and
D3B sands.
The purpose of this work/sundry is to re-perforate the existing Tyonek intervals.
E-Line Procedure
1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low.
2. If necessary, bleed pressure down or add pressure as requested by the RE to establish a drawdown on
the formation.
3. Perforate the Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns. All intervals are planned for 12
SPF so each zone may be shot twice. Send the correlation pass to the Operations Engineer, Reservoir
Engineer, and Geologist for confirmation.
Gross Proposed Perforated Intervals
Sands Top(MD) Btm (MD) FT
Tyonek D-3A ±9,806 ±9,816 ±10 ,
Tyonek D-3B ±9,853 ±9,883 ±30
4. POOH.
5. RD a-line.
6. Turn well over to production.
Attachments:
1. Current and Proposed Wellbore Schematic
• Kenai Gas Field
Well: KBU 23-05
1E4 •
SCHEMATIC Last Completed: 07/19/14
Hilcorp Alaska,LLC PTD: 214-061
CASING DETAIL
RKB:MSL=18.6'
Size Type Wt/Grade/Conn ID Top Btm
16" Conductor 109/X-56/Weld 16" Surf 130'
10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7/P-110/BTC 6.875 Surf 6,108'
16" 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,547'
JEWELRY DETAIL
10-3/4" No Depth Item
a
1 5,607' 5"Swell Packer
2 7,116' RA Marker with 5'Pup
3 7,444' RA Marker with 5'Pup
4 9,029' RA Marker with 5'Pup
5 10,045' CIBP
PERFORATION DETAIL
Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Date Status
D3A 9,808' 9,818' 9,230' 9,240' 6 10 07/01/14 Open
9,847' 9,854' 9,269' 9,276' 6 7 07/19/14 Open
D3B 9,854' 9,870' 9,276' 9,292' 6 16 07/01/14 Open
9,870' 9,880' 9,292' 9,302' 6 10 07/19/14 Open
D5 10,072' 10,087' 9,494' 9,509' 6 15' 06/26/14 Isolated
D6 10,133' 10,153' 9,555' 9,575' 6 20' 06/25/14 Isolated
•
1 OPEN HOLE/CEMENT DETAIL
10-3/4" 156BBL's of cement in 13.5"Hole.Returns to Surface
7-5/8" 178BBL's of cement in 9-7/8"Hole.Est TOC @ 1,500'
7-5/8" A 5" 145BBL's of cement in 6-3/4"Hole. Est TOC @ 3,500'
02
33
3a
Tymek
D3D-D6
5 •
5" A 4
TD=10,547'(MD)/9,969'(TVD)
PBTD=10,461'(MD)/9,883'(TVD)
Updated by DMA 08-07-14
• PROPOSED •
Gas Field
Well: KBU 23-05
. n
SCHEMATIC Last Completed: 07/19/14
xacorn Alaska.LLC PTD: 214-061
CASING DETAIL
RKB:MSL=18.6'
Size Type Wt/Grade/Conn ID Top Btm
16" Conductor 109/X-56/Weld 16" Surf 130'
10-3/4" Surface 45.5/L-80/BTC 9.950 Surf 1,511'
7-5/8" Intermediate 29.7/P-110/BTC 6.875 Surf 6,108'
16" 5" Production 18/L-80/DWC/C-HT 4.276 Surf 10,547'
JEWELRY DETAIL
No Depth Item
10-3/4" . ii
1 5,607' 5"Swell Packer
2 7,116' RA Marker with 5'Pup
3 7,444' RA Marker with 5'Pup
4 9,029' RA Marker with 5'Pup
5 10,045' CIBP
PERFORATION DETAIL
Sand Top(MD) _ Btm(MD) Top(TVD) Btm(TVD) SPF Ft Date Status
9,808' 9,818' 9,230' 9,240' 6 10 07/01/14 Open
D3A
9,806' 9,816' 9,228' 9,238' 12 10 TBD Proposed • '
9,847' 9,854' 9,269' 9,276' 6 7 07/19/14 Open
D3B 9,854' 9,870' 9,276' 9,292' 6 16 07/01/14 Open
9,853' 9,883' 9,275' 9,305' 12 30 TBD Proposed -
9,870' 9,880' 9,292' 9,302' 6 10 07/19/14 Open
D5 10,072' 10,087' 9,494' 9,509' 6 15' 06/26/14 Isolated
D6 10,133' 10,153' 9,555' 9,575' 6 20' 06/25/14 Isolated
OPEN HOLE/CEMENT DETAIL
1
10-3/4" 156BBL's of cement in 13.5"Hole.Returns to Surface
7-5/8" 178BBL's of cement in 9-7/8"Hole.Est TOC @ 1,500'
7-5/8" a ii 5" 145BBL's of cement in 6-3/4"Hole. Est TOC @ 3,500'
02
M 3
04
Tyoiek
D3D-DB
5
5" a 4
TD=10,547'(MD)/9,969'(T1/D)
PBTD=10,461'(MD)/9,883'(ND)
Updated by TWN 11-07-16
• • 21 4061
Seth Nolan Hilcorp Alaska, LLC 2 7 9
GeoTech 3800 Centerpoint Drive, Suite 100
Anchorage, AK 99503
Tele: 907 777-8308
itarnrr t a4kw.I.L( Fax: 907 777-8510
E-mail: snolan@hilcorp.com
DATA LOGGED
5 /2#/201fe
M K.BENDER
DATE 05/17/16
To: Alaska Oil & Gas Conservation Commission
Makana Bender
Natural Resource Technician II RECEIVED
333 W 7th Ave Ste 100
Anchorage, AK MAY 2 0 2016
99501
DATA TRANSMITTAL AOGCC
KBU 23-05 sem4HEQ JUN 1 Q 2016
Production profile and digital data
Prints:
Production Profile (GR/CCL/PRE/TEP/PGMS/ILS/DEFT/FBS/X-Y CAL)
Production Log Interpretation Report
CD1: Elog digital data
DLIS Data 4,14/2016 10:35 AM File folder
s LAS Data 4,'14,2016 10:35 AM File fold er
Log Data 4,/4,20161035 AM File folder
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337
Rece y: }2� Date:
410 • 21 4661
27 193
' Company HILCORP ALASKA, LLC
' Hilrnrp Alaska,LL(:
Well Name KBU 23-05
I
Field Name KENAI BELUGA UNIT
t
State ALASKA
Location 98' FSL & 808' FEL Schlumberger
Logged by E. Horst
' Logging Date 9-Apr-2016
Report Date 14-Apr-2016 RECEIVED
MAY 202016
Prepared By Peter Lywood ®GV
�
Trip Number
' Run Number 1
1
1
Production Services Platform
1
Production Log Interpretation Report
' SIS
• •
1 INTERPRETATION SUMMARY 3
1.1 INTRODUCTION 3
1.2 OBJECTIVES 3
1.3 TECHNIQUE 3
2 DATA QUALITY AND INTERPRETATION COMMENTS 3
3 TABLE 1:PRODUCTION AT STANDARD CONDITIONS 4
4 TABLE 2:PRODUCTION AT RESERVOIR CONDITIONS 4
5 INTERPRETATION PROFILE 5
6 INTERPRETATION PROFILE DETAIL 6
7 BASIC SENSORS AND MATCH DATA 7 '
8 TABLE OF ABBREVIATIONS 8
9 WELL AND JOB DATA 9
9.1 WELL SCHEMATIC 9
9.2 SPINNER CALIBRATION 10
9.3 TOOL STRING 11
10 APPENDIX Z:ZONE COLOR CODE 12
1
1
1
KBU 23-05 1 of 12 14/04/2016 '
I • •
IDISCLAIMER
ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR
RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED
I BY SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES
ARE OPINIONS BASED ON INFERENCES FROM MEASUREMENTS, EMPIRICAL
RELATIONSHIPS AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL
I RELATIONSHIPS AND/OR ASSUMPTIONS ARE NOT INFALLIBLE, AND WITH RESPECT TO
WHICH PROFESSIONALS IN THE INDUSTRY MAY DIFFER. ACCORDINGLY,
SCHLUMBERGER CANNOT AND DOES NOT WARRANT THE ACCURACY, CORRECTNESS
I OR COMPLETENESS OF ANY SUCH INTERPRETATION, RESEARCH, ANALYSIS, DATA,
RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER ACKNOWLEDGES THAT IT IS
ACCEPTING THE SERVICES "AS IS", THAT SCHLUMBERGER MAKES NO
REPRESENTATION OR WARRANTY, EXPRESS OR IMPLIED, OF ANY KIND OR
IDESCRIPTION IN RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES
THAT SCHLUMBERGER DOES NOT WARRANT THAT ANY INTERPRETATION, RESEARCH,
ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION IS FIT FOR A
I PARTICULAR PURPOSE, INCLUDING BUT NOT LIMITED TO COMPLIANCE WITH ANY
GOVERNMENT REQUEST OR REGULATORY REQUIREMENT. CUSTOMER FURTHER
ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE EXPLICIT
I UNDERSTANDING AND AGREEMENT THAT ANY ACTION TAKEN BASED ON THE
SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBILITY AND NO CLAIM
SHALL BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEREOF.
I
I
I
I
I
I
I
I
I
I
I
KBU 23-05 2 of 12 14/04/2016
• •
1 Interpretation Summary
1.1 Introduction '
A production log was run in the KBU 23-05 well on 9-APR-2016 using PSP (Production Services
Platform).
1.2 Objectives
Production log was recorded in the KBU 23-05 with following objective:
1. Obtain a production profile to identify gas and water entries from the D3A and D3B sands.
1.3 Technique
A 1 11/16" surface read out production logging tool was deployed on wireline. The well bore has a
maximum deviation of 1.45 deg over the logged interval. The sensors present are Casing Collar
Locator, Pressure, Temperature, Gamma-Ray, DEFT, PILS spinner, PFCS spinner and
Gradiomanometer. There are three up and three down passes logged at 40, 80 and 120 ft/min
along with 21 station stops.
2 Data Quality and Interpretation Comments
The majority of hydrocarbon (56%) is produced from the D3B sand, followed by 44% from the D3A '
sand. Qualitatively minor water holdup is observed entering the wellbore at the D3A sand but it
quickly disappears above the interval and is too small to quantify. No water production is observed
from the D3B sand. The first hydrocarbon entry is at 9879 ft.
The logged interval is approximately 9191 to 9932 ft. In general the data quality was very good
with only a portion of the 120 ft/min up pass spinner above the perfs being disallowed for the
velocity calculation. The full-bore spinner clearly identifies the wellbore inflows. The inline spinner
data was not representative and may have been clogged with debris. The inline spinner was not
used to calculate a velocity. The spinner data produced valid downhole calibrations and the
reported rate is based on the recorded data and was not normalized to the reported surface rate.
The DEFT data is of good quality and clearly identifies the transition from water in the wellbore
sump to hydrocarbon at 9879 ft. The DEFT identifies minor water entry on all probes at -9812 ft
but this water quickly disappears from probe detection above the interval. This water is also
identified by the density but again quickly disappears from detection and is too small to be
quantified. '
The combined calipers (C1 C2) read 4.35"; the nominal ID (4.276") was used as input to the
interpretation. The caliper data does not identify any anomalies. '
Measured Production at Standard Conditions Gas = 3.51 MMscf/Day
1
KBU 23-05 3 of 12 14/04/2016
I • •
3 Table 1: Production at Standard Conditions
Zones Water Oil Cas
ft STB/D STB/D MMscf/D
ID3A(9808.0-9818.0) 0.00 0.00 1.57
D3B(9847.0-9852.1) 0.00 0.00 0.15
I
D3B(9853.6-9869.0) 0.00 0.00 1.38
03B(9871.0-9880.0) 0.00 0.00 0.40
ITotal (inc. Bottom) 0.00 0.00 3.51
I4 Table 2: Production at Reservoir Conditions
I Zones Cot res. Production
ft McfID %
D3A(9808.0-9818.0) 29.64 43.89
I
D3B(9847.0-9852.1) 2.99 4.43
D3B(9853.6-9869.0) 27.00 39.99
D3B(9871.0-9880.0) 7.90 11.70
IContributions by phase
I Zones Ow res. Qa res Qg res.
ft Mcf�C Mcf1G Mcf/D U W U 0 U G
I D3A(9808.0-9818.0) 0.00 0.00 29.64 -„-
03B(9847.0-9852.1) 0.00 0.00 2.99 II
D3B(9853.6-9869.0) 0.00 0.00 27.00
ID3B(9871.0-9880.0) 0.00 0.00 7.90
I
I
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I
I
I
I
KBU 23-05 4 of 12 14/04/2016
•
1
INTERPRETATION PROFILE • KBU 23-05
Schlumberger Company: Hilcorp Alaska, LLC Test:
I
Field: Kenai Beluga Unit Date: 9-APR-2016
Well: Kenai Beluga Unit 23-05 Survey: FLOWING
GR SCVL CCLD DepthZ WPRE WTEP WFDE DN PASSES SPIN QZT QZI
0 GAPI150 -140ft/min 140 -6. 4 (ft) 800psia850 110 °F 165 -0.2g/cc 1.2 0 mull 1 -30 rps 90 ... ... I I I 1 II
- - 1 I
,
t
�J206 I i
•
p
iL-- _ _
•
1 -9300
Ii
•
E
•
I
4
IP
W0
- -
i
i
'9506 3
•
•
9606 I
- - I
•a
9706
•
_ _ I
fY
oi i6 9806 E
H
Ci ,?ip
0 0 - - • ill
�� ®. (, -- ''.d
�► _ • ---
fi €� E
to ii is b_ • LIM
:lih /44 Iti0 i.01
a '
IIP ii,
I
.:1.„. .
KBU 23-05 5 of 12 14/04/2016
I
I
INTERPTATION PROFILE DETAIL1111 KBU 23-05
IISchlumberger Company: Hilcorp Alaska, LLC Test:
Field: Kenai Beluga Unit Date: 9-APR-2016
Well: Kenai Beluga Unit 23-05 Survey: FLOWING
IGR Depth Z WPRE WTEP WFDE DN PASSES SPIN QZI
0 GAPI 150 (ft) 800 psia 850 110 °F 165 -0.2 g/cc 1.2 0 1 -30 rps 90 -2 Mcf/D 34
' --
I --
�;" Statio Data — —_
I , - _
4,. 111 °
I.
t� 0 „ P
•
'' Small water
9800 O ( i>
1 � 0
,; entry
1
4 - ``` I S9
• 41, I pp — ��
o !� /
tj"® - - 0 0 I0
I
e
Small Ovate,,
`t, - - O 4! entry.' ,ilie
tw,
fn 0 lii I
0 - - ��e
Si i °
— — ;°
i'
qo
I
II
4
(/1
I 9 9900 •
rI ;I
III
I 1,1 Moving pass d. II
it
Dashed line=
- - Solid line=dn
1
; I Dashed=up pass
i i - - Solid Zine=dn
I
KBU 23-05 6 of 12
14/04/2016
0 0
Basic PSP Sensors and Match Data KBU 23-05
Willow Company: Hilcorp Alaska, LLC Test:
Field: Kenai Beluga Unit Date: 9-APR-2016
I
Well: Kenai Beluga Unit 23-05 Survey: FLOWING
GR C1C2 SCVL Depth Z WFDE WTEP WPRE Density match:ter holdup ma Velocity match
0 GAPI 150 3. in 5 -140ft/min 140 (ft) -0.2 g/cc 1.2 110 °F 165 800 psia 850 -0.2 g/cc 1.2 -0.2 1.2 -50 ft/min 750
WFDE S1,11 _FLV S1,I1VASPIN S1,11
VFDEZ-> S1,1 - ASPINZ-> S1,1 1
. 0 0 0 0
1 I I
I1
iI-
... 1 .
I
I
C . i 9700
.• ,
..
1
c i il I
,
-.,
,
I
,
.4-.. 1 1 . ..
, 1 111
1 I
C%. I
i
4(2f
I — — S all water State n Data 1
I _ _ entry
6 a ' ..
4 6 - - 0
lrz,
, o 0
9800 . .k .. I
— V o
i
4 0 41 11,\, 0 '
,.
, ?
•__,,__:;,... 0 > /
I
o 0
,.,
,
. ,- 1 o , 4) 0 . - ..
I!) (I) 11 41 0 ' In
0 f 0 - _ o4)
.. I
il
T
r .
,
4) I e )
. 0
-
?...- I
— — i 10 4/ D •
, '\t '; .
.. . .
4 1 e
— \\
; I 1
9900
jI
it I
. 1
..,
14, ,
,
,
, Moving c I
I - - Dashed line
' (
s,\ Solid lined
- - Ii
KBU 23-05 7 of 12 14/04/2016
I
I • •
8 Table of Abbreviations
I
Tool
Mnemonic Channel Description
Units: Description CVEL Cable velocity
CCLD/
I
B/D Barrels per Day CCLC Casing Collar Locator Discriminated/Calibrated
DFB1/2/3/
scf/bbl Standard Cubic Feet per Barrel 4 DEFT bubble count per probe
I
DFH1/2/3/
cp Viscosity centipoises 4 DEFT water holdup per probe
ft/m Feet per minute SCV1 Depth corrected cable speed to in-line spinner
g/cc Grams per cubic centimeter SCVL Depth corrected cable speed to spinner
I
MMSCF/D Million Standard Cubic Feet per Day GHHM2 Field calculated combined gas holdup
MSCF/D Thousand Standard Cubic Feet per Day DFHM Field calculated combined water holdup
Res. To denote reservoir conditions(downhole) MW FD Field pressure derived density
I rps Revolutions per second GR Gamma Ray
GHB1 /2/3/
S.C. To denote surface conditions(uphole) 4 GHOST gas bubble count per probe
GHH1/2/3/
I
SCF Standard Cubic Feet 4 GHOST gas holdup per probe
STB/D Stock Tank Barrels per Day SPI1 In-line spinner
WPRE Pressure
I
PVT: Pressure Volume Temperature
Oil volume factor DPHZ Pressure derived density(from Emeraude)
Bo PFC1/PFC2 PSP Caliper 1 and Caliper 2
Bw Water volume factor Q Rate
Relative bearing for probe 1 of second tool
I
Bg Gas volume factor D1 RB2 (GHOST)
FVF Fluid volume factor D1 RB Relative bearing of probe 1
GOR Gas Oil Ratio SPIN Spinner(fullbore or turbine)
I
Holduput Ratio of produced water to total fluids WTEP Temperature
Holdup Fraction of fluid present in an interval of pipe TENS Tension
Uncorrected Fluid Density(from
UWFD gradiomanometer)
I
Interpretation: WFDE Well fluid density(from gradiomanometer)
Correlation Model L-G:Liquid Gas W-H:Water
Correl. Hydrocarbon;O-W Oil-Water
I ID Internal Diameter PSP Production Services Platform
Q Cumulate Rate with continuous solution DEFT Digital First Entry Tool(Water holdup)
QZI Incremental rate per zone GHOST Gas Holdup Optical Sensor Tool(Gas holdup)
QZT Cumulative Rate track with zonal contribution
I Regime Modeled Spinner Calibration:
Slope of rps/(ft/m). Defines conversion of
YG Gas Holdup Slope spinner to velocity.
I YO Oil Holdup Int Intercept of line of slope(defines velocity)
Difference between up/down passes. This is the
YW Water Holdup Threshold velocity required to initiate rotation of the spinner.
I
YW_FLV Water Holdup from DEFT
Z Zone:
Yellow-spinner calibration
Red-Perforation
I
White-Inflow Zones
Gray:Calculation(stable)zone
I
I
I
KBU 23-05 8 of 12 14/04/2016
• • I
9 Well and Job Data
I
9.1 Well Schematic
II Kenai Gas Field
Well: KBU 23-05
SCHEMATIC Last Completed:07/19/14
Mowry Marks.IAA: PTD:214 061 I CASING DETAIL
RKB:NEL-165 Size Type Wt/Grade/Conn ID Top Btm
li 16" Conductor 109/X-56/Weld 16' Surf 130' I 10 3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,511'
5/8" Intermediate 297/P-110/BTC 6.875 5url 6,108'
5" Production 28/L-80/OWC/C-HT 4,276 Surf 10,547'
JEWELRY DETAIL
"co Depth !tem
• .
1 5,607' S"Swell Packer
I
' 1,116" RA Marker with S'Pup
3 7,444' RA Marker with 5'Pup
4 9,029' RA Marker with 5'Pup
S 10,045' - 08P
I
PERFORATION DETAIL
, -,z1 Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF !t Date Status
I
-_P. , 9,808' 9,818' 9,230' 9,240' 6 i 07/01/14 Open
9,841' 9.854' 9,269' 9,276' 6 07/19/14 Open
_= 9,854 9,870' 9,276' 9,292' 6 16 07/01/14 Open
9,870 9,880' 9,292' 9,302' 6 10 07/19/14 Open I
D. 10,072 10,087' 9,494' 9509' 6 15' 06/26/14 Isolated
__ 10,133' 1i:.11,3' 9,SS1,' 9575' 6 20 06125/14 Isolated
I
OPEN HOLE/CEMENT DETAIL
10-3/4" 336881'5 of cement in 133"Mote.Returns to Surface
I
7-S/8" 178881's of cement in La 9-7/8'Hole.Est TOC 1,500'
I S" 145881's of cement in 6-3/4"Hole. Est TOC 8113.500'
I
b=
I
'4 I
u
TtI- ?0.�L78
1
TD=1D,547'(hIID)/9,969'(T1ID)
PBTD=10,4611ND)/9,863'(TVD)
I
KBU 23-05 9 of 12 14/04/2016
I
I 0 •
I
I9.2 Spinner Calibration
I Zr-, I Rem:9822.40 To:98422R
-.::- _tj Pews tore
Scow(-4
kint(..) 0.115 onsfido
-310.8413/m
1 i_:iil Roos(-) NIA
I
kW-irgi Olt/rfon
Ow Poirto 0
I , '-' -'-. 32iI3) .
R2 0.98
-Tod
10
DieltI4 I our.,
IIhesh0 I 011Ain
e,r)
-lin -400 400 ON
/A limills 1
I / cr".
-20
. -30
I -40
-00
I
TS vefsus ftrtnin .
I -0
I
I
I
I
I
I
I
IKBU 23-05 10 of 12 14/04/2016
• •
9.3 Tool String
Equip name Length MP name Offset
I
MH-22 29.85
it
illi
AN-38 28.18 I
SAH-G 28.00
EQF-46 26.68
I
I
I
PSTP-A:80 20.68 •r GR 16.98 I 2 /IPSTC 16.68
PSC-A802 7,PSTC Too 0.00
PSTC-A813 r'// I String B
PBMS 4:&02 f/� ottom
5an:,i-d a / Tempera 13.89 I
kP_.= ture
Sapphire .78
Pressure
r CCL 1313.17 I
t,;,,,,,,///
; PBMS 12.42
Inline Sp 6.04
Inner
PGMC-8:72 12.42 ` I
4 7 Gradioma 10.91
PGMC-E:724 nometer
PSOI_Gratiii `----Accelero 10.91
I
0:4957 meter
Acceiero:}2
4
1_____-PGMC 7.67
PAS-A:75 7.67
1 n
PAS-A:751 ,1 I Spinner 6.04
P,i—
111-AS.ld
PFCS-A:80 5.14 I 7
PFc -A:807
EPR08E[4]
I Spinner 1.87
/Caliper 1.87
SPIt�4TrIER_2. r l Probes 1.48
�R0�1] %, t.f IPFCC-A 0.00
/,Relative 0.00
I
k.:' Bearing
TOOL_ZERO
Lengths ale in ft
Maximum Outer Diameter= 2.125 in
I
Line:Sensor Location,Value:Gating Offset
All measurements are relative to TOOL ZERO
I
KBU 23-05 11 of 12 14/04/2016
I
I e •
I10 APPENDIX Z: Zone Color Code
APPENDIX : Z TRACK COLOUR CODING
Depth Z
I (m)
I
I
I
I
I Spinner
I calibrations
- ..
zones are - mil
_
I shown in
ME
Mill
1.a
yellow.
I -4701 III Linear inflow
I Perforati2 il ! zones shown
ons
in white.
I I
I are shown
in red. . ili
-4800 1 1
I WI Stable rate
I 11
1 1 ''' ‘.,,,,, zones
I _ iii
I 1 shown in
I
-4904 grey.
I
IKBU 23-05 12 of 12 14/04/2016
KBU 23-05
Kenai Beluga Unit
Kenai Borough, Alaska
May 24, 2014 – June 12, 2014
Provided by:
Approved by: Sarah Rittenhouse Compiled by: Ralph Winkelman
D y l a n M u l l e r
Distribution Date: 7/1/2014
KBU 23-05
2
TABLE OF CONTENTS
1 MUDLOGGING EQUIPMENT & CREW ................................................................................................3
1.1 Equipment Summary ......................................................................................................................3
1.2 Crew................................................................................................................................................3
2 GENERAL WELL DETAILS...................................................................................................................4
2.1 Well Objectives...............................................................................................................................4
2.2 Hole Data........................................................................................................................................5
2.3 Daily Activity Summary...................................................................................................................5
3 GEOLOGICAL DATA.............................................................................................................................7
3.1 Lithostratigraphy .............................................................................................................................7
3.2 Lithological Details..........................................................................................................................8
3.3 Sampling Program........................................................................................................................15
4 DRILLING DATA..................................................................................................................................16
4.1 Surveys.........................................................................................................................................16
4.2 Bit Record.....................................................................................................................................21
4.3 Mud Record ..................................................................................................................................22
4.4 Drilling Progress Chart..................................................................................................................23
5 DAILY REPORTS ................................................................................................................................24
Enclosures
2” / 100’ Formation Log (MD/TVD)
5” / 100’ Formation Log (MD/TVD)
2” / 100’ LWD Combo Log (MD/TVD)
2” / 100’ Drilling Dynamics Log (MD/TVD)
2” / 100’ Gas Ratio Log (MD/TVD)
Final Data CD
KBU 23-05
3
1 MUDLOGGING EQUIPMENT & CREW
1.1 Equipment Summary
Parameter Equipment Type / Position Total
Downtime Comments
Computers – Surface Logging (5) Rigwatch Server, Rigwatch Remote
DML, LWD WITS, Rigwatch Remote 0 hours
Ditch gas QGM gas trap; Flame ionization total
gas & chromatography.
Hook Load / Weight on bit WITS from Pason 0 hours
Mud Flow In Derived from Strokes/Minute and
Pump Output 0hours
Mud Flow Out WITS from Pason 0hours
Pit Volumes, Pit Gain/Loss WITS from Pason 0hours
Pump Pressure WITS from Pason 0 hours
Pump Stroke Counters (2) WITS from Pason 0 hours
Rate of Penetration Calculated from Pason 0 hours
RPM WITS from Pason 0 hours
Torque WITS from Pason 0 hours
WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 hours
1.2 Crew
Mud Logging Unit Type: Arctic
Mud Logging Unit Number: ML057
Mud Loggers Years1 Days2 Sample
Catchers Years1 Days2 Technician Days2
Ralph Winkelman 23 16 Deb Bomar 3 18
Dylan Muller 4 18 Elijah Callan 0 18
*1 Years experience as Mudlogger
*2 Days at wellsite between rig up and rig down of logging unit.
KBU 23-05
4
2 GENERAL WELL DETAILS
2.1 Well Objectives
KBU 23-05 is permitted as a grass roots Multiple Zone Development Gas well in the Kenai Beluga Gas
Unit, Pad 41-07. The well is planned to be directionally drilled, with a minimum of hole or other problems,
in a NE direction to 10163’ MD/ 9530’TVD planned, ( 10547’MD/ 9969’TVD actual). The KBU 23-05 will
target the Mid-Lower Beluga and Upper Tyonek reserves on the eastern flank of the field. The base plan is an
“S” shaped well bore with a shallow kick off in the surface hole and then dropping back to vertical in the
production hole section.
Operator: HILCORP ALASKA, LLC
Well Name: KBU 23-05
Field: Kenai Beluga Unit
County: Kenai Borough
State: Alaska
Company Representatives: Mike Leslie, Bob Farrell, Doug Yessak, James Lott
Location: Surface Coordinates 98' FSL, 808' FEL, Sec 6, T4N, R11W, SM, AK
Ground ( Pad ) Elevation 66.5’
Rotary Table Elevation 84.6’
Classification: Development - Gas
API #: 50-133-20630-00-00
Permit #: 214-061
Rig Name/Type: Saxon 147/ Land/ Double
Spud Date May 22, 2014
Total Depth Date: June 7, 2014
Total Depth 10,547 MD
Primary Targets Middle and Lower Beluga and Upper Tyonek Gas Pools
Primary Target Depths D2 9502’ MD/8860TVD, D3 9751’ MD/ 9110’TVD, D4 9993’
MD/9350’TVDTotal Depth Formation: Tyonek
Completion Status: Run, Set and Cement 5” Liner to surface.
LWD-MWD Services. Halliburton/ Sperry Drilling Services
Directional Drilling Halliburton/ Sperry Drilling Services
Wireline Logging Services N/A
Drilling Fluids Service M.I. Swaco
CANRIG Logging Geologists: Ralph Winkelman, Dylan Muller
CANRIG Sample Catchers: Deb Bomar, Eli Callan
KBU 23-05
5
2.2 Hole Data
Maximum Depth Shoe Depth Hole
Section MD
(ft)
TVD
(ft)
TD
Formation
Mud
Weight
(ppg)
Dev.
(oinc)
Casing
Diam. MD
(ft)
TVD
(ft)
FIT
(ppg)
13 1/2” 1520’ 1474.9’ Sterling 9.2 21.90 10.75” 1511’ 1466.6’ 12.0
9 7/8” 6118’ 5727.1’ Beluga 9.4 21.87 7.625” 6108’ 5717.8’ 13.5
6 3/4” 10547’ 9969’ Tyonek 12.1 2.09 5” 10353’ 9957’
2.3 Daily Activity Summary
5/24/2014: Rig up Canrig. Test BOP.
5/25/2014: Drill out plugs @ 1424', float collar, cement and shoe @ 1510'. Drilled 20' of new Fm to 1,540'.
Pumped 20 bbl spacer and displaced spud mud with 9.1ppg Kla-Shield. FIT. Drill ahead. Drilled to short
trip point, pumped sweep and prepare to TOH.
5/26/2014: Short trip to casing shoe. Drilled ahead to 4502’. Then made another short trip. Swept hole and
started drilling ahead.
5/27/2014: Drilled to 6118'. TOH to 4500' and will TIH, Pump sweep and then TOH for casing.
encountered tight hole at ~ 5200' Working tight spot from 5200 up to 4700' ~ Tripping back to bottom.
Circulate sweep and will TOH for casing.
5/28/2014: TIH to 4500'. Back ream from 4500 - 4050. Pump from 4050 - 3400. Ream at 520gpm.
Continue POOH. Lay down BHA. Service rig. :level Derrick and track for casing run. Rig up and test
equipment. Test 7 5/8" pipe rams to 250 low and 3500 high. Start RIH with casing
5/29/2014: Continue TIH with casing. At 2916', unable to progress. Made several attempts working pipe
with and without pumps and rotating. Pull casing. Change rams, P/u clean out assembly. RIH, reamed
difficult section. Cont. RIH to 3870'. Still RIH with drill pipe at report time.
5/30/2014: POOH from clean out run. L/D BHA. Change rams and test. R/U csg tools. Run casing.
5/31/2014: RIH with 7 5/8" casing. Land at 6108'. Circulate and condition mud. Rig up cementers. Pump
cement job - started with 37 bbls of 10 ppg spacer, followed by 173 bbls of 10.5 ppg lead cement, followed
by 24 bbls of 13.5 ppg tail cement. The plug was bumped with 260 bbls of 9.5 ppg mud. Rig down
cementers. Clear & clean rig floor. L/D landing joint & CRT. Change rams. Test BOP's.
6/1/2014: Test BOP's. Make up drilling BHA. Shallow test MWD - failed. Trouble shoot MWD. Slip & cut.
Wait on tool. Made up tool and TIH to drill out cement.
6/2/2014: RIH picking up singles. Tag cement at 6024'. Perform casing test - OK. Drill out cement, shoe,
and new formation to 6142'. Perform FIT to 13.5 ppg EMW. Drilling ahead.
6/3/2014: Drilling ahead rotating and sliding to 7444'. CBU. TOH to the shoe. Tight hole from 6450' to
6080' requiring back reaming. Service rig at the shoe. RIH. Tagged bottom, pumped sweep, Drilling.
KBU 23-05
6
6/4/2014: Drilling ahead rotating and sliding. Dropping angle. WOB 8 RPM 80 TORQ 8K GPM 305 SPP
3200. Drill to 8872'. Begin POOH for short trip to shoe. Currently POOH
6/5/2014: Drilling to 8872'. CBU. TOH - Pump out from 7460' to 7450' & 7430' to 7420'. Service rig at the
shoe. RIH, wash down last 2 stands. CBU, 1600 units of gas. Pump sweep around. Drilling ahead sliding
and rotating, to 9133' at report time.
6/6/2014: Drilling ahead: sliding and rotating, while dropping angle. WOB 8 RPM 60 TORQ 8-9K GPM
300 SPP 3400. Perform short trip to confirm wellbore stability - tight spot @ 9343'. TIH to bottom and
sweep hole to circulate. out gas - max gas unit:1800. Continue to drill ahead: sliding and rotating, while
taking survey as per required to 9653' at report time.
6/7/2014: Drilling ahead. Completed slides. WOB 8-10 RPM 70 TORQ 9K GPM 280 SPP 3300. Continue
to drill to section's TD @ 10547', TVD 9969. CBU and Clean hole for trip; take final survey and slow pump
rates. Currently @ 9548' while TOOH at report time.
6/8/2014: Continue to TOH to the shoe. Back ream 10203’ to 10111’. High gas while circulating at the
shoe. Shut in well and circulate through the choke. SICP 260 psi. 8 bbl pit gain. Weight up to 12.1 ppg.
Circulate out high gas. Slip and cut drilling line. RIH stagewise and continue to use recommended well
control practices to circulate out gas while conditioning fluid density to 12.1 ppg.
6/9/2014: RIH on elevators from 7227' to 9300'. Shut in well and circulate out gas (1600 units) while
weighting up to 12.1 ppg. Open well and monitor. Continue to RIH to 10547'. Circulate out gas (2300
units) through flow line. Ream down last stand. Pump sweep around. Simulate connection. CBU. High gas
80 units. Flow check well. Pull 5 stands. Pump slug. POOH to shoe. Monitor well. CBU. POOH laying
down drill pipe. RIH finger's DPs for L/D purpose; 5131' depth as @ report time.
6/10/2014: Continue to lay down 4 1/2" drill pipe. Lay down BHA. Clear rig floor. Held PJSM: R/u Tesco
CRT. Dummy run landing joint. Test upper rams. Held PJSM: Run 5-in casing t/4924' as @ report hour;
breaking circ. every 500' as per DSVs directive.
6/11/2014: Finish running casing to 10535'. Rig up cement tools and cement.
KBU 23-05
7
3 GEOLOGICAL DATA
3.1 Lithostratigraphy
Prognosed and observed tops given by Hilcorp geologist Sarah Rittenhouse. Observed tops determined
after evaluation of Quad-Combo LWD logs.
FORMATION PROGNOSED OBSERVED
MD
(ft)
TVD
(ft)
SSTVD
(ft)
MD
(ft)
TVD
(ft)
SSTVD
(ft)
Sterling 4,126 3,648 (3,581) 3,871 3,651 ‐3,585
Sterling 5.2 4,809 4,249 (4,182) 4,480 4,212 ‐4,146
Upper Beluga 5,352 4,759 (4,692) 5,035 4,723 ‐4,657
Middle Beluga 5,986 5,372 (5,305) 5,686 5,328 ‐5,261
Lower Beluga 6,667 6,040 (5,973) 6,466 6,049 ‐5,982
Upper Tyonek 7,834 7,198 (7,131) 7,709 7,198 ‐7,132
84-6 Sand 9,001 8,396 (8,329) 9,041 8,464 ‐8,398
86-2 Sand 9,212 8,567 (8,500) 9,224 8,646 ‐8,580
D-1 Sand 9,356 8,720 (8,653) 9,358 8,780 ‐8,713
D-2 Sand 9,502 8,860 (8,793) 9,516 8,938 ‐8,872
D-3 Sand 9,751 9,110 (9,043) 9,749 9,171 ‐9,104
D-4 Sand 9,993 9,350 (9,283) 9,977 9,399 ‐9,333
D-6 Sand 10,127 9,490 (9,423) 10,121 9,543 ‐9,477
KBU 23-05
8
3.2 Lithological Details
Full service mudlogging began at 6118’ MD / 5727.1’ TVD. All the sample lithology descriptions provided
by Canrig began after the intermediate casing shoe track. The logged well included the Beluga and
Tyonek Formations, whose lithology of largely volcanic ash-derived fluvial sediments included: tuffaceous
claystone, tuffaceous siltstone, sand/sandstone, volcanic ash, coal and various other minor to trace thinly
bedded lithologies. The wellbore was drilled to 10547’MD / 9969’ TVD.
Tuffaceous claystone/ tuffaceous siltstone (6118' - 6220') = light gray with light brownish gray and light
yellowish gray secondary hues; soft to slightly firm; irregular to shapeless, amorphous cuttings with trace
pdc bit action shaped cuttings; silty to clayey texture; Dull to slightly earthy luster; hydrophilic; moderately
soluble and expansive; Poor cohesiveness; poor to fair adhesiveness; non calcareous; trace thin coal
beds throughout.
Sand (6220' - 6280') = medium light gray overall with individual grains dominantly clear to translucent
quartz and volcanic glass, light to medium gray, medium To dark gray to greenish gray, black and trace
pale rose; very fine lower to trace Coarse lower, dominantly fine upper to lower; angular to subangular; fair
to good sorting; unconsolidated with trace ashy supported sands; very fragile; grayish white to mottled;
very calcareous.
Tuffaceous claystone/ tuffaceous siltstone (6280' - 6340') = light gray to very light gray with light yellowish
gray secondary hues; soft to slightly firm; shapeless to irregular wedge shaped cuttings; silty to clayey
texture; dull, earthy to slightly waxy luster; Moderately soluble and expansive; poor to fair cohesiveness
and adhesiveness; Non calcareous; trace dark brown to black carbonaceous laminations and inclusions.
Sand (6340' - 6400') = medium light gray overall with a strong salt and pepper appearance, individual
grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray to black, dark
greenish gray and trace white; very fine lower to trace coarse upper, dominantly fine lower to medium
lower; angular to trace subrounded, dominantly subangular poor to fair sorting; unconsolidated; Non
calcareous; trace thin coal/ carbonaceous shale beds.
Sand (6400' - 6460') = medium light gray overall with individual grains dominantly clear to translucent
quartz and volcanic glass, light to medium gray, medium To dark gray to greenish gray, black and trace
pale rose; very fine lower to trace coarse lower, dominantly fine upper to lower; angular to subangular; fair
to good sorting; unconsolidated.
Tuffaceous claystone/ tuffaceous siltstone (6460' - 6520') = light gray to very light gray with light yellowish
gray secondary hues; soft to slightly firm; sticky; shapeless to irregular cuttings; silty to clayey texture; dull
to greasy to slightly waxy luster; hydrophilic; moderately soluble and expansive poor cohesiveness; poor
to fair adhesiveness; trace dark brown to black microthin carbonaceous laminations and incl.
Sand (6520' - 6580') = medium light gray overall with a strong salt and pepper appearance, individual
grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray to black, dark
greenish gray and trace white; very fine lower to trace coarse upper, dominantly fine lower to medium
lower; angular to trace subrounded, dominantly subangular poor to fair sorting; unconsolidated; non
calcareous; trace thin coal/ carbonaceous shale beds.
Sand (6580' - 6640') = medium light gray with individual grains dominantly clear to translucent quartz and
volcanic glass medium to dark gray, black, light to dark greenish gray; very fine upper to very coarse
upper, dominantly medium lower to coarse lower; angular to subrounded, dominantly subangular; poor
sorting; unconsolidated; trace thin coal carbonaceous shale beds throughout.
Tuffaceous claystone/ tuffaceous siltstone (6640' - 6700') = medium light to light gray with light brown and
KBU 23-05
9
light brownish gray secondary hues; soft and sticky; irregular shaped cuttings; silty to clayey texture; dull
luster; hydrophilic; poor cohesiveness; poor to fair adhesiveness; non calcareous; trace dark brown to
black microthin carbonaceous laminations and inclusions; trace thin coal beds.
Sand (6700' - 6750') = medium dark grey to medium grey; dominant lower to upper fine, secondary upper
to lower medium sand grains; very well sorted; subangular to subrounded - very even; dominant very
spherical, secondary subspherical; larger grains frosted from impact abrasion, small grains mostly
polished; quartz, secondary lithic clasts of carbonaceous siltstone of similar size, angularity.
Tuffaceous sandstone (6760' - 6815') = medium dark grey to medium grey; lower very fine to lower fine
sand grains, trace lower medium; 95% quartz, 5% lithic clasts; very well sorted; well rounded to
subrounded, secondary subangular; highly spherical to slightly ovular due to contact deformation; slightly
to moderately firm, some easily friable; tuffaceous siltstone matrix supported; mildly calcareous.
Tuffaceous claystone (6810' - 6880') = medium dark grey to medium light grey; malleable to dense
tenacity, mostly amorphic and globular with poor cohesion; blocky to hackly fracture when visible; tabular
to massive cutting habit when visible; earthy to greasy luster; granular to gritty and smooth texture;
massive structure; very arenaceous, grading to argillaceous sandstone of above description.
Sand (6880' - 6935') = medium dark grey to medium grey; lower very fine to lower fine grain, secondary
upper fine to lower medium grains; very well sorted; well rounded to subrounded, secondary subangular
on larger grains; sub spherical, contact deformation, ovular; 90+% quartz, remainder lithic clasts;
imbedded in tuffaceous claystone; trace mildly calcareous.
Tuffaceous claystone: (6935' - 7000') = medium dark grey to medium grey; amorphic hydrophilic globules;
no visible structure, fracture, cutting habit or tenacity; very arenaceous, dominant quartz, secondary lithic
clasts, siltstone and abundant loose carbonaceous material / micro fragments of coal.
Tuffaceous siltstone: (7000' - 7070') = medium dark grey to dark grey; dense tenacity; irregular to scaly
fracture; scaly to slightly platy to tabular cuttings habit when visible; earthy and slightly sparkly luster; silty
to gritty texture; laminae to thick structure when visible; dark brown cuttings; very arenaceous with lower
very fine sand grains, well rounded and highly spherical; increasing frequency of micro laminae crenulated
coal / carbonaceous shale; no visible off gassing from micro-laminae.
Tuffaceous claystone: (7070' - 7140') medium grey to medium dark grey; amorphic hydrophilic globules;
impossible to determine structure, fracture, cutting habit, true tenacity; earthy to slightly waxy luster; very
arenaceous, mostly quartz with varying amount of micro fragments of coal / carbonaceous material; trace
mildly calcareous; slightly curdy appearance due to mixing with drilling mud.
Tuffaceous claystone / siltstone: (7140' - 7220') = medium dark grey to medium grey, varying amounts of
dark grey to grayish black cuttings; hydrophilic amorphic globules of claystone / siltstone with
encapsulated inclusions of sand grains, coal and carbonaceous shale fragments, siltstone and lithic clasts;
no discernable fracture, cuttings habit, structure or tenacity; gelatinous and contaminated with drilling
mud; mildly calcareous.
Tuffaceous siltstone: (7220' - 7300') = medium dark grey to medium light grey; mostly hydrophilic,
amoprhic, globules with indiscernible structure, cutting habit, fracture, tenacity or induration; abundant
encapsulated sand grains of lower very fine to lower fine, well rounded to subrounded, also abundant
inclusions of lithic clasts and carbonaceous shale / coal; when characteristics are visible: irregular to
tabular fracture; massive to slightly platy cutting habit; earthy to slightly greasy luster; earthy to gritty
texture from arenaceous inclusions; thin to massive structure; mildly calcareous.
Sand/ sandstone (7300' - 7380') = medium light gray overall with a moderate salt and pepper appearance,
individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray to black,
medium greenish gray; very fine upper to medium lower, dominantly fine; angular to subangular; well
KBU 23-05
10
sorted; dominantly unconsolidated with trace very fine, light gray sandstone; hard; very calcareous
cement; trace thin coal/ carbonaceous shale beds throughout.
Tuffaceous claystone/ tuffaceous siltstone (7380' - 7440') = medium light to light gray with very light gray
and light brownish gray secondary hues; very soft to slightly firm; irregular, shapeless to trace pdc bit
action shaped cuttings; silty to clayey texture; dull to earthy luster; hydrophilic; very soluble and
moderately expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to
black microthin carbonaceous inclusions and laminations; trace thin coal beds.
Sand ( 7440' - 7500') = medium light to light gray overall with individual grain dominantly clear to
translucent quartz and volcanic glass, medium to dark gray to greenish gray and black; very fine upper to
medium lower, dominantly fine; angular to trace subrounded, dominantly subangular; fair to good sorting;
unconsolidated; non calcareous.
Carbonaceous shale / coal: (7500' - 7570') = brownish black to grayish black to slight olive black; well
indurated, slightly firm to moderately firm; dense to crumbly tenacity; irregular to earthy to planar
fracturing; scaly to massive and slightly platy cutting habit; earthy to resinous and some vitreous luster;
silty to smooth texture; laminae to thin structure, some massive; grading from pure coal to carbonaceous
shale and siltstone, some carbonaceous siltstone with crenulated coal laminae; mild to moderate off
gassing.
Tuffaceous claystone: (7570' - 7680') = medium dark grey to medium grey, some olive black,
carbonaceous shales and coals olive black to grayish black; poorly indurated; soft, hydrophilic amorphic
globules; poor cohesion; fluid; mostly indiscernible characteristics; when visible: sectile to malleable
tenacity with poor to moderate induration; blocky to planar fracture; earthy to greasy luster; clayey to silty
and some granular texture depending on sand grain inclusions (possibly imbedding in the annulus) ;
laminae to thin to massive structure; sometimes very arenaceous; frequent micro laminations of coal and
carbonaceous shales, sometimes crenulated, sometimes planar; mildly calcareous.
Tuffaceous siltstone: (7680' - 7760') = medium dark grey to medium dark grey, individual cuttings brownish
grey to brownish black with black laminations; crumbly to pulverulent tenacity; irregular to slightly planar
fracture; scaly and slightly massive, occasional slightly platy cutting habit; earthy to sparkly luster; silty to
abrasive texture; thin to massive structure with microlaminations of coal, sometimes planar, sometimes
crenulated; occasional mild offgassing from coal laminations.
Sand: (7760' - 7820') = medium dark grey to medium light grey; dominantly lower very fine to upper fine
grains, secondary lower medium; well to moderately sorted; very well rounded to subangular for some of
the larger grains; moderate sphericity, occasional oblong larger grains; 60 - 80% quartz, remainder lithic
clasts and coal flakes possibly some cavings; visible impact deformation in smaller grains; polished to
frosted surface; slightly calcareous.
Sand: (7820' - 7910') = olive grey to olive black to medium dark grey to medium grey; upper very fine to
lower medium grains; finer grains very well rounded to subrounded, coarser grains subrounded to
subangular; highly to moderately spherical, contact deformation in finer grains only; unconsolidated;
polished surface on finer, frosted on coarser grains; 70% quartz, 30% lithic clasts; some green hues in
lithic clasts; very highly calcareous.
Tuffaceous siltstone: (7910' - 7980') = olive black to medium dark grey to medium grey to olive grey;
slightly firm to soft, trace hard; poor induration; crumbly to pulverulent tenacity; earthy to irregular fracture;
massive cutting habit; earthy luster; gritty to granular texture; massive structure; occasionally very
arenaceous; inclusions of tuff, flakes and some seams of coal, and volcanic glass.
Tuffaceous sandstone (7980' - 8060') = olive grey to medium grey to medium dark grey; dominant upper
very fine to upper fine grains, secondary lower medium; well sorted; finer grains well rounded to
subrounded; moderate sphericity, some contact deformation; coarser grains subrounded to subangular,
KBU 23-05
11
moderate to highly spherical, frosted surface; mostly unconsolidated, easily friable to slightly firm, trace
very hard; tuffaceous silt matrix supported; dominant lithic clasts, secondary quartz, trace to moderate
carbonaceous material inclusions; very argillaceous, grading to arenaceous siltstone; moderately
calcareous.
Tuffaceous siltstone: (8060' - 8150') = olive grey to medium dark grey to medium light grey to olive black;
soft to firm, trace very hard; poor to high induration; crumbly to slightly malleable tenacity; earthy fracture;
tabular to massive cutting habit; earthy luster; silty to slightly abrasive texture, sometimes gritty from sand
inclusions; massive structure; very arenaceous, quartz and lithic clasts with trace carbonaceous shale /
coal inclusions; interspersed microlamina of tuff and coal, coal occurrence increasing with depth; mildly
calcareous.
Tuffaceous sandstone (8050' - 8220') = medium grey to medium light grey; lower very fine to lower
medium grains; very well rounded finer, well rounded to subrounded coarser; very spherical to slightly
oblong, contact deformation visible; easily friable; grading from tuff matrix supported to occasionally grain
supported; 75% quartz grains, secondary lithic clasts; trace coal; moderately calcareous; individual grains
brownish grey to light olive grey.
Tuffaceous sandstone (8220' - 8280') = dark greenish black and medium dark grey to dark grey; dense to
slightly crumbly tenacity; irregular to earthy fracture; scaly to massive cutting habit; earthy and mildly
sparkly luster; silty to abrasive texture; laminae structure; abundant coal and carbonaceous material
inclusions; coal laminations mildly crenulated; occasionally arenaceous.
Tuffaceous claystone/ tuffaceous siltstone (8280' - 8380') = very light to light gray with very light brownish
gray and yellowish gray secondary hues; irregular to trace pdc bit action shaped cuttings; silty to clayey to
slightly gritty texture; dull to earthy luster; slight to moderately soluble and expansive; poor to fair
cohesiveness; poor adhesiveness; trace dark brown to black, microthin carbonaceous laminations and
inclusions; light yellowish gray siltstone grades between a silty sandstone and sandy siltstone; fragile to
pulverulent; non calcareous; trace to common, 20% safe carb mud (crushed marble), mud additive
contamination.
Tuffaceous siltstone/ tuffaceous claystone (8380' - 8420') = brownish gray to olive gray with light yellowish
gray secondary hues; very soft and fragile; irregular to trace pdc bit action shaped cuttings; silty to clayey
texture; earthy luster; poor adhesiveness; fair cohesiveness; non calcareous; trace thin coal /
carbonaceous shale beds.
Sand/tuffaceous sandstone (8420'-8490') = light to very light gray with individual grains dominantly clear to
translucent quartz and volcanic glass, trace light gray and light greenish gray; very fine lower to upper;
angular to subrounded, dominantly subangular; very well sorted; unconsolidated to very loosely supported
with grayish white ash matrix; very fragile and pulverulent; non to slightly calcareous; commonly grades to
sandy siltstone and silty sandstone.
Coal/ carbonaceous shale (8490'-8560') = black with brownish black and grayish black secondary hues;
hard and brittle; massive; blocky to platy; planar fracture dominant with trace conchoidal and birdeye
present; earthy to vitreous luster; smooth texture; trace to common outgassing observed; coal grades to a
less developed carbonaceous shale; earthy; silty in part; present as thin beds in dominantly sand and
siltstone formation.
Sand/tuffaceous sandstone (8560'-8620') = light to very light gray with individual grains dominantly clear to
translucent quartz and volcanic glass, trace light gray and light greenish gray; very fine lower to very
coarse lower, dominantly medium; angular to trace subrounded, dominantly subangular; poorly sorted;
unconsolidated to disaggregated with very light grayish white supporting matrix; very fragile to pulverulent;
slight to moderately calcareous; trace thin coal beds.
Coal/ carbonaceous shale (8620'-8680') = black with brownish black and grayish black secondary hues;
KBU 23-05
12
hard and brittle; massive; blocky to platy; planar fracture dominant with trace conchoidal and birdeye
present; earthy to vitreous luster; smooth texture; abundant outgassing observed.
Sand/tuffaceous sandstone (8680'-8740') = medium dark grey to medium light grey and medium light grey;
lower very fine to lower medium grains; moderately well sorted; finer grains well rounded to subrounded,
trace subangular, coarser grains subrounded to subangular; ovular to moderately spherical, contact
deformation; mostly unconsolidated, clasts are matrix supported with white tuff; easily friable to slightly
firm, trace firm; occasionally very argillaceous becoming more so with depth; moderately calcareous.
Tuffaceous siltstone (8740' - 8800') = medium grey to medium light and medium dark grey; firm to very
soft; crunchy to crumbly, some dense; irregular to blocky fracture; massive to tabular cutting habit; earthy
and occasionally slightly sparkly luster; gritty to silty texture; massive structure; thin bed layering of distinct
brownish grey and medium grey; very arenaceous; micro laminations of coal; imbedded micro flakes of
coal and carbonaceous shale.
Coal (8800' - 8860') = black; hard; brittle; conchoidal to blocky fracture; splintery to massive and some
flaky cuttings habit; vitreous luster; massive structure; moderate to high off gassing; abundant large pieces
1-3 centimeters coming across shakers probably from cavings.
Tuffaceous siltstone/ tuffaceous claystone (8860' - 8920') = brownish gray to light gray with light yellowish
gray secondary hues; very soft and fragile; irregular to trace pdc bit action shaped cuttings; silty to clayey
texture; earthy luster; poor adhesiveness; fair cohesiveness; non calcareous; light brownish gray siltstone
grades between sandy siltstone and silty sandstone.
Sand/tuffaceous sandstone (8920'-9000') = light to very light gray with individual grains dominantly clear to
translucent quartz and volcanic glass, trace light gray and light greenish gray; very fine lower to trace
coarse lower, dominantly medium; angular to trace subrounded, dominantly subangular; poorly sorted;
unconsolidated to disaggregated with light yellowish gray supporting matrix; very fragile to pulverulent;
slight to moderately calcareous; trace thin coal.
Coal (9000' - 9050') = black with brownish black secondary hues; hard; brittle at times; massive; blocky to
platy and flaky; planar fracture dominant with abundant conchoidal and birdeye fracture vitreous to slightly
earthy luster; smooth to slightly silty texture; persistent and vigorous outgassing observed.
Tuffaceous sandstone/sand (9050'-9100') = bluish white to very light gray with light greenish gray and light
yellowish gray secondary hues; very fragile, soft and pulverulent; irregular shaped cuttings; ash matrix
very loosely supports fine to medium grain sands; dominantly clear to translucent quartz and volcanic
glass, trace dark gray liths; non calc.
Sand / tuffaceous sandstone (9100' - 9150') = medium light grey to light grey; upper very fine to lower fine
grains, secondary lower medium; well sorted; subangular to subrounded, secondary angular and trace
well rounded; low to moderate sphericity; quartz, translucent to opaque white, trace green staining; trace
lithic clasts, coal, volcanic glass; clasts easily friable; grain supported with white tuff matrix, extremely
calcareous.
Tuffaceous siltstone (9150' - 9250 = olive grey to light olive grey and olive black, also medium grey;
hydrophilic, saturated during annulus travel and non cohesive, mostly amorphic; some tabular cuttings
with blocky to earthy fracture; soft to slightly firm; massive cutting habit, well hydrated with butter - curl
effect, slightly platy; earthy luster; silty to gritty texture; thin bed to massive structure; trace arenaceous
with upper medium grains, very angular to sub angular, frosted surface; trace intervals have micro
laminations of coal and carbonaceous shales.
Tuffaceous sandstone/sand (9250'-9310') = bluish white to very light gray with light greenish gray and light
yellowish gray secondary hues; very fragile, soft and pulverulent; irregular shaped cuttings; ash matrix
KBU 23-05
13
very loosely supports fine to very coarse grain sands; clear to translucent quartz and volcanic glass, trace
dark gray liths, pale rose and light green; angular to subangular.
Coal (9310' - 9360') = black with brownish black secondary hues; hard; brittle at times; massive; blocky to
platy and flaky; planar fracture dominant with abundant conchoidal and birdeye fracture vitreous to slightly
earthy luster; smooth to slightly silty texture; subbituminous to bituminous; trace weak out gassing
observed.
Sand/tuffaceous sandstone (9360'-9430') = very light gray with very light greenish gray and bluish gray
secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, trace medium
to dark gray, light greenish gray, pale rose and dusky red; very fine lower to trace very coarse lower,
dominantly fine upper to medium lower; angular to subangular; poorly sorted; loosely supported with light
grayish white ashy matrix; very fragile and pulverulent; non to slightly calcareous; trace to 20% safe carb
mud additive contamination.
Sand/tuffaceous sandstone (9430'-9490') = very light gray with very light greenish gray and bluish gray
secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, trace medium
to dark gray, light greenish gray, pale rose and dusky red; very fine lower to trace very coarse upper with
pebble fragments to 3mm, dominantly medium; angular to subangular; poorly sorted; very fragile ashy
supporting matrix.
Tuffaceous siltstone (9490' - 9570' ) = medium dark grey to olive grey; earthy to blocky fracture; massive
to tabular cuttings habit; earthy luster, slightly sparkly; gritty to granular texture; thin bed to massive
structure; very arenaceous; grading to, and inter - layering with very tuffaceous sandstone; sand grain
inclusions lower very fine to upper fine, well rounded to subangular to moderate to low sphericity;
abundant tuff; non calcareous, but interlayered tuffaceous sandstones (layers = 1 - 3 mm thick) are very
calcareous.
Tuffaceous sandstone / sand (9570' - 9640') = olive grey to medium dark grey, individual cuttings bluish
white to light greenish with light brownish hues; lower very fine to upper fine grains, trace lower medium;
well sorted; well rounded to subrounded; ovular, low to moderately spherical; easily friable to slightly firm;
matrix supported, white to buff tuff; intermixed and interlayered with very tuffaceous siltstone; sandstone
exclusively very calcareous; trace green stone and coal inclusions.
Tuffaceous sandstone (9640' - 9740') = medium grey to dark grey and olive grey; lower very fine to upper
fine grains, trace lower medium grains; well sorted; well rounded finer grains to subangular larger grains;
low sphericity, secondary very spherical; easily friable to slightly firm; primary matrix supported, white to
slightly grayish tuff, grading to secondary grain supported clasts; intermixed and some interbedding with
tuffaceous siltstone; moderate to very calcareous.
Coal (9740' - 9780') = black; blocky, striated fracture; elongated to massive and slightly flaky cutting habit;
vitreous luster; smooth; massive structure; abundant to moderate off gassing; occasionally grading to
carbonaceous siltstone.
Tuffaceous sandstone (9780' - 9860') = medium grey to medium dark grey, some olive hues; lower very
fine to upper medium grains; moderate sorting; subangular to subrounded, some well rounded finer grains
and some angular coarser grains; very low to moderate sphericity; matrix supported, white tuff; dominant
quartz, trace lithic clasts, volcanic glass, coal, rare green stone inclusions; easily friable to some slightly
firm; moderately calcareous; when siltstone present, interbedded with 1-3 mm beds; tuffaceous siltstone is
darker olive grey with microlaminations of coal.
Tuffaceous sandstone (9860' - 9930') = medium light grey to medium dark grey; abundant white ash;
upper very fine to upper medium grains; moderate to poor sorting; subrounded to subangular; low
sphericity, secondary very spherical; dominant quartz, trace lithic clasts, carbonaceous siltstone, coal, rare
volcanic glass; easily friable; matrix supported, white ash; abundant laminae of white ash<3mm with
KBU 23-05
14
siltstone inclusions.
Coal/ carbonaceous shale (9930'-9980') = black with brownish black secondary hues hard to brittle at
times; massive; blocky to platy and flaky; planar fracture dominant with trace conchoidal and birdeye;
vitreous to slightly earthy luster; smooth to slightly silty texture; subbituminous to bituminous; vigorous and
persistent outgassing observed from larger fragments.
Sand/tuffaceous sandstone (9980'-10050') = very light gray with very light greenish gray and pinkish gray
secondary hues, individual grains dominantly clear to translucent quartz and volcanic glass, trace medium
to dark gray, light greenish gray, pale rose and dusky red; very fine lower to trace very coarse upper with
pebble fragments to 3mm, dominantly medium lower to coarse lower; poorly sorted; very loosely
supported from very light grayish white ash matrix; very fragile.
Tuffaceous sandstone (10050' - 10110') = bluish white to very light gray with light pinkish gray and light
yellowish gray secondary hues; very fragile, soft and pulverulent; irregular shaped cuttings; ash matrix
very loosely supports fine to very coarse grain sands; clear to translucent quartz and volcanic glass, trace
dark gray liths, pale rose and light green; angular to subangular; non to slightly calcareous.
Coal/carbonaceous shale (10110-10160) = black with brownish black secondary hues hard to brittle at
times; massive; blocky to platy and flaky; planar fracture dominant with trace conchoidal and birdeye;
vitreous to slightly earthy luster; smooth to slightly silty texture; subbituminous to bituminous; vigorous and
persistent outgassing observed from larger fragments; present as thin beds in dominantly tuffaceous
sandstone form.
Tuffaceous sandstone (10160' - 10230') = very light gray to grayish white with abundant assorted very light
secondary hues; irregular shaped cuttings; very fragile and pulverulent; slight to moderately calcareous;
ashy matrix supports very fine to coarse grains sand grains; clear to translucent quartz and volcanic glass
with trace medium to dark gray, black and dusky red; angular to subangular; poorly sorted.
Coal/carbonaceous shale (10230-10280) = black with brownish black secondary hues hard to brittle at
times; massive; blocky to platy and flaky; planar fracture dominant with trace conchoidal and birdseye;
vitreous to slightly earthy luster; smooth to slightly silty texture; subbituminous to bituminous; trace weak
outgassing observed.
Tuffaceous siltstone/ tuffaceous claystone (10280'-10350') = brownish gray to
Light gray with light yellowish gray secondary hues; very soft and fragile; irregular to trace pdc bit action
shaped cuttings; silty to clayey texture; earthy luster; poor adhesiveness; fair cohesiveness; non
calcareous; light brownish gray to light yellowish gray siltstone grades between sandy siltstone and silty
sandstone; non calcareous; trace thin coal beds throughout interval.
Tuffaceous siltstone/ tuffaceous claystone (10350' - 10420') = light gray to light brownish gray with light
olive secondary hues; soft to slightly firm; irregular, elongated with pdc bit action shaped cuttings; silty to
clayey texture dull to earthy luster; slight to moderately soluble; hydrophilic; poor adhesiveness; fair
cohesiveness; trace dark brown to black microthin carbonaceous laminations and inclusions in gray
siltstone; light brownish gray siltstone commonly grades between silty sandstone and sandy siltstone; non
calcareous.
Tuffaceous sandstone (10420' - 10480') = bluish white to very light gray with light pinkish gray and light
yellowish gray secondary hues; very fragile, soft and pulverulent; irregular shaped cuttings; ash matrix
very loosely supports fine to very coarse grain sands; clear to translucent quartz and volcanic glass, trace
dark gray liths, pale rose and light green; angular to subangular; non to slightly calcareous.
Tuffaceous siltstone/ tuffaceous claystone (10480' - 10547') = dark grey to medium dark grey; dense,
sectile tenacity; earthy to splintery fracture; tabular to massive and sometimes platy cuttings habit; earthy
and slightly waxy luster; smooth to silty texture; thin bed to laminae structure, some banded and/or mottled
KBU 23-05
15
with carbonaceous material; thin beds are planar and sometimes moderately to very crenulated; mild to
moderate offgassing in carbonaceous material; occasional arenaceous.
3.3 Sampling Program
The sampling program specified by the Geologist called for the collection of three sets of Washed and
Dried Reference Samples beginning at 5946’ MD. The resulting set, interval, and distribution are shown
below.
Sets Type and Purpose Interval Frequency Distribution
1 Washed and Dried 6120’-7100’ 20’
Landon Ellison
Hilcorp Alaska LLC
3800 Center Point Drive, Suite 100
Anchorage, AK 99508
2 Washed and Dried 7100’-8100’ 20’
Landon Ellison
Hilcorp Alaska LLC
3800 Center Point Drive, Suite 100
Anchorage, AK 99508
3 Washed and Dried 8100’-9200’
20’
Landon Ellison
Hilcorp Alaska LLC
3800 Center Point Drive, Suite 100
Anchorage, AK 99508
4 Washed and Dried 9200’-10200’ 20’
Landon Ellison
Hilcorp Alaska LLC
3800 Center Point Drive, Suite 100
Anchorage, AK 99508
5 Washed and Dried 10200’-10547’ 20’
Landon Ellison
Hilcorp Alaska LLC
3800 Center Point Drive, Suite 100
Anchorage, AK 99508
KBU 23-05
16
4 DRILLING DATA
4.1 Surveys
Measured
Depth
(ft)
Incl.
(o)
Azim.
(o)
True
Vertical
Depth (ft)
Latitude
(ft)
N(+), S(-)
Departure
(ft)
E(+), W(-)
Vertical
Section
(Incr) (ft)
Dogleg
Rate
(o/100ft)
232.59 0.45 196.42 232.59 -0.81 -0.24 -0.7 0.21
392.73 2.31 60.5 392.69 0.18 2.39 1.97 1.66
452.66 5.03 57.69 452.49 2.18 5.67 5.77 4.56
514.2 6.46 56.62 513.72 5.53 10.84 11.89 2.32
575.34 7.7 55.92 574.39 9.72 17.11 19.4 2.03
636.71 8.76 55.4 635.13 14.67 24.36 28.15 1.73
699.03 9.9 53.73 696.62 20.54 32.58 38.23 1.89
760.29 11.25 52.52 756.84 27.29 41.57 49.46 2.22
822.11 12.34 55.17 817.36 34.73 51.77 62.07 1.97
884.2 13.85 50.7 877.83 43.22 62.97 76.12 2.93
946.48 15.13 51.14 938.13 53.05 75.07 91.7 2.06
1008.57 16.42 51.82 997.88 63.56 88.28 108.58 2.11
1070.35 18.19 51.34 1056.86 74.98 102.68 126.95 2.87
1132.61 19.97 49.38 1115.7 87.97 118.34 147.3 3.03
1193.86 21.46 48.46 1172.99 102.21 134.66 168.95 2.5
1256.8 22.13 48.1 1231.43 117.77 152.11 192.3 1.08
1318.48 22.17 48.54 1288.55 133.24 169.48 215.54 0.28
1380.34 22.49 48.87 1345.77 148.75 187.14 239.03 0.55
1441.25 22.89 48.62 1401.97 164.24 204.8 262.51 0.68
1478.66 21.9 48.72 1436.56 173.65 215.5 276.75 2.66
1541.55 20.94 48.15 1495.1 188.88 232.69 299.7 1.55
1608.92 20.3 48.8 1558.16 204.61 250.45 323.41 1.02
1670.52 20.87 48.74 1615.83 218.89 266.73 345.05 0.93
1732.43 21.56 49.58 1673.54 233.53 283.68 367.44 1.22
1793.78 22.01 49.9 1730.51 248.25 301.06 390.2 0.76
1856.28 23.06 49.37 1788.24 263.76 319.3 414.15 1.72
1918.3 23.18 49.58 1845.28 279.58 337.81 438.5 0.24
1980.58 22.7 49.52 1902.63 295.34 356.29 462.77 0.77
2042.33 22.3 49.65 1959.68 310.66 374.28 486.4 0.65
2105.48 21.73 49.6 2018.22 326 392.32 510.07 0.91
2166.57 21.41 49.36 2075.03 340.59 409.39 532.52 0.54
2226.81 21.42 49.4 2131.11 354.91 426.08 554.51 0.03
2289.39 21.68 50.34 2189.32 369.72 443.66 577.49 0.7
2351.46 22.09 50.84 2246.92 384.41 461.53 600.62 0.73
KBU 23-05
17
Measured
Depth
(ft)
Incl.
(o)
Azim.
(o)
True
Vertical
Depth (ft)
Latitude
(ft)
N(+), S(-)
Departure
(ft)
E(+), W(-)
Vertical
Section
(Incr) (ft)
Dogleg
Rate
(o/100ft)
2412.47 22.85 51.26 2303.3 399.07 479.67 623.94 1.27
2474.21 22.87 51.66 2360.19 414.01 498.43 647.92 0.25
2536.77 22.59 51.74 2417.89 428.99 517.4 672.09 0.46
2598.55 22.11 51.58 2475.03 443.56 535.82 695.58 0.79
2661.15 21.69 51.61 2533.11 458.06 554.12 718.92 0.67
2722.89 22.24 51.36 2590.37 472.44 572.18 742.01 0.9
2784.99 23.72 50.67 2647.54 487.69 591.02 766.25 2.42
2846.11 24.12 50.09 2703.41 503.5 610.11 791.03 0.76
2908.92 23.39 49.82 2760.9 519.77 629.48 816.33 1.18
2968.98 22.85 49.66 2816.14 535.01 647.48 839.91 0.89
3034.12 22.56 49.48 2876.23 551.32 666.62 865.05 0.46
3096.47 22.17 49.46 2933.89 566.74 684.65 888.77 0.62
3157.06 21.89 49.29 2990.05 581.54 701.91 911.49 0.48
3220.15 21.51 49.58 3048.67 596.71 719.63 934.81 0.63
3282.75 21.09 49.51 3107 611.46 736.93 957.54 0.67
3344.56 21.41 49.39 3164.61 626.02 753.95 979.94 0.53
3406.78 22.57 50.49 3222.3 641.01 771.78 1003.23 1.99
3468.65 23.39 52.11 3279.26 656.11 790.64 1027.39 1.67
3530.38 23.14 52.75 3335.97 670.98 809.96 1051.76 0.58
3593.04 22.72 52.56 3393.68 685.79 829.37 1076.16 0.68
3653.61 22.53 52.49 3449.58 699.97 847.86 1099.45 0.32
3715.35 22.03 52.39 3506.71 714.24 866.42 1122.85 0.81
3777.48 21.9 52.4 3564.33 728.42 884.83 1146.08 0.21
3839.66 21.36 52.17 3622.13 742.44 902.97 1168.99 0.89
3901.86 20.85 52.35 3680.16 756.15 920.67 1191.38 0.82
3964.1 20.94 50.76 3738.31 769.95 938.06 1213.57 0.93
4025.79 21.68 50.5 3795.78 784.17 955.38 1235.99 1.22
4088.14 21.79 50.82 3853.7 798.81 973.24 1259.08 0.27
4150.28 22.36 51.06 3911.28 813.52 991.38 1282.43 0.92
4212.27 22.96 51.2 3968.49 828.51 1009.97 1306.31 0.98
4274.37 24.41 51.35 4025.36 844.11 1029.43 1331.26 2.33
4336.19 24.61 51.02 4081.61 860.19 1049.42 1356.91 0.39
4398.43 24.38 51.12 4138.24 876.4 1069.49 1382.71 0.37
4459.77 24.15 51.33 4194.16 892.19 1089.15 1407.92 0.4
4524.48 23.79 51.08 4253.29 908.66 1109.64 1434.21 0.59
4586.3 23.64 51.33 4309.89 924.24 1129.02 1459.07 0.29
4647.74 23.46 51.27 4366.22 939.58 1148.17 1483.62 0.3
4709.66 23.23 51.45 4423.07 954.91 1167.34 1508.15 0.38
4771.88 22.92 51.2 4480.31 970.14 1186.38 1532.54 0.53
KBU 23-05
18
Measured
Depth
(ft)
Incl.
(o)
Azim.
(o)
True
Vertical
Depth (ft)
Latitude
(ft)
N(+), S(-)
Departure
(ft)
E(+), W(-)
Vertical
Section
(Incr) (ft)
Dogleg
Rate
(o/100ft)
4833.92 22.58 51.54 4537.52 985.12 1205.12 1556.53 0.58
4895.2 22.49 51.98 4594.12 999.66 1223.57 1580.01 0.32
4957.92 22.31 52.17 4652.11 1014.35 1242.42 1603.91 0.31
5020.54 22.03 52.52 4710.1 1028.79 1261.13 1627.53 0.5
5082.22 21.8 52.93 4767.32 1042.73 1279.45 1650.54 0.44
5144.32 21.78 52.73 4824.98 1056.66 1297.82 1673.58 0.13
5207.29 21.61 53.2 4883.49 1070.68 1316.4 1696.84 0.38
5268.88 21.71 52.61 4940.74 1084.39 1334.53 1719.55 0.39
5330.69 21.6 53.1 4998.18 1098.16 1352.71 1742.34 0.34
5390.84 21.59 53.09 5054.11 1111.45 1370.41 1764.46 0.02
5453.1 21.7 51.85 5111.98 1125.44 1388.62 1787.41 0.76
5514.97 22.11 50.81 5169.39 1139.86 1406.63 1810.49 0.91
5577.1 22.26 50.88 5226.92 1154.68 1424.83 1833.95 0.25
5639.35 22.46 50.37 5284.49 1169.7 1443.13 1857.63 0.44
5700.95 23.02 49.46 5341.3 1185.04 1461.35 1881.44 1.07
5763.47 23.07 49.55 5398.83 1200.93 1479.96 1905.9 0.09
5825.77 22.58 49.69 5456.25 1216.58 1498.37 1930.06 0.78
5888.11 22.47 49.73 5513.84 1232.03 1516.58 1953.94 0.18
5949.98 22.06 49.42 5571.09 1247.23 1534.43 1977.39 0.69
6011.48 21.87 49 5628.13 1262.26 1551.85 2000.38 0.41
6072.22 21.59 49.22 5684.55 1276.98 1568.85 2022.86 0.48
6167.08 21.83 48.56 5772.69 1300.05 1595.28 2057.92 0.36
6229.24 21.85 48.18 5830.38 1315.41 1612.56 2081.03 0.23
6293.48 22.48 49.38 5889.88 1331.38 1630.8 2105.25 1.2
6353.14 22.76 49.13 5944.95 1346.36 1648.18 2128.19 0.5
6414.3 23.06 48.77 6001.28 1361.99 1666.14 2151.98 0.54
6478.88 23.31 48.86 6060.65 1378.73 1685.27 2177.39 0.4
6539.94 23.53 48.64 6116.68 1394.74 1703.52 2201.65 0.38
6602.02 23.55 48.59 6173.59 1411.13 1722.12 2226.42 0.05
6666 23.75 48.79 6232.2 1428.07 1741.39 2252.07 0.34
6726.68 23.91 48.39 6287.71 1444.28 1759.78 2276.57 0.38
6786.82 23.89 48.52 6342.69 1460.44 1778.01 2300.91 0.1
6849 24.41 48.18 6399.43 1477.35 1797.02 2326.32 0.88
6911.84 23.34 48.55 6456.89 1494.25 1816.03 2351.74 1.72
6974.48 22.07 49.57 6514.67 1510.09 1834.29 2375.9 2.13
7036.99 22.07 49.14 6572.6 1525.39 1852.11 2399.38 0.26
7098.33 22.34 48.83 6629.4 1540.61 1869.6 2422.55 0.49
7160.82 21.94 48.88 6687.28 1556.1 1887.34 2446.09 0.65
7222.8 22.3 49.05 6744.69 1571.43 1904.94 2469.42 0.59
KBU 23-05
19
Measured
Depth
(ft)
Incl.
(o)
Azim.
(o)
True
Vertical
Depth (ft)
Latitude
(ft)
N(+), S(-)
Departure
(ft)
E(+), W(-)
Vertical
Section
(Incr) (ft)
Dogleg
Rate
(o/100ft)
7282.85 22.82 49.41 6800.15 1586.47 1922.39 2492.45 0.89
7347.35 22.9 49.34 6859.58 1602.79 1941.41 2517.5 0.13
7407.92 20.05 51.2 6915.94 1616.97 1958.44 2539.66 4.84
7471.31 20.31 51.12 6975.44 1630.69 1975.47 2561.53 0.42
7532.79 20.43 51.24 7033.08 1644.1 1992.15 2582.93 0.21
7594.65 20.7 50.64 7091 1657.79 2009.02 2604.66 0.55
7656.46 20.85 50.18 7148.79 1671.76 2025.91 2626.58 0.36
7718.44 20.95 50.23 7206.69 1685.92 2042.9 2648.69 0.16
7780.57 21.08 53.6 7264.69 1699.65 2060.43 2670.96 1.95
7842.95 21.37 53.88 7322.84 1713.01 2078.64 2693.51 0.49
7905.33 21.48 53.85 7380.91 1726.45 2097.05 2716.27 0.17
7967.04 21.45 53.84 7438.33 1739.77 2115.28 2738.82 0.04
8028.77 21.48 53.83 7495.78 1753.1 2133.52 2761.38 0.04
8090.61 21.55 53.68 7553.31 1766.51 2151.81 2784.03 0.14
8153.52 21.71 53.59 7611.79 1780.26 2170.48 2807.19 0.26
8215.41 21.99 53.37 7669.24 1793.97 2189 2830.2 0.47
8278 22.14 53.49 7727.24 1807.98 2207.88 2853.68 0.25
8338.83 22.16 53.28 7783.58 1821.66 2226.29 2876.59 0.13
8402.15 21.05 52.78 7842.45 1835.68 2244.92 2899.89 1.78
8464.53 19.44 52.94 7900.98 1848.71 2262.12 2921.46 2.59
8525.5 16.65 55.02 7958.95 1859.84 2277.37 2940.31 4.69
8588.37 15.76 54.56 8019.32 1869.95 2291.71 2957.81 1.43
8650.19 14.37 53.11 8079.01 1879.43 2304.69 2973.86 2.33
8712.18 12.35 52.6 8139.32 1888.07 2316.11 2988.17 3.27
8774.39 10.66 53.24 8200.28 1895.56 2326 3000.57 2.71
8835.16 9.18 50.26 8260.14 1902.02 2334.24 3011.03 2.58
8897.37 8.11 50.67 8321.64 1907.97 2341.45 3020.39 1.72
8955.54 7.58 50 8379.27 1913.04 2347.56 3028.32 0.93
9018.42 6.21 51.18 8441.69 1917.84 2353.39 3035.87 2.19
9083.25 5.45 49.55 8506.18 1922.04 2358.46 3042.46 1.2
9146.59 4.73 46.35 8569.27 1925.79 2362.64 3048.07 1.22
9208.46 4.35 48.71 8630.95 1929.1 2366.25 3052.96 0.69
9268.04 3.49 52.27 8690.39 1931.7 2369.38 3057.03 1.49
9330.73 2.67 52.93 8752.99 1933.75 2372.06 3060.4 1.31
9394.87 2.57 54.44 8817.06 1935.49 2374.42 3063.33 0.19
9456.06 2.52 55.74 8878.19 1937.04 2376.65 3066.04 0.13
9519.2 2.33 49.8 8941.27 1938.65 2378.77 3068.7 0.5
9580.12 2.16 49.39 9002.15 1940.19 2380.59 3071.08 0.27
9643.11 2.09 48.53 9065.09 1941.73 2382.35 3073.42 0.12
KBU 23-05
20
Measured
Depth
(ft)
Incl.
(o)
Azim.
(o)
True
Vertical
Depth (ft)
Latitude
(ft)
N(+), S(-)
Departure
(ft)
E(+), W(-)
Vertical
Section
(Incr) (ft)
Dogleg
Rate
(o/100ft)
9704.61 1.9 46.17 9126.56 1943.18 2383.93 3075.55 0.34
9767.4 1.67 48.14 9189.32 1944.51 2385.36 3077.51 0.37
9829.06 1.37 42.79 9250.95 1945.65 2386.53 3079.14 0.54
9889.52 1.45 42.28 9311.4 1946.75 2387.54 3080.61 0.12
9951.09 1.34 40.68 9372.95 1947.87 2388.53 3082.09 0.18
10013.71 1.32 42.1 9435.55 1948.96 2389.49 3083.52 0.07
10075.99 1.26 43.02 9497.82 1949.99 2390.44 3084.91 0.1
10137.51 1.39 49.15 9559.32 1950.97 2391.47 3086.33 0.31
10199.89 1.21 48.92 9621.68 1951.9 2392.53 3087.74 0.28
10261.94 1.08 55.07 9683.72 1952.67 2393.51 3088.98 0.29
10323.7 1.37 58.99 9745.47 1953.38 2394.62 3090.29 0.49
10380.64 1.3 63.52 9802.39 1954.02 2395.78 3091.6 0.23
10448.6 0.91 67.4 9870.34 1954.57 2396.97 3092.86 0.58
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KBU 23-05
24
5 DAILY REPORTS
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR James Lott / Bob Farrell
DATE May 26, 2014 DEPTH 3000' PRESENT OPERATION TIH for wiper trip
TIME 00:20:16 YESTERDAY 1520'
24 HOUR FOOTAGE 1480
CASING INFORMATION 10.75" @ MD1520' / TVD 1475'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
2908.92 23.39 49.82 2760.9
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
2 9 7/8" PDC 12154579 1520
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 1118.7 @ 2592' 3.5 @ 2828' 299.0 240.72600 FT/HR
SURFACE TORQUE 7678 @ 2199' 141 @ 2728' 4734.5 7106.08984 FT-LBS
WEIGHT ON BIT 29 @ 1651' 0 @ 2910' 4.3 8.52000 KLBS
ROTARY RPM 69 @ 2953' 0 @ 2728' 44.5 67.32000 RPM
PUMP PRESSURE 1538 @ 3000' 800 @ 1522' 1126.1 1538.51001 PSI
DRILLING MUD REPORT DEPTH 2455 / 2343
MW 9.3 VIS 48 PV 11 YP 18 Gels 5/7/9 FL 10 CL- 34000
FC 1/1 SOL 4 SD 1 OIL tr/96 MBT 5 pH 8.5 Ca+ 200 Alk 0.4
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 118 @ 1816' 5 @ 1556' 47.3 TRIP GAS
CUTTING GAS 0 @ 3000' 0 @ 3000' 0.0 WIPER GAS 7
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 23620 @ 1816' 1126 @ 1556' 9104.1 CONNECTION GAS HIGH
ETHANE (C-2) 0 @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY
SUMMARY
Drill out plugs @ 1424', float collar, cement and shoe @ 1510'. Drilled 20' of new Fm to 1,540'. Pumped 20 bbl spacer and displaced spud
mud with 9.1ppg Kla-Shield. FIT. Drill ahead. Drilled to short trip point, pumped sweep and prepare to TOH.
CANRIG PERSONNEL ON BOARD 2 DAILY COST $2294.75
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR James Lott / Bob Farrell
DATE May 26, 2014 DEPTH 4600' PRESENT OPERATION Drilling ahead
TIME 2359 YESTERDAY 3000'
24 HOUR FOOTAGE 1600
CASING INFORMATION 10.75" @ MD1520' / TVD 1475'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
2 9 7/8" PDC 12154579 1520
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 940.6 @ 3866' 4.3 @ 3453' 336.5 244.01009 FT/HR
SURFACE TORQUE 12794 @ 4421' 529 @ 3464' 7023.3 8462.33984 FT-LBS
WEIGHT ON BIT 20 @ 4386' 0 @ 3417' 8.2 6.99000 KLBS
ROTARY RPM 71 @ 4227' 0 @ 3464' 56.1 60.72000 RPM
PUMP PRESSURE 2329 @ 4401' 1153 @ 3512' 1692.7 1975.03003 PSI
DRILLING MUD REPORT DEPTH 4665' / 4382'
MW 9.3 VIS 80 PV 16 YP 23 Gels 7/9/11 FL 6 CL- 38000
FC 1/1 SOL 5 SD 0.5 OIL /95 MBT 7.5 pH 9.5 Ca+ 400 Alk .7
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 520 @ 4420' 9 @ 3016' 116.2 TRIP GAS
CUTTING GAS @ @ WIPER GAS 252
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 103708 @ 4420' 1017 @ 3016' 22771.6 CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY SUMMARY Short trip to casing. Drilled ahead to 4502. Then made another short trip. Swept hole and started drilling ahead.
CANRIG PERSONNEL ON BOARD 2 DAILY COST $2294.75
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR James Lott / Bob Farrell
DATE May 27, 2014 DEPTH 6118' PRESENT OPERATION POOH
TIME 2359 YESTERDAY 4600'
24 HOUR FOOTAGE 1518'
CASING INFORMATION 10.75" @ MD1520' / TVD 1475'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
6011.48' 21.87 49.00 5628.13'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
2 9 7/8" PDC` 12154579 1520 6118 4598
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 803.4 @ 5255' 1.4 @ 5372' 225.5 69.96 FT/HR
SURFACE TORQUE 13963 @ 5650' 205 @ 5438' 8867.0 8745 FT-LBS
WEIGHT ON BIT 27 @ 5631' 3 @ 4753' 9.8 14 KLBS
ROTARY RPM 70 @ 4674' 0 @ 5438' 59.5 63 RPM
PUMP PRESSURE 2428 @ 6065' 1789 @ 4629' 2184.3 2099 PSI
DRILLING MUD REPORT DEPTH 6118 / 5730
MW 9.4 VIS 60 PV 16 YP 26 Gels 7/9/11 FL 6.2 CL- 35000
FC 1/1 SOL 8 SD 0.75 OIL /92 MBT 7.5 pH 9.0 Ca+ 420 Alk 0.8
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 650 @ 5238' 17 @ 5682' 143.8 TRIP GAS
CUTTING GAS @ @ WIPER GAS 182
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 123281 @ 5238' 3347 @ 5682' 27515.1 CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY 40% SILTSTONE / 30% SAND/ SANDSTONE / 30% CLAYSTONE W/ NUTPLUG SWEEP.
DAILY ACTIVITY
SUMMARY
Drilled to 6118'. TOH to 4500' and will TIH, Pump sweep and then TOH for casing. encountered tight hole at ~ 5200' Working tight spot
from 5200 up to 4700' ~ Tripping back to bottom. Circulate sweep and will TOH for casing
CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.5
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR James Lott / Bob Farrell
DATE May 28, 2014 DEPTH 6118' PRESENT OPERATION RIH with casing
TIME 2359 YESTERDAY 6118'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
6011.48' 21.87 49.00 5628.13'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
2 9 7/8" PDC 12154579 1520 1520 4598 1-2-CT-S-X-I-NO-TD TD
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH No mud report currently
MW VIS PV YP Gels FL CL-
FC SOL SD OIL MBT pH Ca+ Alk
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS
CUTTING GAS @ @ WIPER GAS 182
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY
SUMMARY
TIH to 4500'. Back ream from 4500 - 4050. Pump from 4050 - 3400. Ream at 520gpm. Continue POOH. Lay down BHA. Sirvice rig. :evel
Derric and track for casing run. Rig up and test equipment. Test 7 5/8" pipe rams to 250 low and 3500 high. Start RIH with casing
CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.5
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / Bob Farrell
DATE May 29, 2014 DEPTH 6118' PRESENT OPERATION TIH for clean-out run
TIME 2359 YESTERDAY 6118'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
6011.48' 21.87 49.00 5628.13'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH 6118 / 5727
MW 9.4 VIS 58 PV 13 YP 19 Gels 6/11/15 FL 6 CL- 30000
FC 1/1 SOL 6 SD 0.25 OIL /94 MBT 10 pH 8.0 Ca+ 400 Alk 0.8
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS
CUTTING GAS @ @ WIPER GAS 46
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY
SUMMARY
Continue TIH with casing. At 2916', unable to progress. Made several attempts working pipe with and without pumps and rotating. Pull
casing. Change rams, P/u clean out assembly. RIH, reamed difficult section. Cont. RIH to 3870'. Still RIH with casing at report time.
CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.5
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / Bob Farrell
DATE May 30, 2014 DEPTH 6118' PRESENT OPERATION RIH with casing
TIME 2359 YESTERDAY 6118'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
6011.48' 21.87 49.00 5628.13'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH No update at time of report
MW VIS PV YP Gels FL CL-
FC SOL SD OIL MBT pH Ca+ Alk
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS
CUTTING GAS @ @ WIPER GAS 190
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY SUMMARY
CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.5
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / Bob Farrell
DATE May 31, 2014 DEPTH 6118' PRESENT OPERATION Servicing rig / BOP test
TIME 2359 YESTERDAY 6118'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
6011.48' 21.87 49.00 5628.13'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH Pits empty
MW VIS PV YP Gels FL CL-
FC SOL SD OIL MBT pH Ca+ Alk
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS
CUTTING GAS @ @ WIPER GAS 38
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY
SUMMARY
RIH with 7 5/8" casing. Land at 6108'. Circulate and condition mud. Rig up cementers. Pump cement job - started with 37 bbls of 10 ppg
spacer, followed by 173 bbls of 10.5 ppg lead cement, followed by 24 bbls of 13.5 ppg tail cement. The plug was bumped with 260 bbls of 9.5
ppg mud. Rig down cementers. Clear & clean rig floor. L/D landing joint & CRT. Change rams. Test BOP's.
CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.5
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / Bob Farrell
DATE June 1, 2014 DEPTH 6118' PRESENT OPERATION TIH
TIME 2359 YESTERDAY 6118'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
6011.48' 21.87 49.00 5628.13'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH Pits empty
MW 10 VIS 56 PV 13 YP 19 Gels 5/8/14 FL 5 CL- 40000
FC 1/1 SOL 9 SD 0.5 OIL 1/90 MBT 7.5 pH 9.5 Ca+ 100 Alk 1.2
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS
CUTTING GAS @ @ WIPER GAS
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY
SUMMARY
Test BOP's. Make up drilling BHA. Shallow test MWD - failed. Trouble shoot MWD. Slip & cut. Wait on tool.Made up tool and TIH to
drill out cement
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY $2148.5
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 02, 2014 DEPTH 7013' PRESENT OPERATION Drilling ahead
TIME 2359 YESTERDAY 6118'
24 HOUR FOOTAGE 895
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
7098.33 22.34 48.83` 6629.4
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 478.1 @ 6429' 7.2 @ 6630' 136.1 420.38217 FT/HR
SURFACE TORQUE 8921 @ 6543' 5809 @ 6119' 7284.3 8263.53027 FT-LBS
WEIGHT ON BIT 14 @ 6118' 0 @ 6149' 7.4 4.93000 KLBS
ROTARY RPM 69 @ 6630' 26 @ 6119' 47.8 43.82000 RPM
PUMP PRESSURE 2867 @ 6677' 1762 @ 6119' 2557.9 2774.59009 PSI
DRILLING MUD REPORT DEPTH
MW 10 VIS 60 PV 20 YP 23 Gels 6/11/17 FL 5 CL- 60000
FC 1/1 SOL 11 SD 0.5 OIL 3/86 MBT 7.5 pH 10.5 Ca+ 225 Alk 1.25
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 1223 @ 6611' 6 @ 6119' 261.1 TRIP GAS
CUTTING GAS @ @ WIPER GAS
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 246512 @ 6611.00000 1191 @ 6119.00000 53450.0 CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY tuffaceous claystone, sand, tuffaceous siltstone
PRESENT LITHOLOGY 40% tuffaceous claystone 40% tuffaceous silstone 20% sand
DAILY ACTIVITY
SUMMARY
RIH picking up singles. Tag cement at 6024'. Perform casing test - OK. Drill out cement, shoe, and new formation to 6142'. Perform
FIT to 13.5 ppg EMW. Drilling ahead.
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 03, 2014 DEPTH 7840' PRESENT OPERATION Drilling ahead
TIME 2359 YESTERDAY 7013'
24 HOUR FOOTAGE 827'
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
7842.95' 21.37 53.88 7322.84'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 671.4 @ 7696' 1.6 @ 7322' 101.3 57.04278 FT/HR
SURFACE TORQUE 9500 @ 7338' 6968 @ 7261' 7200.9 7822.62988 FT-LBS
WEIGHT ON BIT 42 @ 7632' 0 @ 7364' 7.3 7.88000 KLBS
ROTARY RPM 70 @ 7423' 41 @ 7148' 52.6 62.66000 RPM
PUMP PRESSURE 3268 @ 7818' 2374 @ 7324.' 2815.7 3006.63989 PSI
DRILLING MUD REPORT DEPTH
MW 10.2 VIS PV 70 YP 21 Gels 29 FL 7/12/17 CL- 50000
FC 1/1 SOL 10 SD 0.25 OIL 2/88 MBT 6 pH 9.5 Ca+ 160 Alk 1.25
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 1034 @ 7745' 43 @ 7322' 354.6 TRIP GAS
CUTTING GAS 0 @ @ WIPER GAS 206
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 199137 @ 7506' 8460 @ 7322' 67961.7 CONNECTION GAS HIGH
ETHANE (C-2) 0 @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY Tuffaceous siltstone, tuffaceous claystone, sand, coal, carbonaceous shale / siltstone,
PRESENT LITHOLOGY 40% Sand 40% Tuffaceous siltstone 20% Carbonaceous shale / coal
DAILY ACTIVITY
SUMMARY
Drilling ahead rotating and sliding to 7444'. CBU. TOH to the shoe. Tight hole from 6450' to 6080' requiring back reaming. Service rig at
the shoe. RIH. Tagged bottom, pumped sweep, Drilling.
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 04, 2014 DEPTH 8872' PRESENT OPERATION POOH for short trip to shoe
TIME 2359 YESTERDAY 7840'
24 HOUR FOOTAGE 1032'
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 1737.9 @ 8006' 0.5 @ 8437' 94.7 22.52252 FT/HR
SURFACE TORQUE 9744 @ 8394' 56 @ 8445' 6846.7 8056.20020 FT-LBS
WEIGHT ON BIT 17 @ 8568' 0 @ 8382' 6.1 8.10000 KLBS
ROTARY RPM 70 @ 7939' 1 @ 8440' 50.8 57.45000 RPM
PUMP PRESSURE 3467 @ 8842' 2689 @ 7938' 3115.8 3343.66992 PSI
DRILLING MUD REPORT DEPTH
MW 11 VIS 63 PV 22 YP 26 Gels 7/14/18 FL 4.2 CL- 48000
FC 1/1 SOL 13 SD 0.1 OIL 2/85 MBT 6 pH 9.1 Ca+ 180 Alk 0.9
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 2663 @ 8820' 43 @ 8572' 316.8 TRIP GAS
CUTTING GAS 0 @ @ WIPER GAS
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 176180 @ 8464' 7989 @ 8574' 45953.0 CONNECTION GAS HIGH
ETHANE (C-2) 0 @ 8872' 0 @ 8872' 0.0 CONNECTION GAS AVG
PROPANE (C-3) 39 @ 8675' 0 @ 8607' 1.4 CONNECTION GAS CURRENT
BUTANE (C-4) @ @ 8872.00000 CURRENT BACKGROUND/AVG 130
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY Tuffaceous siltstone, Tuffaceous claystone, Tuffaceous sandstone, Sand, Coal, Carbonaceous shale / siltstone,
PRESENT LITHOLOGY 90% Tuffaceous sandstone 10%Tuffaceous siltstone
DAILY ACTIVITY
SUMMARY
Drilling ahead rotating and sliding. Dropping angle. WOB 8 RPM 80 TORQ 8K GPM 305 SPP 3200. Drill to 8872'. Begin POOH for
short trip to shoe. Currently POOH
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 05, 2014 DEPTH 9133' PRESENT OPERATION Drilling ahead
TIME 2359 YESTERDAY 8872'
24 HOUR FOOTAGE 261
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 400.0 @ 9091' 0.9 @ 8898' 64.3 37.44888 FT/HR
SURFACE TORQUE 9457 @ 8938' 855 @ 9062' 5698.4 0.00000 FT-LBS
WEIGHT ON BIT 16 @ 8947' 0 @ 9082' 6.4 5.82000 KLBS
ROTARY RPM 62 @ 8903' 0 @ 9062' 36.6 0.00000 RPM
PUMP PRESSURE 3452 @ 8939' 2545 @ 8947' 3197.8 3081.03003 PSI
DRILLING MUD REPORT DEPTH 9132 / 8555
MW 11.5 VIS 68 PV 26 YP 38 Gels 10/18/26 FL 4.2 CL- 49000
FC 1/1 SOL 17 SD 0.5 OIL 3/81 MBT 6.25 pH 9.5 Ca+ 120 Alk 0.8
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 2923 @ 9126' 19 @ 8946' 312.1 TRIP GAS
CUTTING GAS @ @ WIPER GAS 1713
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 477401 @ 9126' 3839 @ 8946' 55989.9 CONNECTION GAS HIGH
ETHANE (C-2) 4236 @ 9126' 194 @ 9130' 113.4 CONNECTION GAS AVG
PROPANE (C-3) 407 @ 9126' 18 @ 9130' 11.8 CONNECTION GAS CURRENT
BUTANE (C-4) 80 @ 9126' 3 @ 9130' 1.4 CURRENT BACKGROUND/AVG 45
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY Tuffaceous siltstone, Tuffaceous claystone, Tuffaceous sandstone, Sand, Coal, Carbonaceous shale / siltstone
PRESENT LITHOLOGY COAL
DAILY ACTIVITY
SUMMARY
Drilling to 8872'. CBU. TOH - Pump out from 7460' to 7450' & 7430' to 7420'. Service rig at the shoe. RIH, wash down last 2 stands. CBU,
1600 units of gas. Pump sweep around. Drilling ahead sliding and rotating, to 9133' at report time.
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 06, 2014 DEPTH 9654' PRESENT OPERATION Drilling ahead
TIME 2359 YESTERDAY 9133'
24 HOUR FOOTAGE 521'
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
9643.11 2.09 48.53 9065.09
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 301.2 @ 9396' 1.8 @ 9369' 77.1 20.09053 FT/HR
SURFACE TORQUE 9370 @ 9622' 965 @ 9315' 7323.6 8434.91016 FT-LBS
WEIGHT ON BIT 28 @ 9258' 0 @ 9199' 7.9 10.66000 KLBS
ROTARY RPM 68 @ 9202' 1 @ 9205' 48.5 53.82000 RPM
PUMP PRESSURE 3675 @ 9265' 2767 @ 9196' 3348.6 3284.32007 PSI
DRILLING MUD REPORT DEPTH 9653 / 9075
MW 11.5 VIS 65 PV 29 YP 32 Gels 10/19/30 FL 4 CL- 55000
FC 1/1 SOL 18 SD 0.5 OIL 2/80 MBT 9 pH 9.7 Ca+ 120 Alk 1
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 684 @ 9343.00000 13 @ 9258.00000 147.0 TRIP GAS
CUTTING GAS 0 @ 9654.00000 0 @ 9654.00000 0.0 WIPER GAS 1880
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 134015 @ 9343.00000 1175 @ 9525.00000 27778.6 CONNECTION GAS HIGH
ETHANE (C-2) 240 @ 9136.00000 8 @ 9163.00000 8.7 CONNECTION GAS AVG
PROPANE (C-3) 28 @ 9341.00000 0 @ 9326.00000 1.9 CONNECTION GAS CURRENT
BUTANE (C-4) 4 @ 9136.00000 0 @ 9163.00000 0.2 CURRENT BACKGROUND/AVG 42
PENTANE (C-5) 0 @ 9654.00000 0 @ 9654.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY Tuffaceous siltstone, Tuffaceous sandstone, Sand, Coal
PRESENT LITHOLOGY 50%Tuffaceous sandstone 50%Tuffaceous siltstone
DAILY ACTIVITY
SUMMARY
Drilling ahead:sliding and rotating, while dropping angle. WOB 8 RPM 60 TORQ 8-9K GPM 300 SPP 3400. Perform short trip to confirm
wellbore stability - tight spot @ 9343'. TIH to btm and sweep hole to circ. out gas - max gas unit:1800. Con't to drill ahead: sliding and
rotating, while taking survey as per required to 9653' at report time.
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 07, 2014 DEPTH 10547.00000 PRESENT OPERATION POOH
TIME 2359 YESTERDAY 9654.00000
24 HOUR FOOTAGE 893
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 389.5 @ 10186' 1.4 @ 10089' 76.3 22.32904 FT/HR
SURFACE TORQUE 9556 @ 10186' 8172 @ 10112' 8970.7 8770.01953 FT-LBS
WEIGHT ON BIT 11 @ 10491' 4 @ 10360' 8.6 11.93000 KLBS
ROTARY RPM 61 @ 10157' 51 @ 10391' 55.6 59.28000 RPM
PUMP PRESSURE 3713 @ 9992' 2395 @ 10236' 3440.4 3345.52002 PSI
DRILLING MUD REPORT DEPTH 10547 / 9969
MW 11.5 VIS 70 PV 34 YP 34 Gels 10/22/29 FL 3.8 CL- 50000
FC 1/1 SOL 18 SD 0.5 OIL 2/80 MBT 8.75 pH 9.2 Ca+ 160 Alk 0.8
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 637 @ 9807' 25 @ 10339' 128.6 TRIP GAS
CUTTING GAS @ @ WIPER GAS
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 151739 @ 9757' 4832 @ 10339' 26471.3 CONNECTION GAS HIGH
ETHANE (C-2) 339 @ 10362' 4 @ 10062' 62.9 CONNECTION GAS AVG
PROPANE (C-3) 33 @ 10131' 0 @ 10048' 5.6 CONNECTION GAS CURRENT
BUTANE (C-4) 0 @ 10547' 0 @ 10547' 0.0 CURRENT BACKGROUND/AVG pumps off
PENTANE (C-5) 0 @ 10547' 0 @ 10547' 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY Tuffaceous siltstone, Tuffaceous sandstone, Sand, Coal, Carbonaceous shale/siltstone
PRESENT LITHOLOGY 40% Tuffaceous sandstone, 30% Tuffaceous siltstone, 10%Sand, 10% Coal 10% Carbonaceous shale/siltstone
DAILY ACTIVITY
SUMMARY
`Drilling ahead. Completed slides. WOB 8-10 RPM 70 TORQ 9K GPM 280 SPP 3300. Con't to drill to section's TD @ 10547', TVD 9969.
CBU and Clean hole for trip; take final survey and slow pump rates. Currently @ 9548' while TOOH at report time.
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 08, 2014 DEPTH 10547' PRESENT OPERATION Circulating high gas
TIME 2359 YESTERDAY 10547'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
10448.6 0.91 67.4 9870.34
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 389.5 @ 10186' 1.4 @ 10089' 76.3 22.32904 FT/HR
SURFACE TORQUE 9556 @ 10186' 8172 @ 10112' 8970.7 8770.01953 FT-LBS
WEIGHT ON BIT 11 @ 10491' 4 @ 10360' 8.6 11.93000 KLBS
ROTARY RPM 61 @ 10157' 51 @ 10391' 55.6 59.28000 RPM
PUMP PRESSURE 3713 @ 9992' 2395 @ 10236' 3440.4 3345.52002 PSI
DRILLING MUD REPORT DEPTH 10547 / 9969
MW 12.1 VIS 71 PV 32 YP 41 Gels 9/15/26 FL 4 CL- 49000
FC 1/1 SOL 19.5 SD 0.5 OIL 2/79 MBT 9 pH 9.5 Ca+ 160 Alk 0.9
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 2152 @ 0830 HRS @ TRIP GAS
CUTTING GAS @ @ WIPER GAS 2152
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1600
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY Tuffaceous siltstone, Tuffaceous sandstone, Sand, Coal, Carbonaceous shale/siltstone
PRESENT LITHOLOGY 40% Tuffaceous sandstone, 30% Tuffaceous siltstone, 10%Sand, 10% Coal 10% Carbonaceous shale/siltstone
DAILY ACTIVITY
SUMMARY
Continue to TOH to the shoe. Back ream 10203' to 10111'. High gas while circulating at the shoe. Shut in well and circulate through the
choke. SICP 260 psi. 8 bbl pit gain. Weight up to 12.1 ppg. Circulate out high gas. Slip and cut drilling line. RIH stagewise and con't to use
recommended well control practice to circ out gas, while condition'n fluid density to 12.1 ppg.
CANRIG PERSONNEL ON BOARD 4 DAILY COST $3028.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 09, 2014 DEPTH 10547' PRESENT OPERATION TIH
TIME 2359 YESTERDAY 10547'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
10448.6 0.91 67.4 9870.34
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
4 4.78" PDC 12396253 6118'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH 10547 / 9969
MW 12.1 VIS 97 PV 38 YP 39 Gels 10/23/30 FL 4 CL- 49000
FC 1/1 SOL 19.5 SD 0.5 OIL 2/79 MBT 8.75 pH 9.4 Ca+ 160 Alk 0.8
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 2267 @ 0242 HRS @ TRIP GAS
CUTTING GAS @ @ WIPER GAS 2267
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG Pumps Offf
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY Tuffaceous siltstone, Tuffaceous sandstone, Sand, Coal, Carbonaceous shale/siltstone
PRESENT LITHOLOGY 40% Tuffaceous sandstone, 30% Tuffaceous siltstone, 10%Sand, 10% Coal 10% Carbonaceous shale/siltstone
DAILY
ACTIVITY
SUMMARY
RIH on elevators from 7227' to 9300'. Shut in well and circulate out gas (1600 units) while weighting up to 12.1 ppg. Open well and monitor.
Continue to RIH to 10547'. Circulate out gas (2300 units) through flow line. Ream down last stand. Pump sweep around. Simulate connection.
CBU. High gas 80 units. Flow check well. Pull 5 stands. Pump slug. POOH to shoe. Monitor well. CBU. POOH laying down drill pipe. RIH
finger's DPs for L/D purpose; 5131' depth as @ report time.
CANRIG PERSONNEL ON BOARD 2 DAILY COST $ 2148.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 10, 2014 DEPTH 10547' PRESENT OPERATION TIH with casing
TIME 2359 YESTERDAY 10547'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
10448.6 0.91 67.4 9870.34
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH 10547 / 9969
MW 12.1 VIS 80 PV 33 YP 40 Gels 9/19/27 FL 4.0 CL- 49000
FC 1/1 SOL 19.5 SD 0.5 OIL 2/79 MBT 8.75 pH 9.3 Ca+ 160 Alk 0.8
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS
CUTTING GAS @ @ WIPER GAS 247
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY
SUMMARY
Continue to lay down 4 1/2" drill pipe. Lay down BHA. Clear rig floor. Held PJSM: R/u Tesco CRT. Dummy run landing joint. Test upper
rams. Held PJSM: Run 5-in casing t/4924' as @ report hour; breaking circ. every 500' as per DSVs directive.
CANRIG PERSONNEL ON BOARD 2 DAILY COST $ 2148.50
REPORT BY D Muller
Hilcorp Alaska, LLC
DAILY WELLSITE REPORT
KBU 23-05
REPORT FOR M Leslie / B Farrell
DATE Jun 11, 2014 DEPTH 10547' PRESENT OPERATION Well cemented.
TIME 2359 YESTERDAY 10547'
24 HOUR FOOTAGE 0
CASING INFORMATION 10.75" @ MD1520' / TVD 1475' 7.625" @ MD 6108' 5" @ MD 10535'
SURVEY DATA
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
10448.6 0.91 67.4 9870.34
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ FT-LBS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH 10547 / 9969
MW 12.1 VIS 80 PV 33 YP 40 Gels 9/19/27 FL 4.0 CL- 49000
FC 1/1 SOL 19.5 SD 0.5 OIL 2/79 MBT 8.75 pH 9.3 Ca+ 160 Alk 0.8
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 2026 @ @ TRIP GAS 2026
CUTTING GAS @ @ WIPER GAS
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) @ @ CONNECTION GAS HIGH
ETHANE (C-2) @ @ CONNECTION GAS AVG
PROPANE (C-3) @ @ CONNECTION GAS CURRENT
BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG
PENTANE (C-5) @ @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY
PRESENT LITHOLOGY
DAILY ACTIVITY SUMMARY Finish running casing to 10535'. Rig up cement tools and cement.
CANRIG PERSONNEL ON BOARD 2 DAILY COST $ 2148.50
REPORT BY D Muller
