Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout215-2187. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU S-113BL1
Acid Stim, Ext Perf w CTU
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
215-218
50-029-23094-60-00
15368
Conductor
Surface
Intermediate
Production
Solid / Slotted Liner
6709
80
5553
13008
2530
15368
20"
10-3/4"
7"
2-3/8"
6709
34 - 114
34 - 5587
31 - 13039
12838 - 15368
34 - 114
34 - 3371
31 - 6767
6589 - 6709
None
470
2480
5410
11780
None
1490
5210
7240
11200
13100 - 15368
3-1/2" 9.2# L-80 29 - 12942
6817 - 6709
Structural
4-1/2" Baker S-3 Perm Packer
Torin Roschinger
Operations Manager
Hunter Gates
hunter.gates@hilcorp.com
(907) 777-8326
PRUDHOE BAY, Aurora Oil
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028257, 0028258, 0028259
29 - 6680
Slotted liner from 15240 -15355'MD & and Perforations from 13100 - 15240'MD.
Pump 192.7-bbls 15% HCl in two stages with final treating pressure = 2250-psi.
66
229
312
407
371
2430
1300
1600
240
180
325-176
13b. Pools active after work:Aurora Oil
No SSSV Installed
12884, 6629
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662)
Date: 2025.09.19 05:06:09 -
08'00'
Torin Roschinger
(4662)
By Grace Christianson at 9:53 am, Sep 19, 2025
J.Lau 11/6/25
RBDMS JSB 092525
ACTIVITYDATE SUMMARY
9/3/2025
LRS #1 1.5" 0.134WT GT-110
Objective: Mill/FCO, Acidize, Ext Adperf
Stage up on location while testers and well support RU.
***In progress***
9/3/2025 LRS Well Test Unit #6. Begin WSR 9/3/25. Assist CTU. Continue WSR 9/4/25
9/4/2025
LRS #1 1.5" 0.134WT GT-110
Objective: Mill/FCO, Acidize, GR/CCL, Ext Adperf
Stage up on location while testers and well support RU. Hot to pop locked up in 1bbl.
MU/RIH with ice pick nozzle. Broke through a few ice bridges. RIH to 5500', POOH.
Well still basically jug tight. MU 2.80 turbo scale mill & Motor. RIH
***In progress***
9/4/2025
LRS Well Test Unit #6. Continue WSR from 9/3/25. Assist CTU. Continue WSR on
9/5/25
9/4/2025
T/I/O = 855/1900/0 (HOT OIL TBG WASH) Pump 1 bbl 60/40 TBG Lockup @ 2500
psi. CTU in control of well upon departure. Pad op notified upon completion.
FWHPs = 2500/1900/0
9/5/2025
LRS Well Test Unit #6. Continue WSR from 9/4/25. Assist CTU. Continue WSR on
9/6/25
9/5/2025
LRS #1 1.5" 0.134WT GT-110
Objective: Mill/FCO, Acidize, GR/CCL, Ext Adperf
RIH, Dry Tag Top of liner 12,835' CTM, Confirm Tag. Clean up on top of the LTP.
Paint flag. Pump Gel Pill & chase OOH. Break down 2.80" Mill BHA. MU 1.69" MHA.
& 1.76: Mill. RIH. **See job log on getting through heel section ~13250'**.FCO from
top of liner to 15,204' CTM. Pumping Gel sweeps.
***In progress***
9/6/2025
(PERFORATING) **Assist CTU** First Stage. Pump 6 bbls 1% KCL followed by 75.7
bbls 15% HCL and 5 bbls 1% KCL down TBG. Let Soak for 30 Min. Pump 71 bbls 1%
KCL Down TBG for Overflush. Pump 15 bbls Scale inhibitor follwoed by 10 bbls Oil
Seeker down TBG. Second Stage. Pump 33 bbls 1% KCL followed by 117 bbls 15%
HCL down TBG. Pumped 116 bbls of KCL, 25 bbls of scale inhibitor followed by
another 122 bbls of KCL & 3 bbls of 60/40 to clear lines.
***Job continued to 9/7/2025***
9/6/2025
LRS #1 1.5" 0.134WT GT-110
Objective: Mill/FCO, Acidize, GR/CCL, Ext Adperf
Finish FCO from 15,255' to 15,355' CTM, Pump Gel sweep & chase OOH. Change
out Packoffs. MU slim DJN bha for acid. L&K well w/2%KCL. Base injectivity 2.5bpm
2040psi, 1bpm = 1373psi. Pump 30bbl diesel FP (3500' MD/2600'TVD). Pump
15%HCL acid schedule as per program from 15240-15355 and 13100-15240.
***In progress***
9/6/2025
LRS Well Test Unit #6. Continue WSR from 9/5/25. Assist CTU. Continue WSR on
9/7/25
Daily Report of Well Operations
PBU S-113B
Daily Report of Well Operations
PBU S-113B
9/7/2025 RDMO. Released from CTU.
9/7/2025
LRS #1 1.5" 0.134WT GT-110
Objective: Mill/FCO, Acidize, GR/CCL, Ext Adperf
Finish 15%HCL acid schedule as per program. from 13100-15240. POOH. Load
well with 2% KCL. Monitor well. KWF calculated to be 9.1ppg. Log HES memory log
from 15,000 to 12,800'. L&K well with 9.1ppg brine.
MU & RIH w/ Tri Point 1.56" x 167.95' Titan Perf Gun Run #1. 6SPF, 60deg phase.
(1.68") Swell. Correct for top shot at coil flag. Perforate interval 13,833' - 14,000'.
POOH.
*H2S/LEL monitors bump tested. PT safety joint. Well Control Drill with Day/Night
Crew. Tagged up on the Brass
***In Progress***
9/7/2025
LRS Well Test Unit #6. Continue WSR from 9/6/25. Assist CTU Continue WSR on
9/8/25
9/8/2025
LRS #1 1.5" 0.134WT GT-110
Objective: Mill/FCO, Acidize, GR/CCL, Ext Adperf
Finish POOH. All shots fired, ball recovered. MU & RIH w/ Tri Point 1.56" Titan Perf
gun, 6spf, 60 deg phase. RIH. Correct for top shot at Coil Flag .
Perforate interval #2 , (13,410' - 13566'). Pooh. All shots fired, ball recovered. RDMO.
*H2S/LEL monitors bump tested. PT safety joint. Well Control Drill with Day/Night
Crew. Tagged up on the Brass
***Job Complete ***
9/8/2025
LRS Well Test Unit #6. Continue WSR from 9/7/25. Assist CTU Continue WSR on
9/9/25
9/9/2025
LRS Well Test Unit #6. Continue WSR from 9/8/25. Assist CTU Continue WSR on
9/10/25
9/11/2025
LRS Well Test Unit #6 Continue WSR from 9/10/25. Post coil flowback, RD. End
WSR 9/11/25
7. If perforating:
1. Type of Request:
2. Operator Name:
3. Address:
4. Current Well Class:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Property Designation (Lease Number):10. Field:
Abandon
Suspend
Plug for Redrill Perforate New Pool
Perforate
Plug Perforations
Re-enter Susp Well
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well
Other:
Change Approved Program
Operations shutdown
What Regulation or Conservation Order governs well spacing in this pool?
Will perfs require a spacing exception due to property boundaries?Yes No
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
PRESENT WELL CONDITION SUMMARY
Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft):
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
12. Attachments:
14. Estimated Date for
Commencing Operations:
13. Well Class after proposed work:
15. Well Status after proposed work:
16. Verbal Approval:
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal.
Proposal Summary Wellbore schematic
BOP SketchDetailed Operations Program
OIL
GAS
WINJ
WAG
GINJ
WDSPL
GSTOR
Op Shutdown
Suspended
SPLUG
Abandoned
ServiceDevelopmentStratigraphicExploratory
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
AOGCC USE ONLY
Commission Representative:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other Conditions of Approval:
Post Initial Injection MIT Req'd?Yes No
Subsequent Form Required:
Approved By:Date:
APPROVED BY
THE AOGCCCOMMISSIONER
PBU S-113BL1
Acid Stim, Ext Perf w
CTU
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK
99503
215-218
50-029-23094-60-00
ADL 0028257, 0028258, 0028259
15368
Conductor
Surface
Intermediate
Production
Solid / Slotted Liner
6709
80
5553
13008
2530
15368
20"
10-3/4"
7"
2-3/8"
6709
34 - 114
34 - 5587
31 - 13039
12838 - 15368
3000
34 - 114
34 - 3371
31 - 6767
6589 - 6709
None
470
2480
5410
11780
None
1490
5210
7240
11200
13100 - 15368 3-1/2" 9.2# L-80 29 - 129426821 - 6709
Structural
4-1/2" Baker S-3 Perm Packer
No SSSV Installed
12884, 6629
Date:
Torin Roschinger
Operations Manager
Hunter Gates
hunter.gates@hilcorp.com
(907) 777-8326
PRUDHOE BAY
4/9/2025
Current Pools:
AURORA OIL
Proposed Pools:
AURORA OIL
Suspension Expiration Date:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 3:05 pm, Mar 27, 2025
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662)
Date: 2025.03.27 11:58:00 -
08'00'
Torin Roschinger
(4662)
325-176
JJL 4/2/25
A.Dewhurst 12MAY25
10-404
*Perforating gun not to exceed 500'.
*Reestablish pressure containment prior to perforating.
*Perform and document well control drill on each shift using attached standing orders and verifycorrect XO for safety joint.
*Ensure well is dead before breaking containment
SDR-4/2/25*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2025.05.13 09:39:40 -08'00'05/13/25
RBDMS JSB 051425
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
Well Name:S-113 Permit to Drill:215-218
Current Status:Operable, PAL API Number:50-029-23094-02/60
Estimated Start Date:4/9/2025 Estimated Duration:5days
Regulatory Contact:Abbie Barker Service Lines:CT/FB
First Call Engineer:Hunter Gates (215) 498-7274 (M)(907) 777-8326 (O)
Second Call Engineer:Tyson Shriver (406) 690-6385 (M)
Current Bottom Hole Pressure:3,017 psi at 6,700’ TVDss
Maximum Potential Surface Pressure:3,000 psi
Last SI WHP:150 psi March 17
th, 2025
Min ID:1.781” @ 12,841’ MD R-Nipple
Max Angle:113 deg @ 13,394’ MD
Last Tag:12,783’ SLM w/ bailer
Brief Well Summary:
S-113B is an operable producer that has been SI since February 2024. Fluid rate rapidly declined near the end of
2020. The well required a HOT to POP in February 2024, however, production was short-lived due to hydrate
issues. In February and March of 2024, bailer runs indicated high tags above our LTP. Drive down and pump bailer
runs provided recovery of “hydrates/asphaltenes/scale/rocks”.
Current Status:
Shut-In – Operable Producer, hydrate issues, unstable flow.
Objective:
Plan is to pick up a motor and mill and RIH to perform a gas lift assisted FCO with the portable test separator to
PBTD of 15,368’. Squeeze 50 bbls of 15% HCl into the slotted liner section of the well and then jet 100 bbls of 15%
HCl across the perforated section. Then we will make 2 extended perforating runs to perforate a new 323’ of
Kuparuk perfs. Flow well back through portable test separator.
Existing Casing/Tubing Program:
String Pipe #/ft Grade Top Bottom
Surface csg 10-3/4”45.5 L-80 Surface 5587’
Prod csg (original hole)7”26 L-80 Surface 13,491’
Prod tbg 3.5”9.2 L-80 Surface 12,942’
Prod Liner Solid Pipe (S-113B L1)2-3/8”4.7 L-80 12,834’15,240’
Prod Liner Slotted (S-113B L1)2-3/8”4.7 L-80 15,240’15,368’
Acid treatment targets:
Type Top Bottom Net perf Footage
Perforated Liner 13,100’15,240’190’
Slotted Liner 15,240’15,368’128’
Total 318’
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
Procedure
Fullbore/Testers
1. MIRU portable test separator in tandem with service coil to help with GL assisted FCO.
2. Kick well off 12-24 hrs before service coil MIRU.
3. Communicate with PCC to optimize lift gas volume. Begin at 1 MMCFD working up to a max of 3 MMCFD.
4. Kick on gas lift to help lift any solids to surface taking liquid returns to tanks and sending gas back down
the flowline. Test unit to help monitor returns and gas lift rates for clean out.
Coil Tubing
1. MIRU 1.5” Service CT.
2. MU and RIH w/ motor and mill with a goal of completing a milling run in the 3-1/2” tubing down to liner
top at 12,834’ MD using 2% KCl as KWF.Paint flag at liner top.
a. ***In case of any aggressively tight/sticky spots, call OE in town before trying to work it too
hard***.
3. Pump final gel sweep and chase OOH.
4. POOH. MU and RIH w/ milling BHA for 2-3/8” liner (min ID 1.781”) keeping well flowing through test unit.
5. RIH to top of liner at 12,834’ and begin milling run.
6. Continue milling to PBTD. If encountering hydraulics issues inside 2-3/8” liner, back off on GL pressure to
achieve better WOB.
7. Once FCO to PBTD is completed, pump a final gel pill and chase uphole above screened orifice at 12,802’
MD. Dry drift to PBTD (or deepest point that was coil made it to) to ensure there are no hang-ups or tight
spots that we need to reciprocate through.
8. After we dry drift clean to bottom, POOH and LD milling BHA.
a. ***NOTE*** Freeze Protect testers if necessary when we shut the well in.
9. MU and RIH w/ Schlumberger 1-11/16” Jet Blaster BHA to PBTD.
10. Ensure well is fluid packed with diesel.
11. Hold safety meeting prior to initiating acid job.
12. Begin pumping into the slotted liner portion of the wellbore to obtain an injectivity test.
13. Pump acid job according to pump schedule below.Max tubing surface pressure is 3000 psi. Monitor IAP
during FCO.
14. Wash across slotted liner portion from PBTD (15,368’ MD) to top of liner at 15,240’ MD with CTBS closed
to squeeze acid into formation.
Pump Schedule Stage 1
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GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
15. Once diverter is pumped, initiate second acid stage as per pump schedule below. Wash equivalent of ~25
gal/ft across all 6 perf intervals from 15,240’ up to 13,100’.
Pump Schedule Stage 2
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16. POOH w/ coil pumping keeping hole filled.
17. Prepare for extended perforation operations.
18. MU GR/CCL and 1.75” nozzle. RIH to 15,000’ MD and pull log to ~12,900’ MD. Paint coil flag for
subsequent perf run.
19. POOH and correlate for perf run.
Coil – Extended Perforating
Notes:
x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations
x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS
coverage is required.
The well will be killed and monitored before making up the perf guns. This is generally done during the
drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating
bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by
bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head.
20. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through
the brass upon POOH with guns.
21. Well should be killed already but utilize 2% KCl KWF on location to ensure that well is properly dead.
a. Wellbore Volume to PBTD = 122 bbls
b. 2-3/8” Liner – 2,534’ X .0039 bpf = 10 bbls
c. 3.5” Tubing – 12,834’ X .0087 bpf = 112 bbls
22. At surface, prepare for deployment of TCP guns.
23. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF as needed. Maintain hole fill
taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
24.Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control
steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once
the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible
near the working platform for quick deployment if necessary.
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one
time to confirm the threads are compatible.
25. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly
monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
Perf Schedule
Use 1.56” Millenium Charge
Perf Interval Perf Length Gun Length Max Swell
Run #1
13,833’ – 14,000’
167’ 167’ 1.69”
26. Make up QTS and PT same.
27. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above.
Note any tubing pressure change in WSR.
28. After perforating, PUH to top of liner tail to ensure debris doesn’t fall in on the guns and stick the BHA.
Confirm well is dead and re-kill if necessary before pulling to surface.
29. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary.
30. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and
commencing breakdown of TCP gun string.
31. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA.
32. At surface, prepare for second deployment of TCP guns.
33. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF as needed. Maintain hole fill
taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
34.Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control
steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once
the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible
near the working platform for quick deployment if necessary.
b.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one
time to confirm the threads are compatible.
35. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly
monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
Perf Schedule
Use 1.56” Millenium Charge
Perf Interval Perf Length Gun Length Swell
Run #12
13,410’ – 13,566’
156’ 156’ 1.69”
36. Make up QTS and PT same.
37. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above.
Note any tubing pressure change in WSR.
38. After perforating, PUH to top of liner tail to ensure debris doesn’t fall in on the guns and stick the BHA.
Confirm well is dead and re-kill if necessary, before pulling to surface.
39. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary.
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
40. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and
commencing breakdown of TCP gun string.
41. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA.
42. RDMO CTU.
43. Turn well over to portable test unit for acid flowback.
Fullbore/Testers
1. Communicate with WPO to determine what neighboring well’s flowline can be utilized for flowback. S-103
may be a good potential candidate.
2. Review RP: Acid Flowback to Portable Separator, Tanks, or Production. Target 1.5-2 MMCFD of gas lift to
kick well off.
3. Ensure flowback tanks include soda ash or similar neutralizer to neutralize pH of the fluids being flowed
back and disposed of.
b. pH >2 and <12 for disposal at GNI
4. Contact PCC and let them know flowback is ready to commence.
5. Open the well and begin unloading to tanks.
6. Once a bottoms up volume has been flowed back, increase GL rate as necessary to optimize flow and
adjust choke to full open, if not already there.
7. Continue flowback to tanks, monitoring pH.
a. Appropriate PPE should be worn when sampling fluid pH.
8. Once pH is 6.5 to 7, solids are <0.2% and emulsions are <2%, it is acceptable to divert returns to
production.
9. Continue to flow until well is stable.
10. Conduct an 8 hour well test. Piggyback with the pad test separator, if possible.
11. RDMO.
Attachments:
x Current Wellbore Schematic
x Proposed Wellbore Schematic
x Tie In Log
x BOPE Schematic
x Standing Orders
x Equipment Layout Diagram
x Sundry Change Form
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
Current Wellbore Schematic:
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
Proposed Wellbore Schematic:
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
Tie In Log:
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
BOP Schematic:
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
GL Assisted FCO & Acid
Stimulation
Well: S-113B
PTD: 215-218
Changes to Approved Sundry Procedure
Date:
Subject:
Sundry #:
Any modifications to an approved sundry will be documented and approved below. Changes to an approved
sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is
required before implementing the change.
Step Page Date Procedure Change
HNS
Prepared
BBy (Initials)
HNS
Approved
By
(Initials)
AOGCC Written
Approval
Received
(Person and
Date)
Approval:
Operations Manager Date
Prepared:
Operations Engineer Date
BA EUGHR 0 PRINT DISTRIBUTION LIST
I ES
a GE company
COMPANY BP Exploration Alaska Inc.
WELL NAME S-113BL1
FIELD Prudhoe Bay Unit
COUNTY PRUDHOEBAY
BHI DISTRICT
21-218
30 90 4
Please sign and return one copy of this transmittal form to:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.comt
to acknowledge recei of this data.
LOG TYPE RPM:PNC3D
LOG DATE March 30, 2019
AUTHORIZED BY Paul Canizares
EMAIL Paul. Canizareslai7bhge com TODAYS DATE June 17, 2019
Revision
STATUS Final Replacement: No Details:
Rev. Requested by: ---
COMPANY
ADDRESS (FEDEX'MLL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
I BP North Slope.
EOA, PBOC, PRB-20 (Office 109)
D&C Wells Project Aides
Attn: Rend. Glassmaker & Peggy O'Neil
1900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
'ATO 3-344
700 G Street
Anchorage, AK 99501
3 Exxon.Mahil, Alaska
(Attn: Lynda M. Yaskell and/or Lisa Boggs
:3201 C Street, Suite 505
,Anchorage, AK 99503
41, State of Alaska - AOGCC
Attn: Makana Bender
,333 W. 7th Ave, Suite 100
'Anchorage, Alaska 99501
5 DNR -Division of Oil &Gas ***
,Attn: Garret. Brown
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
FIELDIFINAL
CD/DVD
FINAL
PRELIM
LOGS
(las, dlis, PDF, META,
SURVEY
REPORT
LOGS
CGM, Final Surveys)
(Compass)
# OF PKINI
UF PKIN I
# OF COPIES
# OF COPIES
# OF COPIES
V � V
RECEIVEn
j
6 BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1 j
l 90 E. Benson Blvd.
Anchorage, Alaska 99508
Attn: Gerardo Cedillo
TOTALS FOR THIS PAGE: 0 1 4 0 0
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
RECEIVED
Ann 4 7 ,.
1. Operations Performed
Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations d g
ph
Suspend ❑ Perforate 21 Other Stimulate ❑ Alter Casing ❑ Chan e A s(L_Y
�
Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑
2. Operator Name: BP Exploration (Alaska), Inc
4. Well Class Before Work
Development El Exploratory ❑
5. Permit to Dnll Number: 215-218
3, Address: P.O. Box 196612 Anchorage,
AK 99519-6612
1 Stratigraphic ❑ Service ❑
1 6. API Number: 50-029-23094-60-00
7. Property Designation (Lease Number): ADL 0028258, 028258 & 028259
8, Well Name and Number: PBU S-113131-1
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10. Field/Pools:
PRUDHOE BAY. AURORA OIL
11. Present Well Condition Summary:
Total Depth: measured 15368 feet Plugs measured None feet
true vertical 6709 feet Junk measured None feet
Effective Depth: measured 15368 feet Packer measured 12884 feet
true vertical 6709 feet Packer true vertical 6629 feet
Casing: Length: Size: MD: TVD: Burst: Collapse.
Structural
Conductor 80 20" 33-113 33-113 1490 470
Surface 5553 10-3/4" 33-5586 33-3370 5210 2480
Intermediate 13008 7" 31 -13039 31 -6767 7240 5410
Production
Liner 2530 2-3/8" 12834 - 15368 6585-6709 11200 11780
13039 - 15368 feet
Perforation Depth: Measured depth
True vertical depth: 6767-6709 feet
Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 29-12942 29-6680
Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Parker 12884 8629
true vertical depth)
no SSSV
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil -Bbl
Gas-Mcf
Water -Bbl
Casing Pressure
Tubing Pressure
Prior to well operation:
Lateral
Subsequent to operation:
Lateral
14. Attachments (inquired Ver20 Me 25.070.25.071, & 25.283)
15. Well Class after work:
Daily Report of Well Operations 0
Exploratory ❑ Development ® Service ❑ Stretigraphic ❑
16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑
Copies of Logs and Surveys Run ❑
Printed and Electronic Fracture Stimulation Data ❑
1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. I herebycertify that the foregoing y g Sundry Number or N/A if C.O. Exempt:
fy regoin I5 We and correct [o the best of m knowledge.
WA
Authorized Name: Lea Duong Contact Name: Lea Duong
Authorized Title: Production Engineer Contact Email: Lea.DuongAbp.cem
Date
Authorized Signature: Contact Phone: +1 907 564 4840
Form 10-404 Revised 04/2017 AfS /KGR44 R'Y RBDMS! -f^/APR 18 2019 Submit Original Only
Daily Report of Well Operations
S-113BL1
ACTIVITYDATF SI IMMARY
CTU#8 1.5" CT. Job Scope: Mill Liner, RPM Log, Adperf
MIRU CTU.
3/28/2019
***Continue Job on 3/29/19***
CTU#8 1.5" CT Job Scope: Mill Liner, RPM Log, Adperf
MU & RIH w/ Baker 1.69" Milling Assembly w/ 1.77" Diamond Speed Mill. Dry Tag PBTD at 15367'.
Re -drift 14,200'- 14,700' with no issues. POOH. C/O packoffs. MU & RIH w/ Baker RPM w/ knuckle
joint and rollers. Log 20fpm down pass from 13050'- PBTD. Tag TD at 15357'. Log 20fpm Up
pass from TD - 12650'. Flagged Pipe at 13100.09'. Pooh.
3/29/2019
***Continue Job on 3/30/19 WSR***
CTU#8 1.5" CT. Job Scope: Mill Liner, RPM Log, Adperf
Pooh with RPM BHA. Receive good data (+18.5' Correction). Correlate to Baker Hughes RPM Log
15 -Oct -2016. MU & RIH w/ HES 1.56" x 32' Perfecta Perf Gun #1. Tag PBTD and correct depth.
Perforate interval 15336- 15368'. POOH. All shots fired, ball recovered. MU & RIH w/ HES 1.56" x
32' Perfecta Pert Gun #2. Tag PBTD and correct depth. Perforate interval 15208'- 15240'. Pooh
All shots fired, ball recovered. MU & RIH w/ HES 1.56" x 32' Perfecta Perf Gun #3. Tag PBTD &
correct depth. Puh to shot depth.
3/30/2019
***In Progress***
CTU#8 1.5" CT. Job Scope: Mill Liner, RPM Log, Adperf
Perforate Interval 15075'- 15107'. Pooh. All shots fired, ball recovered. Stack down & change
packoffs. MU & RIH w/ HES 1.56" x 32' Perfecta Perf Gun #4, Perforate Interval 14996- 15028'.
POOH. All shots fired, ball recovered. Perform Weekly BOP Test. MU & RIH w/ HES 1.56" x 32'
Perfecta Perf Gun #5. Tag PBTD & correct depth. Puh to shot depth.
3/31/2019
***Continue Job on 4/1/19 WSR***
CTU#8 1.5" CT Job Scope: Mill Liner, RPM Log, Adperf
Perforate Interval 14450'- 14482'. Pooh. All shots fired, ball recovered. MU & RIH w/ Perf Gun #6.
Perforate 13100'- 13132'. Freeze Protect Tbg to 6900' and / 3850' tvd. Blowdown reel w/ N2. Rig
own CTU.
4/1/2019
***Job Complete***
VUaLFFAD =
13-518" 5M FMC
ACTUATOR=
DEV
OKB. BEV =
70.33'
REF BEV =
70.33'
BF. ELEV =
37.48'
KOP=
700'
Max Angle =
113- Q 13394'
MD=
UM()aWm
6700'
,TVD.
__
6700'SS
10-314" CSG, 45.5#, L-80, D = 9.950"
Minimum ID = 1.781" @ 12841'
2-3/8" R -NIPPLE IN NS PTSA
S-1 13 B ANGL >E 70T@ 5009'. MAX D SE37' @ 11331 SELL
L1
1 2367' 1
GAS LFT MANDRELS
ST
MD
TVD
DEV
TYPE
VLV
LATCH
FORT
DATE
4
6713
3800
69
MNG
DOME
RK
16
11128/18
3
11147
5598
62
MNG
DOME
RK
16
11/28/18
2
12712
6480
33
MNG
DMY
RK
0
07/12102
1
128021
6557 ii
30
MMS
SO
R( i
22
11/28/18
12834' 3-12"OWBN X-SPANLTPw/NS
12841' 1--�2-3/8' R NP. D=1.781'
12662 lysirz-nesx rvN,o=z.e13-� BEHIND
CT LNR
12884' 7" X 4-12" BAKER 3-3 PKR. D = 3.875"
13-112"HES X NP. D=2.813" 1
1(2.64' FLOW COLLAR D= 1.930')
= 2.992" 12942' 12942' 3-12" WLEG, D = 2.992" (BR3aND CT LNN)
0/07116) 13038' 12932' ELMDTT (LOGGFD0728/02)
PERFORATION SL""ARY
REF LOG: BAKER RPM ON 10/15116
ANGLE AT TOP PERP NA
Note: Refer to Production DB for historical perf data
PBTD —L_13404-
26#, L-80 BTC, ID= 8.276' 1349V
FLOW COLLAR, D=
MLLOUT WINDOW (S-1138 L1) 13039'-13044' 1
FLOW COLLAR D = 1.930')
w /30 X .5" HOLES
' SOLD LNR, 12845' - 15240' \ \ \
L-80 TH511,
bpf, ID = 1.995"
\ \7
2-3/8" SLTD LNR, 15240' - 15368'
4.7#, L-80 TF1511, S-1138 L1
.0039 bpf, D - 1.995'
DATE REV BY COMV64T8 DATE REV BY COMMENTS
07/18(02 DAC/KK ORIGINAL COMPLETION 1127118 M>/JMD FULL DREAMGATa-ff1WRECOVI3iED FISH
18/16116 NORDIC2 CTD ML (S -113B L1) 01/09/19 JL/JMJ GLV CIO (1128/18)
11/07/16 ZB/JMJ FINAL ODEAPPROVAL 04/02119 TFA/JrVU ADfE:FS
0724/18 JUJPoD ADPE MFS 8 SETIM11 I CBP
0724118 CJWJMJ GLV 40 (07/03/18)
0724118 CJWJMD SET DREAM CATCHER (07104118)
AURORA UIT
WELL S-1138 L1
PERMIT ND: 2152180
AR Nb: 50-029-23094-02160
T12K R12E 739 FNL 8 783'PAIL
BP Brploration (Alaska)
S -113B
2-12"
6
13014 - 13038
S
07/28/02
09/18/16
2-1/2
6
13018-13038
S
11/08/0209/18/16
2-12"
6
13038 - 13098
S
06129/14
09/18116
OH
13039 - 13044
O
10/07/16
S -113B
L1
1.56"
6
13100 - 13132
O
04/01/19
1.56"
6
14420- 14450
O
06/28118
1.56"
6
14450- 14482
O
04/01/19
1.56'
6
14996-15028
O
03/31/19
1.56"
6
15075-15107
O
03/31/19
1.56"
6
15208 - 15240
O
03130/19
SLTD
15240-15368
SLOT
10/13/16
1.56'
6
15336- 15368
O
03/30/19
PBTD —L_13404-
26#, L-80 BTC, ID= 8.276' 1349V
FLOW COLLAR, D=
MLLOUT WINDOW (S-1138 L1) 13039'-13044' 1
FLOW COLLAR D = 1.930')
w /30 X .5" HOLES
' SOLD LNR, 12845' - 15240' \ \ \
L-80 TH511,
bpf, ID = 1.995"
\ \7
2-3/8" SLTD LNR, 15240' - 15368'
4.7#, L-80 TF1511, S-1138 L1
.0039 bpf, D - 1.995'
DATE REV BY COMV64T8 DATE REV BY COMMENTS
07/18(02 DAC/KK ORIGINAL COMPLETION 1127118 M>/JMD FULL DREAMGATa-ff1WRECOVI3iED FISH
18/16116 NORDIC2 CTD ML (S -113B L1) 01/09/19 JL/JMJ GLV CIO (1128/18)
11/07/16 ZB/JMJ FINAL ODEAPPROVAL 04/02119 TFA/JrVU ADfE:FS
0724/18 JUJPoD ADPE MFS 8 SETIM11 I CBP
0724118 CJWJMJ GLV 40 (07/03/18)
0724118 CJWJMD SET DREAM CATCHER (07104118)
AURORA UIT
WELL S-1138 L1
PERMIT ND: 2152180
AR Nb: 50-029-23094-02160
T12K R12E 739 FNL 8 783'PAIL
BP Brploration (Alaska)
RECEIVE0
STATE OF ALASKA
•ALASKA OIL AND GAS CONSERVATION COM N � Q0�
REPORT OF SUNDRY WELL OPERA S fi
1. Operations Performed
Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operati .,,. 0
Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Apprr.e. -clifirV ❑
Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Liner Top Packer C
2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 215-218
3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0
AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23094-60-00
7. Property Designation(Lease Number): ADL 028259 8. Well Name and Number: PBU S-113BL1
9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools:
PRUDHOE BAY,AURORA OIL
11.Present Well Condition Summary:
Total Depth: measured 15368 feet Plugs measured None feet
true vertical 6709 feet Junk measured None feet
Effective Depth: measured 15368 feet Packer measured 12884 feet
true vertical 6709 feet Packer true vertical 6629 feet
Casing: Length: Size: MD: ND: Burst: Collapse:
Structural
Conductor 80 , 20" 33-113 33-113 1490 470
Surface 5553 10-3/4" 33-5586 33-3370 5210 2480
Intermediate 13460 7" 31-13039 31-6767 7240 5410
Production
Liner 2530 2-3/8" 12838-15368 6588-6709
Perforation Depth: Measured depth:
15240-15366 feet .
True vertical depth: 6714-6709 feet
Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 29-12942 29-6680
Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 12884 6629
true vertical depth)
12.Stimulation or cement squeeze summary:
Intervals treated(measured):
�( .JUN 1 1-'m
Treatment descriptions including volumes used and final pressure: sat
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 36 1131 156 1375 250
Subsequent to operation: No test available 0 640
14.Attachments:(required per 20 AAC 25.070.25.071,825.283) 15.Well Class after work:
Daily Report of Well Operations 0 Exploratory ❑ Development I I Service 0 Stratigraphic 0
Copies of Logs and Surveys Run 0 16.Well Status after work: Oil II Gas 0 WDSPL 0
Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0
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:
N/A
Authorized Name: Alex Youngmun Contact Name: Alex Youngmun
Authorized Title: //��P//roductiony/Engineer Contact Email: younak(ci�bp.com
Authorized Signature: 4410 j+^��/,,.--1 Date: (O///18 Contact Phone: +1 907 564 4864
Form 10-404 Revised 04/2017 ""''1!777 RBDMS JUN 0 6 2018 VT(- 6-//741 ' , Vali g/m9( �Original
• •
Daily Report of Well Operations
PBU S-113B
ACTIVITYDATE SUMMARY
***WELL SHUT IN ON ARRIVAL***(Scale Removal)
STAGE EQUIPMENT
STANDBY FOR WIND
5/19/2018 ***CONT. ON 05/20/2018 WSR***
***CONT. FROM 05/19/18***(Scale Removal)
RAN 2.80" OWEN SETTING TOOL/ PACKER DRIFT& PTSA DRIFT TO DEPLOYMENT SLV @
12838' MD
RAN MAXFIRE PRESS/TEMP TOOLS &2.80" CENT TO DEPLOYMENT SLV @ 12838' MD
5/20/2018 ***CONT. ON 05/21/2018 WSR***
***CONT. FROM 05/20/2018 WSR***(Scale Removal)
SET OWEN LTP& NORTHERN SOLUTIONS PTSA W/ 1.781" R NIPPLE PROFILE ACROSS
DEPLOYMENT SLV @ 12,838' MD
PULLED 2.25" R LOCK AND RETRIEVABLE SEAL GUIDE @ 12,814' SLM.
DRIFTED WITH 10'x 1.75" BAILER TO 13,115' SLM
RAN HES CALIPER FROM 12,900' SLM - 12,600' SLM...GOOD DATA
5/21/2018 ***JOB COMPLETE, WELL LEFT S/I***
T/I/O = 1640/40/VAC. Temp= SI. ALP= 1860 psi, SI @ CV. T FL @ 1920' (17 bbls).
5/21/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 21:30
Fluids Summary
Bbls Type
1.00 Diesel
TREE= - - S 113E
• WB_U-EAD- 13-5!8 SM FMC � NOTES: 3-1/2"CHROME NIPPLES. WELL
ACTUATOR= L1 ANGLE>70" 5009'.MAX DLS:37"@ 13175'.
BEV EV= 70.33
REF BEV= 70.33'
BF.B.EV= 37.48'
KOP= 700* 1 1 2367' [-13-1/2"HES X NP,ID=2.813"
Max Angie- 113"@ 13394'
)
Datum M 6700'
GAS LFT MAPCRB_S
Datum 1VD= 6700'SS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
10314"CSG,45.5#,L-80,13=9.950" —I 5587' i 4 6713 3800 69 I*v$3 DMY RK 0 07/22/17
3 11147 5598 62 MAG DMY RK 0 07/22/17
2 12712 6480 33 MAG DMY RK 0 07/12/02
1 12802 6557 30 MAG DMY RK 0 07/22/17
Minimum ID =1.781"@ 12841'
2-3/8" R-NIPPLE IN NS PTSA 12834' —3-1/2.OWENX-SPANLTPw/NS PTSA,
D=225"(05/21/18)
12838' --2.63"DEPLOYMENT SLEEVE,D=1.92"
12841' }—{2-3/8"R NP,D=1.781' I
12862 --I3-1/2"HES X NP.D=2.813" BEHI D
ITOP OF c NT SHEATH H 12868'-12942' 1 1 CT LIIR
z ilko
12884' --17"X 4-1/2"BAKER S-3 PKR,D=3.875"
12910' H3-1/2-HES X NP,D=2.813"
12930' —13-1/2"HES X NP,D=2.813"
• 12939' —FLOW PLUG#3
(2.64"FLOW COLLAR,D=1.930")
3-1/2"TBG,9.2#,L-80,.0087 bpf,D=2.992" — 12942' -4/,` ►�1► 12942' H3-1/2"WLEG,D=2.992"(B CT LHR)
+am �#�` 12932' H ELMD TT (LOGGED 07/28/02)
• • ►�f4 12971 }—FLOW PLUG#2
(2.64'FLOW COLLAR,D=1.930')
�♦ ►�+
3-1/2"MONOBORE WHPSTOCK(10/07/16) -I 13039' ►► ►;�f N4-LOUT WIDOW(S-1138 L1) 13039'-13044'
PERFORATION SUAAARY ♦.,►..",;� 13695 —FLOW PLUG#1 1
REF LOG:BAKER R!'M ON 10/15/16 ►1 , � (2.64'FLOW COLLAR,D=1. ")
ANGLE AT TOP PERF: N4 "+1►�•4r'�i►•►•w►•-ip
+4fr+►+►A►
Note:Refer to Production DB for historical perf data *4' 4��jt 14600' H RP JT w/RA TA
SIZE SPF INTERVAL Opr(Sqz SHOT SQZ 15240' —1 Jr MAC SLID
51138 •►+~i►*4*1R►►�, C LNRw/30X. "HOLES
•
2-1/2" 6 13014-13038 S 07/28/02 09/18/16 •+ j►i►� \
2-1/2" 6 13018-13038 S 11/08/02 09/18/16 ♦♦♦� "
2-1/2" 6 13038-13098 S 06/29/14 09/18/16 4► j4r'►..j��►*4 \ \ \
OH 13039-13044 0 10/07/16 �+►+►Q�l�4 \ \
►�i'* . 2-3/8"SOLD LN R, 12845'-15240' \ \
S-1138 Ll ''♦4 �► ►
SLID 15240-15368 SLOT 10/13/16 '►��j j►���f 4.7#,L- TH511, \
♦♦♦♦+►!♦
�+►+►+►4+4►♦ 0039 bpf,D=1.995"
+I►#*►4�+►_
+►4♦►1►+►+► 2-3/8"SLID LNR —I 15240'-15368'
7
•PBTD — 13404' A_e 4Mih 4.7#,L-8011-511,
4444444444 5-1138 L.1
7"CSG,26#,L-80 BTC,ID=6.276' —) 13491' 7A4•4•4A4A A A A$A4e4i .0039 bpf,D=1.995"
5-1136
DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT
OT/13102 DAC/KK ORIGINAL COMPLETION 04/11/17 JPK/JM)OZWIRECTED STA#1 VALVE WEIL S-1136 L1
10/16/16 C2 CTD ML(S-113B L1) 07/24/17 CJNJM)GLV C/O(07/22/17) PERMIT No: 2152180
11/07/16 ZB/JMD FINAL ODEAPPROVAL 05/24/18 TJS/JMD SET LTPw/PISA&R NP AR No: 50-029-23094-02/60
11/09/16 JN./JM) FIXE)SLID LNR 0137TH ' SEC 35,T12N,R12E,738'FPL&783'FWL
12/06/16 NLW/.M)SET WFD PB PKRw/GAUGES
12/13/16 JTG/.NuD PULLB)WFD&PB PKR w/GAUGES BP Exploration(Alaska)
• •
or Thr
, 9 THE STATE Alaska Oil and Gas
OfLASKA Conservation Commission
_ 333 West Seventh Avenue
Anchorage, Alaska 99501-3572
GOVERNOR BILL WALKER g
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
•
Tyson Shriver
Well Intervention Engineer SCAN
BP Exploration(Alaska), Inc.
P.O Box 196612
Anchorage,AK 99519-6612
Re: Prudhoe Bay Field,Aurora Oil Pool,PBU S-113BL1
Permit to Drill Number: 215-218
Sundry Number: 318-078
Dear Mr. Shriver:
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,
6ar.Yr
Hollis S. French
{-1 Chair
tc
DATED this day of March,2018.
inr,ort.,crk
STATE OF ALASKA a Hr$ L T ,"f" ` 7
' OALASKA OIL AND GAS CONSERVATION COMMION
APPLICATION FOR SUNDRY APPROVALS2 .
13
20 AAC 25.280 -�-•7�/ '° F`tt ,,,) _ _
1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0• Repair Well 0 J '+ "'-'
Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 04-1.V4.0,1„ . %Amur(ba,
Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0
2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 215-218
•
3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0
99519-6612 Stratigraphic 0 Service 0
6. API Number 50-029-23094-60-00 •
7. If perforating: 8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception? Yes 0 No 0 PBU S-113BL1
9. Property Designation(Lease Number): 10. Field/Pools:
ADL 028257,028258&028259 PRUDHOE BAY,AURORA OIL(Un ed) /z,,.Z7-(;
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):
15368 ' 6709 • 15368 6709 None None
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 80 20" 33-113 33-113 1490 470
Surface 5553 10-3/4" 33-5586 33-3370 5210 2480
Intermediate 13008 7" 31-13039 ' 31-6767 7240 5410
Production
Liner 2530 2-3/8" 12838-15368 ' 6588-6709 11200 11780
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
15240-15366 6714-6709 3-1/2"9.2# L-80 29-12942
Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 12884/6629
No SSSV Installed No SSSV Installed
12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work:
Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 • Service 0
14.Estimated Date for Commencing Operations: March 20,2018 15. Well Status after proposed work:
Oil 0 WINJ 0 WDSPL 0 Suspended 0
16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑
Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0
17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Shriver,Tyson
be deviated from without prior written approval.
Contact Email: Tyson.Shriver@bp.com
Authorized Name: Shriver,Tyson Contact Phone: +1 9075644133
Authorized Title: Well
�Intervention r p'
Authorized Signature: 1_ �Engine Date: ?/9 3/ / d
7i COMMISSION USE ONLY
Conditions of approval:Notify Commission so that a representative may witness Sundry Number:
Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 312-
09-'3
Other
Post Initial Injection MIT Req'd? Yes 0 No L9'
Spacing Exception Required? Yes 0 No I / Subsequent Form Required: /r .4)4_
APPROVED BYTHE
Approved by: COMMISSIONER COMMISSIONDater�l le/
VTI- 3/!3/18
aw Vippt ORIGINAL RBDms9v4AR 2 2 210
,��
1t, ' Submit Form and
-/ Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate
0 i
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
AFFIDAVIT OF NOTICE OF OPERATIONS
/ c")
Before me, the undersigned authority, on this day personally appeared /4,S c9 ✓I7C,✓{/, who
being duly sworn states: 4
1. My name is Tyson Shriver. I am 18 years of age or older and I have personal knowledge of the
facts stated in this affidavit.
2. I am employed as an Engineer by BP Exploration (Alaska) Inc. ("BPXA") and I am familiar with
the Application for Sundry Approvals to stimulate the S-113BL1 Well (the "Well") by hydraulic
fracturing as defined in 20 AAC 25.283(m).
3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true
copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations").
4. On February 21, 2018, the Notice of Operations was sent to all owners, landowners, surface
owners and operators within a one-half mile radius of the current or proposed wellbore trajectory
of the Well. The Notice of Operations included:
a. A statement that upon request a complete copy of the Application for Sundry Approvals
is available from BPXA;
b. BPXA's contact information.
Signed this 21St day of February, 2018. V /
(Signat e)
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
401 f/Subscribed and sworn to or affirmed before me at '� Q , F- on the �� c
day of 'Ft OYl. ,20/g'.
la 0: , 1
_.gnature of Officer
v'
Mete of Alaska -
/16-6
Notary Public l �r Title of Officer
Loris L Jordheim
My Commission : 34040
• •
Date: February 21st, 2018
Subject: S-113BL1 Fracture Stimulation
From: Tyson Shriver—Wells Engineer,Alaska
e:Tyson.Shriver@bp.com
o: 907.564.4133
c:406.690.6385
David Wages—Wells Engineer,Alaska
e: David.Wages@bp.com
o: 907.564.5669
c: 713.380.9836
To: Chris Wallace
ZZlE
Attached is BP's proposal and supporting documentation to perform a fracture stimulation on well S-113BL1 (PTD#
143-0) in the Kuparuk reservoir of the Prudhoe Bay Unit. ! �? fe
Well S-113BL1 is a coiled tubing drilling sidetrack that was completed in October 2016. The well is an undulating lateral
through the Kuparuk C sands that is expected to be fracture stimulated in the toe, mid-lateral and heel.The base plan is
to perform a toe and mid-lateral fracture stimulation now and return at a later date (later than a year)to execute the
heel stage. However, access in the liner is currently restricted due to suspected scale build-up.A coiled tubing
intervention has been planned to clean out the 2-3/8" liner to TD. If the intervention is successful in gaining liner access
all the way to TD,the toe and mid-lateral frac's will be executed. If coiled tubing is unsuccessful in cleaning out to TD,
the plan will be to perform the mid-lateral (accessible at this time) and heel fracs. BP is applying for all three stages
knowing that, at most,only two of the three possible stages will be performed.
Please direct questions or comments to Tyson Shriver or David Wages.
•
•
Section 1—Affidavit of Notification (20 AAC 25.283,a, 1):
All owners, landowners, surface owners and operators within Y2 mile radius of the current wellbore trajectory have been
provided a notice of operations on 02/21/2018:
ConocoPhillips
ExxonMobil
Chevron
Department of Natural Resources
Section 2—Plat Identifying Wells(20 AAC 25.283, a, 2):
Plat
T.
cr i i�
i''.72----)
_ Vit'
sa v,
2.
S-717r3 A, 7l
$ c$
•
:' e \ -.0� \ k
M1M s rte , ' °
f4 o , .._
''''''''''•-„,„,,,„,,N,:4**4J7,40.e3 ' %(-=.)--- .
y,..44: ,' 1 Nr, M1. S_ _., X0...4. `s-
"T
'deg'r iil es:1'9'".f.
SSl*Ilitl 3 f,6 4
'-,
ng- t,. . ,„ F W `$-/i
01 µ„ ... __IT:., .. ;867 `tit c
0 e
V
o
u,
3.'''''' ortf lio S
N9
s-, m AE'-0232'ti
ok, 8,0,.
1 m5' i A
ch ' t
S
io1
s.1f,
_ 2000 r_S-113BL1 Frac Location Data Sources:
AiSt ',.errs. Coastline maintained try PO
Feet —S-113BL1-Deviation Survey Am9raGhr
`t'!
Webs within 1/2 mile of 5-11313L1
it4t0tl# S-113BL1 S-1138L1 Production Interval 1/2 Mile Buffer -
✓Y"L^gti YF?.fS
-"- -,12.00".".. Q S-113BL1 112 Mile Buffer sE._ MAP 1
41.001
�' � 13 -.3E, 5.771'-'.
Tv BP Leases 'E ew I hnW.EE.,,,_ .
Figure 1:Plat showing well location(highlighted in red)and all wells that penetrate within one-half mile of the current wellbore trajectory and
fracturing interval(brown&orange outline).
• • 111 10
Well Name Well Classification Well Status Well Name Well Classification Well Status
S-01 Development Abandoned S-110 Service Suspended
S-01A Development Abandoned S-110A Service Abandoned
S-01B Development Abandoned S-110B Service Water Injector Injecting
S-01C Development Oil Producer Shut-In S-111 Service Water Injector Injecting
• 5-02 Development Abandoned S-111PB1 • Service Plugged Back For Redrill
S-02A Development Oil Producer Gas Lift S-111PB2 Service Plugged Back For Redrill
S-02AL1 Development Oil Well 5-112 Service Water Injector Injecting
S-02AL1PB1 Development Plugged Back For Redrill S-112L1 Service Water And Gas Injector
S-02APB1 Service Plugged Back For Redrill S-112L1PB1 Service Plugged Back For Redrill
' 5-03 Development Oil Producer Gas Lift S-112L1PB2 " Service Plugged Back For Redrill
S-04 Service Miscible Injector Shut-In S-113 Development Abandoned
5-05 Development Abandoned S-113A Development Abandoned
S-05A Service Water Injector Injecting S-113B Development Oil Producer Shut-In
S-05APB1 Service Plugged Back For Redrill S-113BL1 Development Oil Producer Shut-In
' S-06 Service Water Injector Shut-In 5-114 " Development Abandoned
5-07 Development Abandoned S-114A. Service Water Injector Shut-In
S-07A Development Oil Producer Shut-In 5-115 " Development Oil Producer Gas Lift
S-08 Development Abandoned S-116 ' Service Abandoned
S-08A Development Abandoned S-116A Service Miscible Injector Shut-In
• S-08B Development Oil Producer Shut-In S-116APB1 ' Service Plugged Back For Redrill
S-09 Service Abandoned S-116APB2 • Service Plugged Back For Redrill
S-09A Service Miscible Injector Shut-In 5-117 Development Oil Producer Shut-In
S-09APB1 Service Plugged Back For Redrill S-118 Development Oil Producer Shut-In
S-09APB2 Service Plugged Back For Redrill S-119 Development Oil Producer Gas Lift
• S-09APB3 Service Plugged Back For Redrill S-11A Service Abandoned
5-10 " Development Abandoned S-11B Service Miscible Injector Shut-In
S-100 Development Oil Producer Shut-In S-12 Development Abandoned
5-101 Service Water Injector Injecting 5-120 Service Water Injector Injecting
S-101PB1 - Development Plugged Back For Redrill S-121 Development Oil Producer Gas Lift
• 5-102 Development Oil Producer Gas Lift S-121PB1 • Development Plugged Back For Redrill
S-102L1 Development Abandoned S-122 Development Oil Producer Gas Lift
S-102L1PB1 • Development Plugged Back For Redrill S-122PB1 Development Plugged Back For Redrill
S-102PB1 ' Development Plugged Back For Redrill S-122PB2 Development Plugged Back For Redrill
S-103 Development Oil Producer Gas Lift S-122PB3 Development Plugged Back For Redrill
• 5-104 Service Water Injector Injecting S-123 Service Water Injector Shut-In
5-105 Development Oil Producer Gas Lift 5-124 Service Miscible Injector Shut-In
S-106 Development Oil Producer Shut-In S-125 Development Oil Producer Gas Lift
S-106PB1 - Development Plugged Back For Redrill S-125PB1 Development Plugged Back For Redrill
5-107 Service Water Injector Shut-In S-126 Service Water Injector Shut-In
• S-108 Development Suspended S-128 Service Water Injector Injecting
S-109 Development Oil Producer Shut-In S-128PB1 Service Plugged Back For Redrill
S-109PB1 Development Plugged Back For Redrill S-128PB2 Service Plugged Back For Redrill
S-10A Development Suspended 5-129 Development Oil Producer Gas Lift
. • .
Well Name Well Classification Well Status Well Name Well Classification Well Status
S-10APB1 Development Plugged Back For Redrill S-129PB1 _ Development Plugged Back For Redrill
S-10APB2 Development Plugged Back For Redrill S-129PB2 - Development Plugged Back For Redrill
S-11 Service Abandoned S-12A Development Abandoned _
S-12B Development Oil Producer Gas Lift S-22A Development Abandoned
5-13 Development Abandoned S-22B Service Water Injector Injecting
5-134 Service Miscible Injector Shut-In S-23 Development Oil Producer Shut-In
S-135 Development Oil Producer Gas Lift S-24 Development Abandoned
S-135PB1 ' Development Plugged Back For Redrill S-24A Service Abandoned 1
S-135PB2 - Development Plugged Back For Redrill S-24APB1 , Service Plugged Back For Redrill
S-13A Development Oil Producer Shut-In S-24B Service Water Injector Shut-In
S-13APB1 ' Development Plugged Back For Redrill 5-25 Development Abandoned
5-14 Service Abandoned S-25A Service Water Injector Injecting
S-14A Service Suspended S-25APB1 ' Service Plugged Back For Redrill
5-15 Service Water Injector Shut-In 5-26 Development Oil Producer Shut-In
S-15PB1 " Service Plugged Back For Redrill S-27 Development Abandoned
S-16 Development Oil Producer Shut-In S-27A Development Abandoned
S-16PB1 Development Plugged Back For Redrill S-27APB1 - Development Plugged Back For Redrill
S-17 Development Abandoned S-27B Development Oil Producer Shut-In
S-17A Development Abandoned S-28 Development Abandoned
S-17AL1 Development Abandoned S-28A Development Abandoned
S-17AL1PB1 Development Plugged Back For Redrill S-28B Development Oil Producer Shut-In
S-17APB1 Development Plugged Back For Redrill S-28BPB1 - Development Plugged Back For Redrill
S-17B Development Abandoned S-29 Development Abandoned
S-17C Development Oil Producer Shut-In S-29A Service Water Injector Shut-In
S-17CPB1 Development Plugged Back For Redrill S-29AL1 Service Water Injector Shut-In
S-17CPB2 _ Development Plugged Back For Redrill S-30 Development Oil Producer Shut-In
5-18 Development Abandoned S-31 Development Abandoned
S-18A Development Abandoned S-31A Service Water Injector Injecting
S-18B Development Oil Producer Shut-In 5-32 Development Abandoned
S-19 Development Oil Producer Shut-In S-32A Development Oil Producer Shut-In
S-20 Service Abandoned 5-33 Development Oil Producer Gas Lift
S-200 Development Oil Producer Shut-In 5-34 Service Water Injector Injecting
S-200A Development Oil Producer Shut-In 5-35 Development Oil Producer Shut-In
S-200PB1 Development Plugged Back For Redrill 5-36 Development Oil Producer Shut-In
S-201 Development Oil Producer Shut-In S-37 Development Abandoned
S-201PB1 Development Plugged Back For Redrill S-37A Development Oil Producer Gas Lift
S-20A Service Water Injector Injecting S-37APB1 ` Development Plugged Back For Redrill
S-21 Development Oil Producer Gas Lift S-38 Development Oil Producer Shut-In
5-213 Development Abandoned S-40 Development Abandoned
S-213A Development Oil Producer Gas Lift S-400 Service Abandoned
S-213AL1 Development Oil Producer Flowing S-400A Service Water Injector Shut-In
S-213AL1-01 Development Oil Producer Flowing S-401 Service Water Injector Shut-In
S-213AL2 Development Oil Well S-401PB1 Service Plugged Back For Redrill
•
•
Well Name Well Classification Well Status Well Name Well Classification Well Status
S-213AL3 Development Oil Well S-40A Development Oil Producer Shut-In
S-215 Service Water Injector Injecting S-41 Development Abandoned
S-216 Service Water Injector Shut-In S-41A Service Water Injector Injecting
S-217 Service Water Injector Shut-In S-41AL1 Development Oil Producer Gas Lift
• S-218 Service Miscible Injector Shut-In S-41L1 Development Abandoned
S-22 Development Abandoned S-41PB1 Service Plugged Back For Redrill
S-42 Development Abandoned
S-42A Development Oil Producer Gas Lift
S-42PB1 Service Plugged Back For Redrill
S-43 Development Oil Producer Shut-In
S-43L1 Development Oil Producer Gas Lift
S-44 Development Abandoned
S-44A Development Oil Producer Gas Lift
S-44L1 Development Abandoned
S-44L1PB1 Development Plugged Back For Redrill rf
4 7 I(4 L 1- me 4"
S-504 Service Water Injector Shut-In
V-200 Exploratory Abandoned
Sections 3-4—Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4):
Well S-113BL1 is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986
where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an
order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the
Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state:
1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe
Bay Unit do not currently serve as a source of drinking water.
2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe
Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes
economically impracticable.
3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe
Bay Unit are reported to have total dissolved solids content of 7000 mg/I or more.
4. By letter of July 1, 1986, EPA-Region 10 advises that the aquifers occurring beneath the Western Operating and
K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non-
substantial program revision not requiring notice in the Federal Registrar.
Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad
Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440"thus allowing BP exemption
from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater
sampling.
• •
Sections 5-6—Detailed Casing and Cement Information (20 AAC 25.283,a, 5-6A):
The parent bore of S-113BL1 (S-113B)was spudded 07/08/2002. Surface location for S-113BL1 (PTD#215-218) is as
follows:4542' FSL, 4496' FEL, Sec. 35,T12N, R12E, UM.
A 13-1/2" hole was drilled to 5600' MD where 10-3/4",45.5#, L-80, BTC casing was run (casing shoe at 5587' MD, 3371'
TVD) and cemented in place with 620 bbls of"G"ArcticSet 3- Lite lead cement slurry and 156 bbls of 15.8 ppg Class G tail
cement. During cement displacement, approximately 30 bbls of cement were seen back to surface. The 10-3/4" casing
was successfully pressure tested to 3500 psi for 30 minutes. Float collar,shoe and 20' of new formation were drilled out
with a 9-7/8" bit to 5620' MD where a leak off test(LOT)was performed with 9.4 ppg mud (1220 psi surface pressure,
3371'TVD, 16.35 ppg EMW).
A 9-7/8" production hole was drilled from 5620'to 14,440' MD for reservoir evaluation (S-113). A 105 bbl, 15.8 ppg
cement plug was laid in from 14,440'—13,440' MD as per program. No losses were encountered while spotting the P&A
cement plug. After lying in cement, a balanced kick-off plug was spotted from 10,575'—10,150' MD for sidetracking to
another BH location for additional formation evaluation. A 9-7/8" production hole was sidetracked from 10,095'—
12,640' MD(S-113A). Cement was laid in from 12,640'—11,840' as per program. Above the P&A plug, a balanced kick-
off plug was spotted from 10,025'—9,600' MD for sidetracking S-113B. The top of the kick-off plug was dressed off to
9,700' MD and a 9-7/8" production hole was directionally drilled to TD at 13,515' MD where 7", 26#, L-80, BTC casing
was run (casing shoe at 13,490' MD, 7169'TVD) and cemented in place (S-113B). The casing was cemented with 105
bbls, 15.8 Class G premium cement. No losses were noted during cementing and plug bumped on calculated volume.
The completion assembly consisting of 3-1/2",9.3#, L-80 IBT tubing was run to 12,944' MD with the production packer
set at 12,884' MD (6559'TVDss).
S-113BL1 kicked-off in the existing perfs and was directionally drilled to 15,368' MD (6639'TVDss) undulating through
the Kuparuk sands. An uncemented 2-3/8",4.7#, L-80,TH511 liner was run consisting of both solid (12,838'MD—15,240'
MD) and slotted liner(15,240'—15,368' MD). Since this is a coiled tubing drilling sidetrack,the existing production
tubing is being utilized for production.
Section 7—Pressure Testing(20 AAC 25.283,a,7):
Table 1—Tubing and Production Casing Pressure Testing
Tubing Pressure Production Casing Differential Pressure
Date (psi) Pressure (psi) (psi)
07/22/2017 4662 0 4662
07/22/2017 2540 4694 2154
*The tubing was most recently pressure tested to 4662 psi differential which is greater than 110%max differential
during stimulation per 20 AAC 25.283, b.
7600 psi (max tbg pressure)—3500 psi (IA casing pressure) =4100 psi (differential while stimulating)
4100 psi (differential)x 1.1 =4510 psi (110%max differential pressure while stimulating)
A00 — 4000 = 360 0 ,,� / C'DY`) 3/6/7X1
ACM)ACM) x 1, t - 0 5 '✓
IP
III
Section 8—Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283, a,8):
Wellbore Schematic
TREE=
WELLHFAD= 13-5/8'5M RC S-113B SAFETY NOTES: 3-112CHROME NIPPLES, WELL
ACTUATOR- ANGLE>70°*6009'.MAX OLS:37°,z! 13176'.
ORB.REV= 70.33' I-1
REF EL.EV= 70.33'
BF.ELL/= 37.48'
(OF= 700' I 2367' 3-1/2'HES X MP,ID=2.813'1
171ax ANN w 113'ft 13394'
Detural13w 6700'
Datum ND= 6700'SS
10-3/4'CSG,45,58,L-80,13=9.950' 1- 5587' I GAS LFT MCLS
ST IAD I ND LV TY FE VLV LATO-1 FORT DATE
Wil s 4 6713 3800 69 WAG OW RC , 0 07/22/17
3 11147 5598 62 If DM RK 1 0 07/22/17
Minimum ID =1.92"@ 12838' 2 12712 6480 33 FAVG DMY RC I 0 07/12/02
2.63" DEPLOYMENT SLEEVE 1 12802 6557 30 WAG DM1 RC I 0 07/22/17
0=1.92"1 I
I I 128412 —13-1/2Hcs x MR D=2313.1 BEHIND
[TOP OE aiviRa SIT-1 Fr 12368'-12942 1
' CT L.N0
...2v, ..‹. 12894' 7')1-1L-1/2"BAKER S-3 FKR.13=3.8M"j
' I 12910' —I3-lir 1 im X MIR ID 2 913'I
L 12930' H -" 'HEs X'4F',10-2 817 I
i'
' N f 12939' —,EUNV PLUG 03 ,
i
(2.04'FLOW COLLAR,0=1.930')
,
,
12147 --13-1/2.%%LEG El-1992"4891 ND c T LW)
3-1/2-ISO,9.20,L-80,.cee7 bpf.ID-2 992'j--E ---121142' f .
t•
4r
.10
. 12932 ELMO TT (LOGGED 07/28102)
ti•
",4I a ,,e, .1-197.1 .H INV P100 92
''.. •• (2 64'I LOW COLLAR,ID 1.9301
7.
OA" •,
••4
• 1 ,
13 1/2"MONUtf OHL All tIM IVA;1610 e'?19 -1. 13039' k-_,. • •- mi I.OUT WNDOW(S-11313 LI) 13039' 13044'
..____...:. . • #
'Ai t
F92PORA710N SUFAVARY
'..>`•'1.1 136911--IFL OW FtUG#1
FEF
,LOG BAKB1 RIV 01410115116 -------
.12 64'FLOW COLLAR.,ID-1930. ")
ANGLE AT TOF PEFF: NA • v vv..
40 ;••••••• '
• •••-•• 14600' 1-4PLPJ1 w/HA IALL1
We Refer to Production LU for historical pert data 110••••••• , .
SIZE I 5F1r i INTERVAL J Opnraqz1 SI1DT 1 SOZ 4 L,,,,4:14404",.t
16140.1—lir Waite°SLTO
5-1138 ••. ;•; V LER w/30 X 5"HOLES
2-1/7 6 13014-13038 S 07/28/02109/1W16 '
4* 4 IF ...•
111,11. • •• :::-'- --
2-1/2 6 13018-13038 S 11/06/02,09/18/18 .. • 41***
\ ,, .
• II. --., ...
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8-113B
,—
DATE REV BY COMMENTS 34TE RBI 3Y 06.14:NI5 A UFORA UK
07/13/02 DA C/KK OFIG1NAL COMPLETION 04111/17 JPK/JAD CORRECTID STA 01 VALVE NEIL S-1136 L1
10I161164NDROICiCTD ML(8-1138 L1) 07/24/17 CJIIJIA)GLV CIC(07/22/17) PERMT Nix It152180
11/07/16 ZBOARD FiNAL O( APPROVAL AF1No: 50-029-23094-02/60
11/09/16 JNL/JIA .3 FIXED SLID LFR CEPTH SEC 35,712N,R12E,738 FT&&783'PAIL
12/06116 N_WIJAC SET V.FD Fe PKR w!GAUGES
12/13/16 JIG/.94O FULL LOWED&FB FKR w/GAUGES . BP Exploration lAlaska)
Figure 2—Proposed wellbore schematic for well S-113BL1.
• i
Table 2—Tubular Ratings
Size/Name Weight Grade Connection ID Burst, psi Collapse, psi
10-3/4" Surface 45.5# L-80 BTC 9.950" 5,210 2,480
7" Production Casing 26# L-80 BTC 6.276" 7,240 5,410
3-1/2" Production Tubing 9.2# L-80 IBT 2.992" 10,160 10,530
2-3/8" Production Liner 4.7# L-80 H511 1.995" 11,200 11,780
(Solid)
2-3/8" Production Liner 4.7# L-80 H511 1.995" N/A N/A
(Slotted)
Wellhead
Wellhead: FMC manufactured wellhead, rated to 5,000 psi.
• Tubing head adaptor: 13-5/8" 5,000 psi x 4-1/16" 5,000 psi
• Tubing Spool: 13-5/8" 5,000 psi w/2-1/16" side outlets
• Casing Spool: 13-5/8" 5,000 psi w/2-1/16" side outlets
Tree: Cameron 4-1/16" 5,000 psi
Tree-saver
Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the treating iron.
Bottom connection is 7-1/16"
The tree-saver is rated to 10,000 psi.
momo
mom
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Figure 3—Diagram of tree-saver to be used during fracture stimulation.
•
S •
Section 9-Geological Frac Information (20 AAC 25.283,a,9):
Table 3-Geological Information
Formation MD MD TVDss TVD Frac
Top Bottom Top TVDss Bottom Thickness Grad Lithological Desc.
Top HRZ 12,784. 13,000 6471 6662 191 "0.83 Shale(Upper confining
d
zone)
Top Kalubik 13,000 - 13,017 6662 6677 15 -0.83^ Shale
TKUP-Parent 13,017 - 6677 - - - -
C4 13,017 13,026 6677 6685 8 0.63 SS
C3B 13,026 13,037 6685 6695 10 0.63 SS
C3A 13,037 13,050 6695 6706 11 0.63 SS
KOP 13,039 13,044 6697 6701 - - -
C2E 13,050 13,066 6706 6720 14 0.63 SS
C2D 13,066 13,085 6720 6735 15 0.63 SS
C2C 13,085 13,101 6735 6747 12 0.63 SS
C2B 13,101 13,126 6747 6763 16 0.63 SS
C2A 13,126 13,151 6763 6776 13 0.63 SS
C1C 13,151 13,231 6776 6794 18 0.63 SS
Invert in C1C - 13,231 - 6794 - - -
C1C 13,351 13,231 6771 6794 23 0.63 SS
C2B 13,408 13,351 6750 6771 21 0.63 SS
C2C 13,438 13,408 6739 6750 11 0.63 SS
C2D 13,480 13,438 6724 6739 15 0.63 SS
C2E 13,529 13,480 6708 6724 16 0.63 SS
C3A 13,579 13,529 6696 6708 12 0.63 SS
Revert in C3B 13,719 - 6689 - - - -
C3A 13,800 13,850 6690 6691 1 0.63 SS
Unmapped Fault 13,850 - 6691 - - - -
C2C 13,906 13,967 6697 6707 10 0.63 SS
C2B 13,967 14,014 6707 6714 7 0.63 SS
C2A 14,014 14,066 6714 6723 9 0.63 SS
C1C 14,066 14,183 6723 6736 13 0.63 SS
Invert in C1C - 14,183 - 6736 - - -
C1C 14,454 14,183 6721 6736 15 0.63 SS
C2A 14,725 14,454 6708 6721 13 0.63 SS
C2B 14,825 14,725 6697 6708 11 0.63 SS
C2C 14,895 14,825 6687 6697 10 0.63 SS
Unmapped Fault 14,990 -
6674 - - - -
C2E 15,035 14,990 6668 6674 6 0.63 SS
C3A 15,165 15,035 6652 6668 16 0.63 SS
TD 15,368 - 6639 - - - -
Miluveach 6801 7781 980 ^0.84 Shale(Lower confining
zone)
Within the reservoir section, formation tops were picked from GR logs and cuttings while drilling S-113BL1.The upper
confining zone (HRZ) and top Kuparuk were determined from the parent wellbore logs and cuttings.Top of the lower
confining Miluveach shale was projected from isopach maps of the area and thickness was determined from offset well
S-01.
S
0
Sections 10-11—Location of Wells, Mechanical Information and Faults(20 AAC 25.283, a, 10-11):
Area of Review
N
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Figure 4—Plat showing Area of Review of wells and faults transecting the confining zones within one-half mile of S-113BL1 wellbore trajectory
(brown outline).Also depicted are the planned intervals containing-300'half-length hydraulic fractures(black lines)in the main stress ..
orientation(-N-S).
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•
BP has formed the opinion based on seismic, logs, drilling data and other subsurface information available that there are
9 mapped faults that transect the Kuparuk interval and enter the confining zone within the%2 mile radius of the
production and confining zone trajectory for S-113BL1. Fracture gradients within the confining zone (Kalubik and HRZ)
will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. The HRZ and
Kalubik in this area are predominately shale with some silts with an estimated fracture pressure of at least 0.83 psi/ft.
During pumping activities, if pressures are seen that indicate fracturing out of zone, linkage to a fault or any other event
leading to loss of treating pressure, operations will be shut down immediately. Issues will be identified and dealt with
accordingly prior to proceeding with any further pumping.
There are two faults that are of concern while performing fracturing operations that were crossed by the S-113BL1
production interval (Fault#1 & 2). Both Fault#1 and Fault#2 terminate upwards in the Colville. No losses were ,�-
observed when Fault#1 or Fault#2 were crossed.
S-113BL1 Fault MD SSTVD THROW
Fault#1 13850' 6691' 35' (DTNE) •
Fault#2 14990' 6674' 10' (DTSW)
Fault#3-9 intersect the production interval and confining zone within the 1/2 mile radius. Their displacements, sense of
throw and zone in which they terminate upwards in are given below.
Fault
Termination
Faults THROW Zone
Fault#3 200' (DTW) Sagavanirktok
Fault#4 150' (DTS) Ugnu
Fault#5 220' (DTSW) Schrader Bluff
Fault#6 90' (DTW) Colville
Fault#7 100' (DTSW) Colville
Fault#8 40' (DTSW) Colville
Fault#9 120' (DTE) Colville
If the heel is frac'd, the solid liner will be perforated in the heel 600' MD up-hole of Fault#1 (13,850' MD) and should "
ensure adequate standoff between the perforations and fault for fracturing operations. The wellbore is generally drilled
perpendicular to the maximum stress orientation in this area which runs N/S(10°W of N) based on a regional stress
map. With this wellbore orientation, a transverse fracture will be created leaving an —600' standoff from Fault#1
assuming 300' half-length. Since this will be an open hole completion utilizing perforations, it is assumed the fracture
will initiate at the perforations, 13,100-13,130' MD for the heel frac.
The middle portion of production hole is drilled perpendicular to the maximum horizontal stress which will result in a
transverse fracture. The fracture is planned to be initiated in perforations that will be added from 14,420-14,450' MD.
With a fracture initiating at perforations and a modelled 300' half-length, 360' of standoff exist between the tip of the
fracture and Fault#1 and 440' of standoff exist between the tip of the fracture and Fault#2.
The toe portion of production hole is drilled perpendicular to the maximum horizontal stress which will result in a
transverse fracture. The fracture is planned to be initiated within 15,150'-15,240 MD in the open hole interval with solid
liner(junction of the slotted/solid liner crossover(15,240' MD)). If the liner clean out is successful to the junction,
fracture initiation will be assumed at the junction. If the hole clean out does not get to the junction, the solid liner will
• •
be perforated and the fracture initiation will be assumed at the perforations. With a fracture initiating at the junction
(15,240' MD) and a modelled 300' half-length, 100' of standoff exist between the tip of the fracture and Fault#2.
Expecting–300 ft fracture half-lengths; minimum stand-off from faults can be seen in Table 4—Standoff Values.
Table 4—Standoff Values.
Heel Frac 13,100'-13,130' MD
Fault#1 600
Heel Frac 13,1001-13,130' MD
Fault#6 650
Middle Frac 14,420'-14,450' MD
Fault#1 360
Middle Frac 14,420'-14,450' MD
Fault#2 440
Toe Frac 15,150'-15,240' MD
Fault#2 100
• •
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• •
Anticipated Treating Pressures
Table 5—Anticipated Pressures
Maximum Anticipated Treating Pressure: 6700 psi
Maximum Allowable Treating Pressure: 7600 psi
Stagger Pump Kickouts Between: 6840 psi and 7220 psi (90%to 95%of MATP)
Global Kickout: 7220 psi (95%of MATP)
N2 IA Pop-off Set Pressure: 4275 psi(95%of 4500 psi MIT-IA)
IA Minimum Hold Pressure: 4000 psi
Treating Line Test Pressure: 8600 psi
Maximum Anticipated Rate: 30 bpm
Sand Requirement: 197,000 lbs 16/20 CarboBond Lite NRT
Minimum Water Requirements: 2400 bbls(pump schedule: 1900 bbls)
OA Pressure: Monitor and maintain open to atmosphere
There are three overpressure devices that protect the surface equipment and wellbore from an overpressure event. 1)
Each individual frac pump has an electronic kickout that will shift the pumps into neutral as soon as the set pressure is
reached. Since there are multiple pumps,these set pressures are staggered between 90%and 95%of the maximum
allowable treating pressure. 2) A primary pressure transducer in the treating line will trigger a global kickout that will
shift all the pumps into neutral. 3)There is a manual kickout that is controlled from the frac van that can shift all pumps
into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations.
Additionally,the treating pressure, IA pressure and OA pressure will be monitored in the frac van.
Frac Dimensions:
TVD,feet Frac Half-Length, ft
Top 6745 ^'300 ft
Bottom 6855
The above values were calculated using modeling software.
Maximum Anticipated Treating Pressure: 6700 psi
Surface pressure is calculated based on a closure pressure of—0.63 psi/ft or^'4200 psi. Closure pressure plus anticipated
net pressure to be built (500 psi) and friction pressure minus hydrostatic results in a surface pressure of 2950 psi at the
time of flush.
4200 psi(closure)+500 psi(net)+4950 psi (friction)-2950 psi (hydrostatic)=6700 psi (max surface press)
The difference in closure pressures of the confining shale layers determines height of the fracture. Average confining
layer stress is anticipated to be —0.83 psi/ft limiting fracture height to 110 ft TVD.
Fracture half-length is determined from confining layer stress as well as leak-off and formation modulus. The modeled
frac is anticipated to reach a half-length of^'300 ft.
•
1110
Chemical Disclosure
(i) sts .
Cliertt: BP Exploration Alaska
Well: S-11313L1
Basin/Fieid: Prudhoe Bay
State: Alaska
CountaParish: north Slope Borough
Case:
Disclosure Type: Pre-foti
Weir Completed: 3/18/201S
Date Prepared: 2/19/2018 7:44 PM
Report ID: RPT-53581
nail Nana&Volume Additive Additive Description Conicentrarbon 'Y online
F103 3t.,rfactant I Gal/1000 Gal 85_0 Gal
...
1211 Breaker L6 lb/1113C iC r.:Frl I 1400 Lb
r
1475 Breaker 61 lb I 10.3C 7..s .L. 5800 Lb
1604 Crosslidaer i 3 --,a ,4',- --a , 16511 Gal
- 1891 CivarSkory 6 3 r3a ;_,K.T.,13a :4 540.0 Gal
.
YF1211FlexOlodf 128 86,310 Gal 1065 Scale InhiIs , ^,,bitor ' , r -4a 4 ,
- . ___, _ 15 C Is
...
1071 DayControi Agent, ."..9 "2,a .,..,Z40C,3a 1S5 0 3a
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M002 Andras* 1 2 _b,.-DX,-,..4.i 1CC? Jr
,..,... .. . _
M275 Bactericide 3 _b: _C4:4::,la , 55? Jr
$123 Activator 195? '3a
S526-1620 ' Proppmg Apent varied co---ii-i-.-3-impr z 197;-4C40;-.. Jr
-
The teed weneree&PP in are eaters aPerre represents Me.51.171 r r atm n sf ester ems'Want., PPP-ts ssepted Or sleet.
CAS Number alesy.1..m.1 same Mass 7-r-wt.:tr.,
- _. _ Water thictidlorg Mix Water Supplied by asentr -77 56
66402-68-4 Ceramic materials and wares dremnals -21%
64742-47-8 Distillates petroleum hydrotreated light <1%
9000-30-0 Guar gurn <1%
67-48-1 2-hydroxy41,14,144rirrieth9ethanarninium chloride <1%
67-63-0 — Propan-2-ol , <0196
1319-33-1 Lliexite ' <01 96
...
68131-40-8 Acotiols„t-11-15-secondary,ethoxylated <01 96
7727-54-0 Diarnmonium i- oxid", i -, <0196
107-21-1 Ethylene Glycol -01%
11.1-76-2 2-buntryethanor - 31 it
'
34396-31-1 Ethoxylated CU Alcohol - 3196
129898-01-7 - 2-Propenoic aciddictiver with sodiunaphosphinalle - 3 1 36
_.
68131-39-5 Etharyiated Arcolhol - 3 1
25038-72-6 Viriyidene chtoridefinethinacryhte copolymer <0_1%
. .....„..,,. ,_ . . ,_„...„. _
1310-73-2 Sodium hydroxide iimpurity) <0.1 c
1303-96-4 Sodium Tetraborate Decihydrate <0.01 9..:
68153-30-0 Amine treated srnectite day <0.01%
- 7647-14-5 Sodium dikvide <0.01 36,
91053-39-3 Diatomaceous earth,calcined <001 96
110-174 but-2-enedioic acid <00196
10343-52-4 Calcium Chloride <0.01 96
112-42-5 Undecanol <110196
7631-86-9 Silicon Dioxide <0_001 96
-- -, - .
10377-6D-3 Magnesium nitrate <3 101
_ .
14807-96-6 Magnesium silicate hyclrate,(talc) <0001%
26172-55-4 5-chloro-2-rnethyl-211-isodtazolol-3-one <0001 96
._
7796-30-3 Magnesium chloride <01031%
—„...— —.. —
111-46-6 22'-oxydietharna(impurity) ll <3 CO1%
...
9002-84-0 P9.1719.9Ien4), <0001 %
125005-87-0 Diutan gum <0001 t
595585-15-2 Denim <0.001 96
2682-20-4 2-rnethY1L2h-isothiaol-3-one <0001 96
127-08-2 Acetic acid,potassium salt <0.0001 96
14464-46-1 Cristobalite <0000196
14808-60-7 Quartz,crystailiMe silica <0.0001%
.
7447'40-7 Potassium chloride(impurity) <0001 96
64-19-7 Acetic add(impwity) <°Dotal 96
100%
0 OneStino 2028.Wad by BP Expkinatiory kaska by pormaraort. Page:1,,:
•
•
4111
S-113BL1 Fracture Stimulation
Intervention Engineer
Tyson Shriver(907) 564-4133
Intervention Engineer
David Wages (907) 564-5669
Objective
Perform a two stage fracture stimulation on the newly drilled coil sidetrack to increase well's PI and off-take.
Procedural Steps
Slickline with Fullbore Assist
1. Install a liner top packer.
Coiled Tubing
2. Mill scale in liner to gain access to liner/ toe of well.
Special Projects with Fullbore and Coiled Tubing Assist
3. Rig up tree-saver for fracturing operations
4. Execute two stage fracture stimulation with the following pressure limits:
Maximum Anticipated Treating Pressure: 6700 psi
Maximum Allowable Treating Pressure: 7600 psi
Stagger Pump Kickouts Between: 6840 psi and 7220 psi (90% to 95% of MATP)
Global Kickout: 7220 psi (95%of MATP)
IA Pop-off Set Pressure: 4275 psi (75% of 4500 psi MIT-IA)
IA Minimum Hold Pressure: 4000 psi
Treating Line Test Pressure: 8600 psi
Maximum Anticipated Rate: 30 bpm
Sand Requirement: 197,000 lbs 16/20 CarboBond Lite NRT (split
between two stages)
Minimum Water Requirements: 2400 bbls(pump schedule: 1900 bbls)
OA Pressure: Monitor and maintain open to atmosphere
Coiled Tubing
5. Between fracturing stages, RD tree saver, set CIBP, perforate for next stage of fracture stimulation and re-install
tree saver.
6. Perform a fill cleanout to TD of the well post stimulation
Slickline
7. Install a generic GLV design
Well Testers
8. Flow well back post stimulation to ensure solids are at a manageable level for facilities to handle and conduct a
post frac/post drill well test
Pae 1 of 1
• !'TD 21$--2
)(I(
Loepp, Victoria T (DOA)
From: Shriver,Tyson <Tyson.Shriver@bp.com>
Sent: Wednesday, February 22,2017 9:26 AM
To: Loepp,Victoria T(DOA)
Subject: RE: PBU S-113BL1 (Sundry#316-518) - Update
Follow Up Flag: Follow up
Flag Status: Flagged
VictoriaScp��1E9APR 2 ��1
,
Please disregard the email below about performing a three (3)stage hydraulic fracture stimulation of well S-113BL1. It
was brought to my attention yesterday that we, BP,will perform what was originally applied for in the approved Sundry
(a two (2)stage hydraulic fracture stimulation).
However, in the approved Sundry, it was called out that the fracturing intervals would be from 14,900'—15,835' MD for
the first stage and 13,400' MD for the second stage.The first stage interval has remained unchanged. Liner running
operations inhibited us from installing a sliding sleeve at 13,400' MD. Due to this,the second stage fracture interval has
shifted and will now be performed through perforations that will be shot from 14,410'—14,440' MD(6723'—6726'
TVDss).This does not change or require any additional evaluation of wells/faults located within a one-half mile radius
of the wellbore trajectory.
I apologize for the confusion. Please let me know if you have any further questions/comments. If not, we will execute
the two stage fracture stimulation as originally applied for in the approved Sundry.
Thank you,
Tyson Shriver
BP Alaska Wells
o: (907) 564-4133
c: (406) 690-6385
From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov]
Sent:Tuesday, February 07, 2017 10:46 AM
To: Shriver,Tyson
Subject: RE: PBU S-113BL1 (Sundry #316-518) - Update
Can you outline what the changes are to the approved sundry?
From:Shriver,Tyson [mailto:Tyson.Shriver@bp.com]
Sent:Tuesday,January 31,2017 2:27 PM
To: Loepp,Victoria T(DOA)<victoria.loepp@ialaska.gov>
Subject: PBU S-113BL1(Sundry#316-518)-Update
Hello Victoria,
After further reservoir evaluation of newly drilled lateral S-113BL1, it has been determined that we, BP,would like to
perform a three stage fracture stimulation.The initial sundry application approved by the state(Sundry#316-518)was
for a two stage stimulation.Since the sundry for the two stage work has been approved,what actions need to be
taken/information provided to pursue an additional stage of fracture stimulation for this well?
s s
11,
Thank you,
Tyson Shriver
BP Alaska Wells
o:(907)564-4133
c: (406)690-6385
2
DATA SUBMITTAL COMPLIANCE REPORT
2/2112017
Permit to Drill 2152180 Well Name/No. PRUDHOE BAY UN AURO S-113BL1 Operator BP EXPLORATION (ALASKA) INC. API No. 50-029-23094-60-00
MD 15368 TVD 6709 Completion Date 10/16/2016
REQUIRED INFORMATION /
Mud Log Noy/
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/ Electr
Data Digital Dataset
Type Med/Frmt Number Name
ED C 27714 Digital Data
ED
C
27714 Digital Data
ED
C
27714 Digital Data
ED
C
27714 Digital Data
ED
C
27714 Digital Data
ED
C
27714 Digital Data
ED
C
27714 Digital Data
ED
C
27714 Digital Data
ED C
ED C
ED C
ED C
27714 Digital Data
27714 Digital Data
27714 Digital Data
27714 Digital Data
MWD/GR/RES, GR/CCL/RPM
Completion Status 1-0IL
Samples No
Current Status 1-0I1- UIC No
Directional Survey Yes✓
(data taken from Logs Portion of Master Well Data Maint)
Log Log Run Interval OH/
Scale Media No Start Stop CH Received
12614 15368 11/11/2016
11/11/2016
11/11/2016
11/11/2016
11/11/2016
11/11/2016
11/11/2016
V
n11/11/2016
11/11/2016
11/11/2016
11/11/2016
11/11/2016
Comments
Electronic Data Set, Filename: S-
113BL1_LW D_FI NAL_FIELD_COMPOSITE_140
CT2016 BHI CTK.las
Electronic File: 10398698 air hang and
constants.pdf
Electronic File: S-113BL1 Post run
10_10398698.pdf
Electronic File: S-11361-1 Pre -Run
07_10398698.pdf
Electronic File: S-
113BL1_GR_Res_14OCT2016 MD FINAL FIEL .
D_BH I_CTK.cgm
Electronic File: S-
113BL1 GR Res 140CT2016_TVDSS_FINAL
FIELD _BHI_CTK.cgm
Electronic File: S-
113BL1_GR_Res _140CT2016_MD_FI NAL_FIEL
D_BHI _CTK. pdf '
Electronic File: S-
113131-1_GR_Res_140CT2016_TVDSS_FINAL_ `
FIELD_BHI_CTK.pdf
Electronic File: S-113BL1 Final Survey Report.pdf
Electronic File: S-11361-1 Final Survey Report.txt
Electronic File: S-113BL1 Final Surveys.csv .
Electronic File: S-113BL1 Final Surveys.xls
AOGCC Page I of 3 Tuesday, February 21, 2017
DATA SUBMITTAL COMPLIANCE REPORT
2/21/2017
Permit to Drill 2152180 Well Name/No. PRUDHOE BAY UN AURO S-113BL1 Operator BP EXPLORATION (ALASKA) INC. API No. 50-029-23094-60-00
MD
15368
TVD 6709
ED
C
27714
Digital Data
ED
C
27714
Digital Data
ED
C
27714
Digital Data
ED
C
27714
Digital Data
ED
C
27714
Digital Data
Completion Date 10/16/2016 Completion Status 1 -OIL
Log
C
27714
Log Header Scans
Log
C
27716
Log Header Scans
ED
C
27716
Digital Data
ED
C
27716
Digital Data
ED
C
27716
Digital Data
ED
C
27716
Digital Data
ED C 27716 Digital Data
ED C 27716 Digital Data
Well Cores/Samples Information:
Name
0 0
0 0
12488 15366
12600 15378
Current Status 1 -OIL UIC No
11/11/2016
Electronic File: S-
113BL1_25_tapescan_BHI_CTK.txt .
11/11/2016
Electronic File: S-
113BL1_5_tapescan_BHI_CTK.txt .
11/11/2016
Electronic File: S-113BL1_output.tap
11/11/2016
Electronic File: S-
113BL1_GR _ Res _140CT2016_MD_FI NAL_FIEL
D BHI CTK.tif
11/11/2016
Electronic File: S-
113BL1_ GR—Res —
Res_ 140CT2016_TVDSS_FINAL_
FIELD BHI CTK.tif
2152180 PRUDHOE BAY UN AURO S-113BL1
LOG HEADERS
2152180 PRUDHOE BAY UN AURO S-113BL1
LOG HEADERS
11/11/2016
Electronic Data Set, Filename: S-
113BL1_MRPM_PNC3D_RAW_PASS01 DOWN.
150CT2016 BHI.Ias
11/11/2016
Electronic Data Set, Filename: S-
113BL1_MRPM_PNC3D RAW PASS02UP_150 .
CT2016 BHl.las
11/11/2016
Electronic File: S-
113BL1 _MRPM_PNC3D_RAW_15OCT2016_BH I .
.meta
11/11/2016
Electronic File: S-
IF
113BL1 _MRPM_PNC3D_RAW_15OCT2016_BH I
.PDF
11/11/2016
Electronic File: S-
113BL1_MRPM_PNC3D_RAW_PASS01DOWN_
•
150CT2016 BHI.dlis
11/11/2016
Electronic File: S-
113BL1 MRPM PNC3D_RAW_PASS02UP_150
CT2016 BHl.dlis
Sample
Interval Set
Start Stop Sent Received Number Comments
AOGCC Page 2 of 3 Tuesday, February 21, 2017
DATA SUBMITTAL COMPLIANCE REPORT
2/21/2017
Permit to Drill 2152180 Well Name/No. PRUDHOE BAY UN AURO S-113BL1 Operator BP EXPLORATION (ALASKA) INC
MD 15368 TVD 6709
INFORMATION RECEIVED
Completion Report
Production Test Information Y /0
Geologic Markers/Tops l../
COMPLIANCE HISTORY
Completion Date: 10/16/2016
Release Date: 1/6/2016
Description
Comments:
Completion Date 10/16/2016 Completion Status 1 -OIL Current Status 1 -OIL
API No. 50-029-23094-60-00
UIC No
f 111)
Directional / Inclination Data Mud Logs, Image Files, Digital Data Y / U Core Chips Y/6
Mechanical Integrity Test Information YY Composite Logs, Image, Data Files v Core Photographs Y e
Daily Operations Summary l YI Cuttings Samples Y /76 Laboratory Analyses Y /&
Date Comments
Compliance Reviewed By: Date: d a
AOGCC Page 3 of 3 Tuesday, February 21, 2017
PTP 215-zI�(
Loepp, Victoria T (DOA)
From: Shriver, Tyson <Tyson.Shriver@bp.com>
Sent: Tuesday, January 31, 2017 2:27 PM
To: Loepp, Victoria T (DOA)
Subject: PBU S-113BL1 (Sundry #316-518) - Update
Follow Up Flag: Follow up
Flag Status: Flagged
Hello Victoria,
After further reservoir evaluation of newly drilled lateral S-113BL1, it has been determined that we, BP, would like to
perform a three stage fracture stimulation. The initial sundry application approved by the state (Sundry #316-518) was
for a two stage stimulation. Since the sundry for the two stage work has been approved, what actions need to be
taken/information provided to pursue an additional stage of fracture stimulation for this well?
Thank you,
Tyson Shriver
BP Alaska Wells
o: (907) 564-4133
c: (406) 690-6385
THE STATE
GOVERNOR BILL WALKER
David Wages
Well Interventions Engineer
BP Exploration (Alaska), Inc.
P.O. Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-1 13BL1
Permit to Drill Number: 215-218
Sundry Number: 316-518
Dear Mr. Wages:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.alaska.gov
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,
Cathy P. Foerster
Chair, Commission
DATED thisday of December, 2016.
RDDMS [ L DEC 2 9 2016
STATE OF ALASKA
,SKA OIL AND GAS CONSERVATION COMMISSII
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
" G %./ GG II M G LJ
OCT 072016
°r5 `2,fz-dfs4
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate H 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: BP Exploration (Alaska), Inc
4. Current Well Class:
Exploratory ❑ Development PI
5. Permit to Drill Number: 215-218
3. Address: P.O. Box 196612 Anchorage, AK
99519-6612
Stratigraphic ❑ Service ❑
6. API Number: 50-029-23094-60-00 '
7. If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
8. Well Name and Number:
Will planned perforations require a spacing exception? Yes ❑ No IZ
PBU S-113BL1
9. Property Designation (Lease Number):
10. Field/Pools:
ADL 028257. 028258 & 028259
PRUDHOE BAY, AURORA OIL (Undefined)
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):
—15900—6755'ss —15900—6755'ss
6700 None None
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 80 20" 33-113 33-113 1490 470
Surface 5553 10-3/4" 33-5586 33-3371 5210 2480
Intermediate
Production —13002 7" 31 - —13033 31 - —6761 7240 5410
Liner —2867' 2-3/8" 13033 - —15900 1 —6691'ss -—6755'ss 11200 / N/A 11780 / N/A
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
14000 - —15900
—6711'ss -—6755'ss
3-1/2" 9.2#
L-80
29-12942
Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer
Packers and SSSV MD (ft) and TVD (ft): 12884/6629
No SSSV Installed
No SSSV Installed
12. Attachments: Proposal Summary R1 Wellbore Schematic Q
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development B - Service ❑
14. Estimated Date for Commencing Operations: October 31, 2016
15. Well Status after proposed work:
Oil m WINJ ❑ WDSPL ❑ Suspended ❑
16. Verbal Approval: Date:
GAS ❑ 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 Contact Wages, David
be deviated from without prior written approval.
Email David.Wages@bp.com
Printed Name Wages, David Title Well Interventions Engineer
Signature7
q, /; L Phone +1 907 564 5669 Date J tl
' �
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
�1ce—�1�
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes ❑ No IXY
Spacing Exception Required? Yes ❑ No 53 Subsequent Form Required:
APPROVED BYTHE
Approved by,/-� �.
COMMISSIONER COMMISSION Date:
IFL
ORIGINAL REMMS c:[U 2 9 lois
0/If q�/ (0 Submit Form and
Form 10-403 Revised 11/2015 Approved application is valid for 12 m6nth from the date of approval. f(, Attachments in Duplicate
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
AFFIDAVIT OF NOTICE OF OPERATIONS
D4Before me, the undersigned authority, on this day personally appeared DG U C' , who
being duly sworn states:
1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the
facts stated in this affidavit.
2. I am employed as an Engineer by BP Exploration (Alaska) Inc. ("BPXA") and I am familiar with
the Application for Sundry Approvals to stimulate the S-113BL1 Well (the "Well") by hydraulic
fracturing as defined in 20 AAC 25.283(m).
3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true
copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations").
4. On October 3, 2016, the Notice of Operations was sent to all owners, landowners, surface owners
and operators within a one-half mile radius of the current or proposed wellbore trajectory of the
Well. The Notice of Operations included:
a. A statement that upon request a complete copy of the Application for Sundry Approvals
is available from BPXA;
b. BPXA's contact information.
Signed this 51" day of October, 2016.
(Signature)
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
Subscribed and sworn to or affirmed before me at d41eon the --
day of
am" of Alaska
Nbtary Public
Lorne L. Jordheim 4p,
CamNssion :3-20-20
6gnature of Officer
Title of Offic
Date: October 3, 2016
Subject: 5-113BL1 Fracture Stimulation
From: Tyson Shriver— Wells Engineer, Alaska
e: Tyson.Shriver@bp.com
o: 907.564.4133
c: 406.690.6385
David Wages —Wells Engineer, Alaska
e: David.Wages@bp.com
o: 907.564.5669
c: 713.380.9836
To: Chris Wallace
Attached is BP's proposal and supporting documents to perform a fracture stimulation on well 5-113BL1
in the Kuparuk reservoir of the Prudhoe Bay Unit.
Well 5-113BL1 is a planned coiled tubing sidetrack expected to be drilled in October 2016. The well will
be an undulating lateral through the Kuparuk C sands that is expected to be fracture stimulated in both
the toe and heel. A toe frac will aim to stimulate the C sands on the western side of an expected fault
while a heel frac will be performed east of the fault to maintain access to parent wellbore reserves. The
2-3/8" completion liner will consist of both slotted and solid liner with a ball drop frac sleeve located in
the solid liner section to reduce the cost of performing a two stage fracture stimulation.
We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which require identification of fresh
water aquifers and a plan for basewater sampling.
Please direct questions or comments to Tyson Shriver or David Wages
Affidavit of Notification (20 AAC 25.283, a, 1):
Partners notified 10/03/2016:
ConocoPhillips
ExxonMobil
Chevron
Department of Natural Resources
Plat Identifying Wells (20 AAC 25.283, a, 2):
*See Figure 3 in section 'Location of Wells and Faults (20 AAC 25.283, a, 10-11)"
Exemption for Freshwater Aquifers (20 AAC 25.283, a, 3-4):
Well 5-11361_1 is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated
July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas
Conservation Commission to issue an order exempting those portions of all aquifers lying directly below
the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities.
Findings 1-4 state:
1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas
of the Prudhoe Bay Unit do not currently serve as a source of drinking water.
2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas
of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for
drinking water purposes economically impracticable.
3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas
of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/I or
more.
4. By letter of July 1, 1986, EPA -Region 10 advises that the aquifers occurring beneath the Western
Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be
a minor exemption and a non -substantial program revision not requiring notice in the Federal
Registrar.
Per the above findings, "Those portions of freshwater aquifers lying directly below the Western
Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC
25.440" thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of
freshwater aquifers and establishing a plan for basewater sampling.
lo"I`�.1�
Detailed Casing and Cement Information (20 AAC 25.283, a, 5-6A):
The parent bore of 5-113BL1 (5-1138) was spudded 07/08/2002. Surface location for 5-113BL1 (PTD #
215-218) is as follows: 4542' FSL, 4496' FEL, Sec. 35, T12N, R12E, UM.
A 13-1/2" hole was drilled to 5600' MD where 10-3/4", 45.5#, L-80, BTC casing was run (casing shoe at
5587' MD, 3371' TVD) and cemented in place with 620 bbls of "G"ArcticSet 3 - Lite lead cement slurry
and 156 bbls of 15.8 ppg Class G tail cement. During cement displacement, approximately 30 bbls of
- cement were seen back to surface. The 10-3/4" casing was successfully pressure tested to 3500 psi for
30 minutes. Float collar, shoe and 20' of new formation were drilled out with a 9-7/8" bit to 5620' MD
where a leak off test (LOT) was performed with 9.4 ppg mud (1220 psi surface pressure, 3371' TVD,
16.35 ppg EMW).
A 9-7/8" production hole was drilled from 5620' to 14,440' MD for reservoir evaluation (5-113). A 105
bbl, 15.8 ppg cement plug was laid in from 14,440'- 13,440' MD as per program. No losses were
encountered while spotting the P&A cement plug. After lying in cement, a balanced kick-off plug was
spotted from 10,575'- 10,150' MD for sidetracking to another BH location for additional formation
evaluation. A 9-7/8" production hole was sidetracked from 10,095'- 12,640' MD (5-113A). Cement was
laid in from 12,640'- 11,840' as per program. Above the P&A plug, a balanced kick-off plug was spotted
from 10,025'- 9,600' MD for sidetracking 5-11313. The top of the kick-off plug was dressed off to 9,700'
MD and a 9-7/8" production hole was directionally drilled to TD at 13,515' MD where 7", 26#, L-80, BTC
casing was run (casing shoe at 13,490' MD, 7169' TVD) and cemented in place (S-1138). The casing was
cemented with 105 bbls, 15.8 Class G premium cement. No losses were noted during cementing and
plug bumped on calculated volume*.
The completion assembly consisting of 3-1/2", 9.3#, L-80 IBT tubing was run to 12,944' MD with the
production packer set at 12,884' MD (6559' TVDss).
5-113BL1 is planned to be kicked -off in the existing perfs and directionally drilled to 15,835' MD (6755'
TVDss) undulating through the Kuparuk sands (1798' FNL, 207' FEL, Sec. 32, T12N, R12E, UM). An
uncemented 2-3/8", 4.7#, L-80, H511 liner will be run consisting of both slotted (15,900'- 14,000' MD)
and solid liner (14,000' MD -12,910' MD). A ball drop frac sleeve will be placed in the solid liner at
13,400' MD. Since this is a coiled tubing sidetrack, the existing production tubing will be utilized for
production.
*See Mechanical report and cement evaluation
Table 5 in section "Location of Wells and Faults (20 AAC 25.283, a, 10-11)" for conformance with 20 AAC
25.283, a, 6B
Pressure Testing (20 AAC 25.283, a, 7):
Table 1—Tubing and Production Casing Pressure Testing
Tubing Pressure
Date (psi)
Production Casing
Pressure (psi)
Differential Pressure
(psi)
TBD 5000*
0
5000
TBD 2500
5000
2500
*The tubing will be pressure tested to 5000 psi differential which is greater than 110% max differential
during stimulation per 20 AAC 25.283, b.
8000 psi (max tbg pressure) — 3500 psi (IA casing pressure) = 4500 psi (differential while stimulating)
4500 psi (differential) x 1.1= 4950 psi (110% max differential pressure while stimulating)
Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8):
Weiivore JCnemavc
VWEi1 -EAD= 13-5/(r5MFMr,
ACTUATCIR =
TVD
MtB H.P/ •
- 70.33
Bf- ELIa/
39.13'
Kms=
7.00'
Mex Angle
6713
Damn AD =
69
dttm TVD=
6700' SS
PRUPUSED S`—'I'I 3�L1 SAFETYNOIW: 3-1r2'CHROMENp+PLES. wt't_t
ANGILL > (M . .,��', MAX DLS, . V �,....,
1 1 L J 23sr 3 112• II P. D12813-
Minimum ID @ '
1113( �t
To C,
S%OYI
13.12"TBG, 921, L-80, .0087 bpt, D = 2.992- I
1�,AS I FT MAtrRF1_S
ST
MD
TVD
DEV
TYPE
VLV
LATCH
PORT
DATE
4
6713
3600
69
MYG
DOME
RK
16
09118015
3
11147
5598
82
MYG
DOME
RK
16
09/18015
2
12712
6480
33
MRIG
DW
RK
0
07112102
I
12802
s557
3o
MdG
SO
RK
22
09118115
.v[-re;,r w,u=cat a- I
'X 412' BAKER S-3 FKF;L D - 3.875'
-12• FIES X NP. D = 2813'
- 2.70' DEPLOY M4T SLEEV 6, ID- 2.00"
I 12942 I-{3 1rr wLr�3 0 z.882"
12932 B.b7DTT (IAGf..,8?o72B102)
MLL-OUT WADOWjS-T13BL1) 13036-13U46
13036' ]—ti, 1
--134.00 2-� Z"3 Frac S6e� eve 11
PER ORATION SIA NAWY
RFF LOG_
ANGLE AT TOP PES: Nn
We: Refer to Ptodm ion OB for Nstorical pert data
SIZE
SPF
I RMWAL
OprdSgz
SHOT
SCIZ
S'LTD
74000- t5900
SLTD
CSG. 2810. L-80 BTC. ID =
_—
Figure 1—Proposed wellbore schematic for well 5-113BL1.
�. o
2'.64' box x pin flow Piug�.(5) —
2-31ti" Tm.-ever - SW x Slotted finer -14300
2 318" LW4.44.7#, Sold x 5brred, D =- 1.995" 15835,
ALIRDRA LMT
VVELL: S•113C
PBffiff No: _---
AR M: 50-029-2309403
SEC 35, T12K RUES 738' FN L & 783 PILI.
OP 6mWatba (Alaska)
Table 2—Tubular Ratines
Size/Name
Weight
Grade
Connection
ID
Burst, psi
Collapse, psi
10-3/4" Surface
45.5#
L-80
BTC
9.950"
5,210
2,480
7" Production Casing
26#
L-80
BTC
6.276"
7,240
5,410
3-1/2" Production Tubing
9.2#
L-80
IBT
2.992"
10,160
10,530
2-3/8" Production Liner
(Solid)
4.7#
L-80
H511
1.995"
11,200
11,780
2-3/8" Production Liner
(Slotted)
4.7#
L-80
H511
1.995"
N/A
N/A
Wellhead
Wellhead: FMC manufactured wellhead, rated to 5,000 psi.
• Tubing head adaptor: 13-5/8" 5,000 psi x 4-1/16" 5,000 psi
• Tubing Spool: 13-5/8" 5,000 psi w/ 2-1/16" side outlets
• Casing Spool: 13-5/8" 5,000 psi w/ 2-1/16" side outlets
Tree: Cameron 4-1/16" 5,000 psi
Tree -saver
Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to
the treating iron.
Bottom connection is 7-1/16"
The tree -saver is rated to 10,000 psi.
Figure 2—Diagram of tree -saver to be used during fracture stimulation.
i
i F
f
-
_ x
f
Figure 2—Diagram of tree -saver to be used during fracture stimulation.
Geological Frac Information (20 AAC 25.283, a, 9):
Table 3 -Geological Information
Formation
TVDss
Top
TVDss
Bot
TVD
Thickness
Frac
Grad
Lithological Desc.
Top HRZ
6472
6647
175
0.72
Shale
Top Kalubik
6648
6673
25
0.72
Shale
TKUP - Parent
6673
6685
12
0.65
SS
C3B - Parent
6685
6691
6
0.65
SS
KOP
6691
6695
4
0.65
SS
C3A
6695
6710
15
0.65
SS
C2E
6710
6720
10
0.65
SS
C21)
6720
6735
15
0.65
SS
C2C
6735
6750
15
0.65
SS
C26
6750
6765
15
0.65
SS
C2A
6765
6780
15
0.65
SS
C1C
6780
6800
20
0.65
SS
Invert in C1C
6800
6775
20
0.65
SS
Top LCU
6800
-
-
0.72
Shale
C1C
6775
6745
30
0.65
SS
C26
6745
6730
15
0.65
SS
C2C
6730
6720
10
0.65
SS
C21)
6720
6705
15
0.65
SS
C2E
6705
6690
15
0.65
SS
C3A
6690
6680
10
0.65
SS
Revert in C3b
6680
6690
10
0.65
SS
C3A
6690
6705
15
0.65
SS
C2E
6705
6720
15
0.65
SS
C21)
6720
6727
7
0.65
SS
Fault #1
6727
6715
12
0.65
SS
C3A
6715
6705
10
0.65
SS
C3B
6705
6700
5
0.65
SS
Revert in C4
6700
6700
0
0.65
SS
C313
6700
6710
10
0.65
SS
C3A
6710
6725
15
0.65
SS
C2E
6725
6740
15
0.65
SS
C213
6740
6750
10
0.65
SS
C2C
6750 1
6755
5
0.65
SS
TD in C2C
6755 1
-
-
0.65
SS
Tops have been predicted by looking at offset well picks and seismic data. Within the reservoir section,
tops have been calculated from the AuroraFFM structural model within RMS. RMS model built from
seismic volume 105T, depth converted on TRIO velocity model v14, and flexed to wellpicks and regional
isopachs in RMS. Depth uncertainty exists due to seismic push -down below fault shadow, low vertical
seismic resolution, and different seismic processing vintages.
OWC: 6810' TVDss, OGOC: 6678' TVDss
Location of Wells, Mechanical Information and Faults (20 AAC 25.283, a, 10-11):
Location of wells and faults
6c4::ro
60x_90 608090 50&�L
508E:{
670404 5ti2v0'
617 OW
6t.509 513600
- Borealis TKUP Structure Map =' -5,.a
EleYe
DC ptfi)m)
AM
..55 99
X99
0C
-160
OVOO O -C
3-99 OC
375900
AW DC
'AW 00 $
'
-%5000
700000
..
-795000
-et 0000
,15000
DO
_TM OD
-'90090 &
.
--
-�950.00
OC
-'45C OC
�Ac OC
S-943
100_SW��
•550 OC
-'559cc
00 C
$ 200' _
D
Fault 1
J5'._3
85' SiY
aS-1
ie
D u *
40'W
113$
- 180'
moo
)(
r
—
ssaa
100'
..
230'W
S-11 1_ 13
""�,
Fault 2
12
a
145' S
S-125
s
s
0
_
�q
5i60'tL'=
'xa'60C' =
so—'M 598003 5G8
505s00
516i."�II 5"'Ff
it'Ke9M1
tt'an c�acm
Figure 3—Plat of wells within one-half mile of S-113BL1 wellbore trajectory (green circles), location of faults, and planned
location of hydraulic fractures (black lines). Fracture half -lengths are expected to be –300' and the main stress orientation is
N -S within this part of the field.
The above plat shows faults and wells within a % mile radius of the subject well. There are two faults
that are of concern while performing fracturing operations (Fault 1 & 2). Fault 1 is a 35' downthrown to
the west fault that is predicted to intersect the S-11361-1 wellbore at —14,410' MD (6727' TVDss) within
the Kuparuk C interval. This fault was predicted using the 105T seismic volume and has never been
penetrated before leaving loss circulation risks unknown. Fault 1 resides in an area of significant depth
uncertainty and poor quality data due to strong fault shadow effects. The upper extent of the fault is
estimated to be 6000' TVDss and lower extent 8000' TVDss (cuts some Colville (dies out) in the upper
side, and dies out in the Miluveach shale).
A frac sleeve will beset 1000' MD on the up -hole side of Fault 1 (13,400' MD, 6756' TVDss) to ensure
adequate standoff is present between the sleeve and fault for fracturing operations. The wellbore east
of the fault is planned to be drilled perpendicular to the maximum stress orientation in this area which
runs N/S (100 W of N) based on a regional stress map. With this wellbore orientation, a transverse
fracture will be created leaving an —400' standoff from Fault 1 assuming 300' half-length. Since this will
be an open hole completion utilizing a frac sleeve without perforations, it is assumed the fracture will
initiate at the sleeve, 13,400' MD (6756' TVDss). Interval of open hole annulus that is open to fracturing
runs from 13,036'— 15,835' MD (6694' TVDss & 6755' TVDss).
Fault 2 represents a 145' downthrown to the south fault. This fault was predicted based on the 105T
seismic volume. The well plan for S-11361_1 is designed to not penetrate Fault 2. The upper extent of
the fault is estimated to be —4500' TVDss and lower extent —12000' TVDss (upper section cuts into some
of the Schrader formation, the lower section goes all the way to seismic basement).
The toe portion of production hole is to be drilled parallel to the maximum horizontal stress which will
result in a longitudinal fracture. The fracture is planned to be initiated in the open hole interval
between the junction of the slotted/solid liner crossover (14,900' MD, 6725' TVDss) and the toe of the
well at 15,835' MD (6755' TVDss). With a fracture initiating at the very toe of the well (15,835' MD) and
a modelled 300' half-length, 826' of standoff exist between the tip of the fracture and Fault 2.
Expecting —300 ft fracture half -lengths; stand-off from faults can be seen in Table 4—Standoff Values.
Table 4—Standoff Values
Heel Frac
13,400' MD
13,400' MD
Fault 1
400'
400'
Toe Frac
14,900' MD
15,835' MD
Fault 2
1423'
826'
An approximate 200 ft of stand-off exists between the predicted fracture in the heel of S-113BL1 and
the parent bore S -113B. All other wells within a %2 mile radius of S-11361_1 have standoffs that exceed
expected fracture half -lengths. Mechanical designs and reservoir isolation for these wells can be seen in
Table 5.
Mechanical report and cement evaluation
Table 5—Mechanical Report and Cement Evaluation
Well Name
Casing Type
Casing Size
Casing Depth
Hole Size
Vol cmt
TOC est. via
TOC
TOC
Top of pay interval Zonal Isolation?
in
lbs/ft
MDFeet
TVDss Feet
Inches
bbls
MDFeet
TVDssFeet
TVDssFeet
5-113BL1
Intermediate
7
26#
13491
7100
9.875
105
Volumetric
11931
5908
6673
Yes
Production Liner
2.375
4.7#
15835
6825
3.25
0
No Cement
N/A
N/A
6673
Plop and drop I
No
S-113
Open Hole
-
-
14440
7149
9.875
105
Volumetric
13664
6504
6622
Yes
S -113A
Open Hole
12640
6919
9.875
84
Volumetric
12019
6316
6572
Yes
S-1135
Production
7
26#
13491
7100
9.875
105
Volumetric
11931
5908
6673
Yes
S-126
Production
7
26#
11:119.4
6999 1
9.875
318
Bond Log
5490
3394
6631
Yes
* All top of cement calculations estimated volumetrically were calculated as follows unless otherwise specified in the
TOC = Casing/Liner Bottom MD — (Volume of Cement [bbls] _ Annular Volume [bbl/ft] X 0.7 [30% Hole Was
Notes:
*S-113BL1 Intermediate Casing: Refer to "S-1138 Production Casing" below as this is the same string.
*S-113 Open Hole P&A Plug: No losses prior to, during or after spotting cement plug.
*S -113A Open Hole P&A Plug: No losses were noted while lying in cement plug.
*S-1138 Production Casing: Bumped plug on calculated strokes and no losses were noted while circulating or cem
Hydraulic Fracture Program (20 AAC 25.283, a, 12):
Fracture Stimulation Pump Schedule
STEP
STAGE
COMMENTS
FLUID
PUMP
CF
DIRTY VOLUME
PROPPANT
CLEAN VOLUME
Encaps
Fiber
PUMP TIME
#
#
TYPE
RATERATE
STAGE
CUM
STAGE
CUM
STAGE
cum
SIZE
GROSS
CUM
Breaker
Cone.
STAGE
CUM
(BPM)
(BPM)
(BBL)
(BBL)
(GAL)
(GAL)
(LBS)
(LBS)
(BBL)
(BBL)
(WMgap
(#IMgal)
(hh:mm:$)
(hh:mm:ss)
1
Injection test
WF128
20
20.0
25
26
1050
1050
25
25
0.0
00.01.15
00:01:15
Hard shutdown; monitor pressure.
0.0
00:00:00
00:01:15
2
Calibration Test
YF128FIexD
20
20.0
150
175
6300
7350
150
175
8.0
00:07:30
000845
3
1
Sand
YF1281`190
20
19.2
0
175
0
7350
0
0
16120CorbcUta
0
175
8.0
00:00:00
00:08:45
4
Spacer
YF128FIexD
20
20.0
0
175
0
7350
0
175
8.0
00:00:00
00:08:45
3
Displacement
WF128
20
20.0
178
363
7476
14826
178
353
0.0
00:08:54
00:17:39
Hard shutdown; monitor
pressure.
FLUID
PUMP
CF
DIRTY VOLUME
PROPPANT
CLEAN VOLUME
Encaps
Fiber
PUMP
TIME
STEP
STAGE
AVERAGE
COMMENTS
TYPE
RATE
RATE
STAGE
CUM
STAGE
CUM
STAGE
CUM
SIZE
GROSS
CUM
Breaker
Cone.
STAGE
CUM
#
#
PPA
(BPM)
(BPM)
(BBL)
(BBL)
(GAL)
(GAL)
(LBS)
(LBS)
(BBL)
(BBL)
(#IMgal)
(#IMgal) I
(BBL)
(BBL)
4
1
PAD
YF128F1exD
20
20.0
100
463
4200
19026
0
0
0
100
453
8.0
00:05:00
00:22:39
5
1
0.5
FLAT
YF128FIexD
20
19.6
100
663
4200
23226
2055
2,055
16130 Sand
98
551
8.0
00:05:00
00:27:39
6
1
PAD
YF128F1exD
20
20.0
100
663
4200
27426
0
2,055_ _
_
100
651
8.0
00:05:00
00:32:39
7
1
1
FLAT
YF128F1e0
20
19.2
50
703
2100
29526
2011
4,066
16120 CarboUto
48
699
8.0
000230
00:35:09
8
1
1
RAMP
YF128FIexD
20
19.2
50
753
2100
31626
2011
6,077
lsnocarboute
48
747
8.0
00:02:30
00:37:39
9
1
2
RAMP
YF128FIexD
20
18.4
50
803
2100
33726
3859
9935
16=Carbolits
46
793
8.0
00:02:30
00:40:09
10
1
3
RAMP
YF128FIexD
20
17.7 1
50
853
2100
35826
5562
15,497
16120 Carbotlta
44
837
8.0
00:02:30
00:42:39
11
1
4
RAMP
YF128FIOXD
20
17.0
60
903
2100
37926
7137
22,634
16120CarboUte
42
879
8.0
00:02:30
00:45:09
12
1
6
RAMP
YF128FIexD
20
16.4
60
963
2100
40026
8598
31,232
1enoCarboute
41
920
10.0
00:02:30
00:47:39
13
1
6
RAMP
YF128FIGxD
20
15.8
50
1003
2100
42126_
9957
41,189
lsnocarboute
40
960
10.0
00:02:30
00:50:09
14
1
7
RAMP
YF128FIexD
20
15.3
60
1053
2100
44226
11224
52,412
16120Carbotland
38
998
10.0
00:02:30
00:52:39
15
1
8
RAMP
YF128FIGxD
20
14.8
60
1103
2100
46326
12408
64,820
16120CarboBond
37
1035
10.0
000230
00:55:09
16
1
9
FLAT
YF128FIexD
20
14.3
50
1163
2100
48426
13517
78,338
16120 CarboBond
36
1070
10.0
00:02:30
00:57:39 J
17
1
10
FLAT
YF128FloxD
20
13.9
50
1203
2100
50526
14559
92,896
isno carboBond
35
1105
10.0
00:02:30
01:00:09
21
1
FLAT
WF128
20
200
0
1203
0
50526
0
92,896
0
1105
8.0
00:00:00
01:00:09
22
2
PAD
YF128F1exD
20
20.0
100
1303
4200
54726
0
92,896
Drop Free 60
100
1205
8.0
00:05:00
01:05:09
23
2
PAD
YF128FIexD
0
0.0
0
1303r2100
4726
0
92,896
0
1205
8.0
00:00:00
01:0509
24
2
PAD
YF728FIexD
20
20.0
100
14038926
0
92,896
100
1305
8.0
00:05:00
01:10:09
25
2
0.5
FLAT
YF128FIexD
20
19.6
100
16033126
2055
94,951
16130 Sand
100
1405
8.0
00:05.00
01:15:09
26
2
PAD
YF128FIexD
20
20.0
100
16037326
0
94,951
100
1505
8.0
00:05:00
01:20:09
27
2
1
FLAT
YF128FIexD
20
19.2
50
16639426
2011
96,962
lsnocarboute
50
1555
8.0
00:02:30
01:22:39
28
2
1
RAMP
YF128F1exD
20
19.2
60
17031526
2011
98,973
lsnocarbouts
50
1605
8.0
00:02:30
01:25:0929
2
2
RAMP
YF128FIexD
20
18.4
60
17533626
3859
102,831
16no CarboUte
50
1655
8.0
00:02:30
01:27:39
30
2
3
RAMP
YF128FIexD
20
17.7
60
1803
2100
75726
5562
108,393
16120C2rboUb
50
1705
8.0
00:02:30
01:30:09
31
2
4
RAMP
YF128FIexD
20
17.0
60
1863
2100
77826
7137
115,530
16nocarboute
50
1755
8.0
00:02:30
01:32:39
32
2
5
RAMP
YF128FIexD
20
16.4
50
1903
2100
79926
8598
124,128
16nocarbam
50
1805
8.0
00:02:30
01:35:09
33
2
6
RAMP
YF128FIexD
20
15.8
50
1963
2100
82026
9957
134,085
16120Carboute
50
1855
8.0
00:02:30
01:37:39
34
2
7
RAMP
YF128FIexD
20
15.3
60
2003
2100
84126
11224
145,309
i6nocarboute
50
1905
8.0
000230
0140:09
35
2
8
RAMP
YF128FIexD
20
14.8
50
2063
2100
86226
12408
157,717
lsno carboute
50
1955
8.0
00:02:30
01:42:39
36
2
_
9
FLAT
YF128FIexD
20
14.3
60
2103
2100
88326
13517
171,234
isnocarbouts
50
2005
8.0
00:02:30
01:45:09
37
2
10
FLAT
YF128FIexD
20
13.9
60
2163
2100
90426
14559
185,793
1612ocarboute
50
2055
8.0
000230
01:47:39_
-'
156
4
FLUSH
WF128
20
20,0
98
2261
4110
94536
185,793
98
2153
0.0
00:04:53
01:52:32
157
4
FLUSH
Freezeprotect
16
15.0
19
2.270
804
_-
19
_ 2172
_ _
00:01:16
01:53:48
TOTAL$
2270
-
_95340
186793
_ _185_,793
2172
01:53:48
Chemical Disclosure
_!ienr,
BP Uploration Alaska
Schlumberger
��:
i-1dhoe
Ba5lnc�iFledd:
Prudhoe say
State:
Alaska
Cxourrh+;PParish:
North Slq)e Borough
Case:
Disciu a Fvpe.
Pte -.Bob
kvell Competed:
WIV2016
Date Prepared:
14,,12,+`ZOS%7:.14 PM
Report JD:
RPL-47WG
F103
Surfactants u
i
1 Gal e' MM Gal
90.0 Gal
:4875
weaker
7.9 Lb,,ei000Gal
69D.o 1b
1604
Croslimker
2.5 Gal I1000Gal
235.0 Gal
1391
G" g�
6.6 Gal, I= Gal
5.�9_o Gal
L065 -
�-
-- . Scate lnhibitot
1 Gal j Io00 Gal
90.0 Gal
tai
clayContrxsdAgent
2 Gal I1000Gal
17'5.0 Gal
5r6 ?14Fteu�:W8 28 $6,310 Gal
l.8O02
Ado u,e
2 Lb J 1000 Gal
175.o 6.6
Bactericide
0.4 Lb/100O Gal
36.0 Lb
W12-3630
Propping nt
waled me cewaid w
4,104.O Lb
5123
tar
F Gal II=Gal
175.0 Gal
r&2.2--1620
ProWing Agent
,wed eroncaeRtations
125,532.0 Lb
5526 36
Prta i . trt
.pried concentrabom
36.152.0 tb
Th.OWd na4aanr A, nuV- .6K ,xgeeae6 Ws auvea t in, 4 r Vwd Uru4m[
-
Water 1lndludinMix Water3 ed Cdieru •
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--112-d3-5
- ----
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<0.01 bb
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<0.1 c
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common Chloride
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68131-39-5
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Ee
Anticipated Treating Pressures
Table 6—Anticipated Pressures
Maximum Anticipated Treating Pressure:
6700 psi
Maximum Allowable Treating Pressure:
8000 psi
Stagger Pump Kickouts Between:
7200 psi and 7600 psi (90% to 95% of MATP)
Global Kickout:
7600 psi (95% of MATP)
IA Pop-off Set Pressure:
3750 psi (75% of 4500 psi MIT -IA)
IA Minimum Hold Pressure:
3500 psi
Treating Line Test Pressure:
9000 psi
Maximum Anticipated Rate:
30 bpm
Sand Requirement:
105,000 Ibs 20/40 Carbolite
45,000 Ibs 20/40 CarboBond Lite
Minimum Water Requirements:
2700 bbls (pump schedule: 2200 bbls)
OA Pressure:
Monitor and maintain open to atmosphere
There are three overpressure devices that protect the surface equipment and wellbore from
overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into
neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are
staggered between 90% and 95% of the maximum allowable treating pressure. 2) A primary pressure
transducer in the treating line will trigger a global kickout that will shift all the pumps into neutral. 3)
There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All
three of these shutdown systems will be individually tested prior to high pressure pumping operations.
Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van.
During pumping activities, if pressures are seen that indicate fracturing out of zone, linkage to a fault or
any other event leading to loss of treating pressure, operations will be shut down immediately. Issues
will be identified and dealt with accordingly prior to proceeding with any further pumping.
Frac Dimensions:
TVD, feet
Frac Half -Length, ft
Top 6745
—300 ft
Bottom 6855
The above values were calculated using modeling software.
Maximum Anticipated Treating Pressure: 6700 psi
.✓
Surface pressure is calculated based on a closure pressure of —0.6 psi/ft or 4000 psi. Closure pressure
plus anticipated net pressure to be built (500 psi) and friction pressure minus hydrostatic results in a
surface pressure of 2950 psi at the time of flush.
4200 psi (closure) + 500 psi (net) + 4950 psi (friction) - 2950 psi (hydrostatic) = 6700 psi (max surface
press)
The difference in closure pressures of the confining shale layers determines height of the fracture.
Average confining layer stress is anticipated to be "0.72 psi/ft limiting fracture height to 110 ft TVD.
Fracture half-length is determined from confining layer stress as well as leak -off and formation modulus.
The modeled frac is anticipated to reach a half-length of —300 ft. -
r
S-113 RLI Ric! Un
1
4L
J''
5-113BL1 Fracture Stimulation
Intervention Engineer
Tyson Shriver (907) 564-4133
Intervention Engineer
David Wages (907) 564-5669
History
Well S-113BL1 is a planned coiled tubing sidetrack expected to be drilled in October 2016. The well will be an undulating
lateral through the Kuparuk sands that is expected to be fracture stimulated in both the toe and heel. The toe frac will
aim to stimulate the Kuparuk C sands on the western side of an expected fault while the heel frac will be performed to
maintain parent wellbore reserves. A ball drop frac sleeve will be run in the 2-3/8" liner to reduce the cost of performing
a two stage fracture stimulation.
Objective
Perform a two stage fracture stimulation on the newly drilled coil sidetrack to increase well's PI and off -take.
Procedural Steps
Slickline with Fullbore Assist
1. Set a retrievable bridge plug in the tubing
2. Pull DGLV from bottom station and set a circulation valve
3. Circulate well with 9.8 ppg brine and leave a 500' freeze protect in the tubing and inner annulus
4. Pull circulation valve and set a DGLV
S. MIT -T to 5000 psi with 0 psi on IA
6. MIT -IA to 5000 psi with 2000 psi on tubing
7. Pull retrievable bridge plug from tubing and drift to deviation
8. Set a LTP in deployment sleeve
Special Projects with Fullbore Assist
9. Rig up tree -saver for fracturing operations
10. Execute two stage fracture stimulation with the following pressure limits:
Maximum Anticipated Treating Pressure:
6700 psi
Maximum Allowable Treating Pressure:
8000 psi
Stagger Pump Kickouts Between:
7200 psi and 7600 psi (90% to 95% of MATP)
Global Kickout:
7600 psi (95% of MATP)
IA Pop-off Set Pressure:
3750 psi (75% of 4500 psi MIT -IA)
IA Minimum Hold Pressure:
3500 psi
Treating Line Test Pressure:
9000 psi
Paae 1 of 2
Maximum Anticipated Rate:
30 bpm
Sand Requirement:
105,000 lbs 20/40 Carbolite
45,000 lbs 20/40 CarboBond Lite
Minimum Water Requirements:
2700 bbls (pump schedule: 2200 bbls)
OA Pressure:
Monitor and maintain open to atmosphere
Coiled Tubing
11. Perform a fill cleanout to TD of the well post stimulation
Slickline
12. Install a generic GLV design
Well Testers
13. Flow well back post stimulation to ensure solids are at a manageable level for facilities to handle and conduct a
post frac/post drill well test
raue a cn e
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-113BL1 (PTD No. 215-218; Sundry No. 316-518)
Paragraph Sub -Paragraph Section complete?
(a) Application for
--
(a)(1) Affidavit
Included with application.
SFD
Sundry Approval
10/13/2016
(a)(2) Plat
Included with application.
SFD
10/13/2016
Displayed on the plat within the application. Legal
description not included with packet, but the well lies
within T12N, R12E, UM. The surface location lies in Section
35, the well traverses Sections 34, 27, 28 and 33, and
(a)(2)(A) Well location
reaches total depth in Section 32. The proposed fracturing
SFD
intervals for this two-stage operation are located within
10/13/2016
Section 32. Only PBU partners and DNR are potentially
affected. The well lies more than 1 mile from the nearest
external boundary of the PBU and within the Affected
Areas of CO 341F, AIO 313, and AEO 1.
Per AK DNR's Water Estate Map, no water wells are
present within % mile of PBU 5-111361-1. The nearest
surface water rights permit (LAS File 28154) is associated
with a surface water take point at a lake near BP's S -Pad
(a)(2)(e) Each water well within 'z mile
about 2 miles to the east of the proposed fracturing
SFD
10/14/2016
intervals. The nearest temporary surface water rights
permits are issued to BP (Case ID TWUP A2011-01) to
utilize surface water take points located about 1.8 miles to
the east of the proposed fracturing interval.
(o)(2)(C) Identify all well types within %
_
Provided on 11/202016
SFD
mile
(a)(3) Freshwater aquifers: geological
12/9/2016
None: AEO 1 exempts aquifers in this area for Class II
SFD
name
injection activities.
10/14/2016
AOGCC Page 1 December 9, 2016
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-113131_1 (PTD No. 215-218; Sundry No. 316-518)
Paragraph Sub Paragraph Section Complete
- -- --
AOGCC Page 2 December 9, 2016
(a)(3) Freshwater aquifers: measured and
SFD
true vertical depth
Not applicable per AEO 1
10/14/2016
(a)(4) Baseline water sampling plan
- --- --- --
Not required; no freshwater aquifers present per AEO 1.
SFD
10/14/2016
(a)(5) Casing and cementing information
provided
CDW
10/19/2016
(a)(6) Casing and cementing operation
provided
CDW
assessment
(a)(6)(A) Casing cemented below
10/19/2016
lowermost freshwater aquifer and
provided
CDW
conforms to 20 AAC 25.030
10/19/2016
(a)(6)(B) Each hydrocarbon zone is
Yes, except for two uncemented slotted liners in S -42A and
SFD
isolated
S-101, which are both located more than 5,000 from the
12/9/2016
nearest fracturing interval in S-113131-1.
(a)(7) Pressure test: information and
pressure -test plans for casing and tubing
provided
CDW
installed in well
10/19/2016
(a)(8) Pressure ratings and schematics:
CDW
wellbore_, wellhead, BOPE, treating head
provided
10/19/2016
The planned fracture intervals lie in the Kuparuk sand,
which is about 70' true vertical thickness in this area.
Upper confinement will be provided by the HRZ, Pebble,
(a)(9)(A) Fracturing and confining zones:
and Kalubik shale intervals (about 200' true vertical
lithologic description for each zone
thickness, or TVT). Fracturing will be in the Kuparuk C
SFD
I
Interval (the modeled fracture height is 110' TVT). Lower
10/14/2016
(a)(9)(B) Geological name of each zone
confinement will be provided by the Lower Kuparuk
siltstone/shale (about 260' TVT), the Miluveach shale
(about 450' TVT) and the Kingak shale (about 1,250' TVT).
(See attached figure.)
AOGCC Page 2 December 9, 2016
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-113BL1 (PTD No. 215-218; Sundry No. 316-518)
Paragraph Sub -Paragraph Section Complete?
AOGCC Page 3 December 9, 2016
Upper Confining Interval – (205' thick)
HRZ Shale: -6454' to -6584' TVDSS
I (a)(9)(C) and (a)(9)(D) Measured and true
Pebble / Kalubik Shale: -6584' to -6659' TVDSS
vertical depths, measured and true vertical
Fracturing Interval – (142' thick)
SFD
thicknesses
Kuparuk C Interval: -6659 to -6801' TVDSS
12/9/2016
Lower Confining Interval – (est. 980' thick)
------- _
_ _
Miluveach Shale: -6801 TVDSS
HRZ / Pebble / Kalubik Shales: 0.72 psi/ft
(a)(9)(E) Fracture pressure for each zone
Kuparuk: 0.65 psi/ft
SFD
_
Miluveach Shale: 0.87 psi/ft
12/9/2016
(a)(10) Location, orientation, report on
CDW
mechanical condition of each well----
provided
10/19/2016
The designed half-length of the frac wings in S-113BL1 is
(a)(11) Sufficient information to determine
300', so if operations occur as planned, it appears highly
wells will not interfere with containment
unlikely that the induced fractures will extend to any other
SFD
within % mile
well. BP's contingency plan is to cease pumping operations
10/14/2016
—_
if a sudden loss of treating pressure occurs.
A naturally occurring, north -trending normal fault is
located between stages 1 and 2. The induced fractures are
(a)(11) Faults and fractures, Location,
expected to lie parallel with this naturally occurring fault
orientation
and about 400' and 550' from it. The modeled half-length
of the fracture wings is about 300', so it is highly unlikely
jthat
(a)(11J Faults and fractures, Sufficient
the induced fractures will extend to the naturally
SFD
information to determine no interference
occurring fault. A second naturally occurring, east -trending
10/14/2016
with containment within %mile
fault lies about 800' south of the southern tip of the
projected toe fracture in PBU S-11361-1. It is highly unlikely
that the projected fracture will reach this fault. BP's
contingency plan is to cease pumping operations if a
_.
sudden loss of treating pressure occurs.
(a)(12) Proposed program for fracturing
CDW
operation _
provided
p
10/19/2016
AOGCC Page 3 December 9, 2016
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-113BU (PTD No. 215-218; Sundry No. 316-518)
Paragraph Sub -Paragraph SectionComplete?
AOGCC Page 4 December 9, 2016
(a)(12)(A) Estimated volume 2270 bbl
CDW
10/19/2016
(a)(12)(8) Additives: names, purposes,
concentrations
provided
CDW
10/19/2016
(a)(120) Chemical name and CAS number
of each
provided
CDW
10/19/2016
(a)(12)(D) Inert substances, weight or
volume of each
Provided, 186K Ib
CDW
(a)(12)(E) Maximum treating pressure with
10/19/2016
supporting info to determine
6700 psi, max allowed 8000 psi
CDW
appropriateness for program
10/19/2016
(a)(12)(F) Fractures—height, length, MD
and TVD to top, description of fracturing
Interval between 6745 and 6855 ND Frac half length of
CDW
model
300 ft, average fracture height of 110 ft TVD.
10/19/2016
(a)(13) Proposed program for post-
fracturing well cleanup and fluid recovery
Class I disposal available North Slope
CDW
(b)Testing of casing
10/19/2016
or intermediate
Tested >110% of max anticipated pressure
IA hold of 3500 psi plan, IA test to 4500 psi, IA popoff set as
CDW
casing
3750 psi (75%)
10/19/2016
(c) Fracturing string
(c)(1) Packer>100' below TOC of
Packer set as 12884 ft MD (approx. 6557+ TVD) TOC 11931
CDW
production or intermediate casing
ft MD, 5908 ft TVDss
10/19/2016
Max pressure of 8000 psi and 3500 psi IA hold = 4500 psi,
(c)(2) Tested >110% of max anticipated
so test would need to be 4950 psi. Plan pressure of 6700
CDW
pressure differential
psi and 3500 psi IA hold = 3200 psi differential, tubing test
10/19/2016
to 5000 psi
(d) Pressure relief
Line pressure <= test pressure, remotely
Line test = 9000 psi, stagger pump kickouts 7200 and 7600
valve
controlled shut-in device
psi, global kickout 7600 psi, max allowable pressure plan of
CDW
8000 psi.
10/19/2016
(e) Confinement
Frac fluids confined to approved
CDW
formations
10/19/2016
AOGCC Page 4 December 9, 2016
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-113BL1 (PTD No. 215-218; Sundry No. 316-518)
Paragraph( Sub -Paragraph Section Complete?
(f) Surface casing
Monitored with gauge and pressure relief
CDW
pressures
device
10/19/2016
(g) Annulus
pressure
monitoring &
500 psi criteria
notification
(g)(1) Notify AOGCC within 24 hours
(g)(2) Corrective action or surveillance
(g)(3) Sundry to AOGCC
(h) Sundry Report
(i) Reporting
(i)(1) FracFocus Reporting
(i)(2) AOGCC Reporting: printed &
electronic
(j) Post frac water
sampling plan
(k) Confidential
Clearly marked and specific facts
information
supporting nondisclosure
(I) Variances Modifications of deadlines, requests for
requested variances or waivers
AOGCC Page 5 December 9, 2016
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-113BL1 (PTD No. 215-218; Sundry No. 316-518)
Paragraph Sub Paragraph Section Complete?
- KEY ` c,
'10
Kuparuk Intercept X s -los I
+ -
Frac Wellbore — S -31A i
Area of Review 13 .Q
5-100 S S-1
Cross-section Path µ -24B C
V-200
S 01 S 05 -
5-27�,q CUPAR ST 26-12-1 ~
i z� S 09A \��, S ti
Sh S-32
4r l 35y
.o. _0 r
S-1 S 44 r j
i
ti 1 S 15A.
SS•101 v U J w
5-1138 a ` 120 �TM ��
nr 4, `.� � i
S-117
S-113BL1 'J
S-126 S -17C
3 S- 6 i - 2
5-125 f S
S 28A
S -21Y I S_
l
f ge
X2S ,.
S-120/ 116A S-2 6 5;
AOGCC Page 6 December 9, 2016
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-11361.1 (PTD No. 215-218; Sundry No. 316-518)
--- ---- --- --- - --
Paragraph Sub -Paragraph Section Complete?
--
SP Correlation C Te Depth Sh Rests Porosity
Well Log from SP(WA) RHOB <MD ResD(RPD) RHOB
Nearby 170 301,75 G/CM 2.7 0.200 OHMM 200.000 1.85 GiCld 2.8=
PEF GR - VDSS> ResM(RPM) DRHO
PBU S -113B M 20-10 API 24 0.200 OHMM 200.D—OO 0.2 GICM 0.,
CALI(WA) Sand - Sift - Sha TVD ResS(RPS) NPOR
GAS(WA)
3 0.200 OHMM 200.00 0 p
<M D
DTCP(N!A)
Measured Subsea
Depth Depth
-r
12800
Upper Confining Interval: Cn_, 4
HRZ shale _ '>
Pebble shale °� 12900 a
Kalubik shale 6h;00
13000
Fracturing Interval:ul "
-6700 �--
Frac.
Kuparuk Formation Height _
13100 11`
— 1 _
-6;00 f __
13200
Lower Confining Interval:
Lower Kuparuk silt/shale
Miluveach shale
Kingak shale
-6900
13300 7000
-7000
AOGCC Page 7 December 9, 2016
20 AAC 25.283 Hydraulic Fracturing Application — Checklist
PBU S-113131_1 (PTD No. 215-218; Sundry No. 316-518)
Paragrap
__-Sub-Paragraph Section
2
20�00
1
221
PBLJAURORA S-113
738 FNL 783 FWL
TWP' 12 N - Range! 12E -Sec. 35
0.4 miles
Complete?
261400 0 0 Miles 500292309460
BP 2021430
PSUAURORA S -113A BP 21 52180
Ex 2152160
(Alaska) Inc
738 FNL 783 FWL PBU AURORA S-1 136 BP PEU SM113BLI
TWP: 12 N - Ranqe� 12 E 738 FNL 753 FWL 4542 FSL "96 FEL
Sec. 35 TWP: 12 IN - Range! 12 E - Sec. 35 TWP: 12 N - Range- 12 E - Sec. 35
Fracturing
TaT3-"?4900 rIM900Interval c
M=14440
Confining
Intervals
';'D=13615
ACIGCC Page 8 December 9, 2016
Expanded Area of Review (cont.)
Well Name
I Casing Type
Casing Size Casing Depth Hole Size Vol cmt TOC est. via
TOC TOC
Top of pay interval Zonal Isola
Inches
Feet
Inches I
Cu Ft
MDFeet TVDssFeet
TVDssFeet
S-16 pc
S-17 pc
Production Casing
Production Casing
9.625
9.625
10693
9488
12.251
12.251
2260 Volumetric
1935 Volumetric
5137
4731
4803
4517
6606 Yes
6593 Yes
S-20 pc
Production Casing
9.625
9132
12.25
1751 Volumetric
4827
4720
6558 Yes
S-21 pc
S-22 pc
Production Casing
Production Casing
9.625
9.625
9884
9726
12.25
12.25
2077 Volumetric
2020 Volumetric
4778
4760
45251
4578
6600 Yes
6607 Yes
S -22b pc
Production Casing
9.625
5402
12.25
2020 Volumetric
436
3711
6613 Yes
S -22b pli
S-23 pc
S-24 pc
Production Linerl
Production Casing
Production Casing
7
9.625
9.625
9452
10899
9843
8.5
12.25
12.25
948 Volumetric
1515 Volumetric
2040 Volumetric
3696
7174
4827
3620
6065
4553
6613 Yes
6378 Yes
6640 Yes
S -24A pc
S-25 pc
Production Casing
Production Casing
7
9.625
10180
9140
8.5
12.25
1403 Volumetric
1865 Volumetric
1661
4555
1597
4489
6430 Yes
6610 Yes
S-26 pc
JProduction Casing
9.625
8816
12.25
1870 Log
2674
2609
6425 Yes
5-31 pc
Production Casing
9.625
10783
12.25
2343 Log1
2502
24331
6575 Yes
S -31a pc
Production Casing
9.625
10783
12.25
2343 Log
2502
2433
6594 Yes
S-32 pc
Production Casing
9.625
10099
12.25
2078 Volumetric
4990
4692
6649 Yes
S-34 pc
Production Casing
9.625
10149
12.25
1241 Volumetric
7098
6227
6624 Yes
5-42 pc
Production Casing
7
9375
8.5
495 Volumetric
6369
5795
6649 Yes
S-42 pbl
Open Hole
17651
8.5
0 No cement
N/A N/A
6634 No ✓'
S -42A pc
S -42A pl
5-44A pc
S -44A pl
V-200 p1
Production Casing
Production Liner
Production Casing
iProduction Liner
jProduction Liner
7
4.5
7
4.5
4.51
8480
11248
10016
12078
74636
8.5
6.125
8.5
6
412 Volumetric
0 No Cement
954 Volumetric
01 No Cement
304 Volumetric
65371
N/A N/A
4223
N/A N/A
4738
5198
4156
4674
6635 Yes
6635 No ✓
6569 Yes
6569 No P
6545 Ypcz
No losses noted. Pressure tested casing to 3000 psi.
No losses noted. Pressure tested casing to 3000 psi.
No losses noted. Pressure tested casing to 3000 psi.
No losses noted. Pressure tested casing to 3000 psi.
No losses noted.
No losses noted.
Fully cemented Liner, Cement returns at liner hanger
No losses noted.
No losses noted. Pressure tested casing to 3000 psi.
No losses noted. Bumped plug on calculated strokes.
Pressure tested casing to 4000 psi.
No losses noted.
No losses noted.
No losses noted.
No losses noted.
No losses noted. Pressure tested casing to 3000 psi.
Plug did not bump. Pressure tested casing, ok.
No cement pumped for OH sidetrack.
Lost 16 bbls while displacing cement. Bumped plug on
calculated strokes. Pressure tested casing to 3500 psi. 16
bbl loss taken into account for volumetric TOC.
Uncemented liner.
No losses noted.
Uncemented liner.
No losses noted.
* All top of cement calculations estimated volumetrically were calculated as follows unless otherwise specified in the
"Comments" column:
TOC = Casing/Liner Bottom MD — (Volume of Cement [bbls] _ Annular Volume [bbl/ft] X 0.77 [30% Hole Washout])
Expanded Area of Review
Well Name
Casing Type
Casing Size
Inches
Casing Depth
Feet
Hole Size
Inches
VOI cmt
Cu Ft
TOC est. via
TOC
MDFeet
TOC
TVDssFeet
Top of pay interval
TVDssFeet
S -01A pc
S-016 pl
S-03 pc
5-04 c
5-08 c
Production Casing
Production Liner
Production Casing
Production Casing
Production Casing
9.625
7
9.625
9.625
9.625
10098
10149
7302
9013
8892
12.25
8.5
12.25
12.25
12.25
1792
906
862
1738
1348
Volumetric
Volumetric
Log
Volumetric
Volumetric
5692
4648
2040
4740
5578
5054
4327
1968
4665
5378
6533
6546
6497
6540
6526
S-10 PC
Production Casing
9.628
7900
12.25
1199
Volumetric
4949
4779
6651
S-100 PC
S-100 p1
Production Casing
Production Liner
7
4.5
10250
12150
9.875
6.5
650
287
Log
Volumetric
7908
10308
5223
6751
6619'
6619'
S-101 pc
Production Casing
7
8880
9.875
800
Log
1498
1418
6609'
S-101 pl
S-108 p1
S-112 pc
S-112 pl
S-113
S -113A
S -113B pc
S-113131-1 pl
Production Liner
Production Liner
Production Casing
Production Liner
Open Hole
Open Hole
Production Casing
Production Liner
4.5
5.5x3.5
7
4.5
7
2.375
11721
5497
6825
8535
14440
12640
13491
15835
6.125
6.75
8.75
6.125
9.875
9.875
9.875
3.25
84
809
131
129
590
472
590
0
Volumetric
Log
Volumetric
Volumetric
Volumetric
Volumetric
Volumetric
No Cement
11034
3180
6154
7480
13440
11840
11774
N/A
6682
3106
6044
6716
6349
6147
5908
N/A
6609 1
6642
6639 )
6639 )
6423 -
6462 )
6472 N
6472 P
S-115 pc
Production Casing
5.5 x 3.5
7585
6.75 x 4.1
679
Log
6140
5456
6517 V
S-117 pc
Production Casing
7
8315
8.75
465
Volumetric
5933
4893
6551 Y
S-118 pc
Production Casing
5.5 x 3.5
7232
6.75
472
Volumetric
3480
3129
6477 Y
S-120 pc
Production Casing
7
8425
8.75
357
Volumetric
6596
5116
6487 Y
5-126 pc
Production Casing
7
13491
9.875
1786
Log
5490
3394
6443 Y
S-134 pc
S-15 pc
Production Casing
Production Casing
7
9.625
7762
11307
8.75
12.25
784
3003
Log
Volumetric
4018
3924
3864
3801
6519 Y
6640 Y
Zonal Isolation?
Comments
Cemented in 2 stages, no losses noted. Pressure tested
les casing to 3000 psi
les No losses noted. Pressure tested liner.
Z Pressure tested casing to 3000 psi.
'es Cemented in 2 stages, pressure tested casing to 3000 psi
'es Cemented in 2stages, pressure tested casing to 3000 psi
Cemented in 2 stages, no losses noted. Pressure tested
'es casing to 3000 psi
Displaced cement w/ full returns and bumped plug on
es calculated strokes. Pressure tested casing to 3500 psi.
es Fully cemented Liner, cement returns at liner hanger
Displaced cement w/ full returns. Pressure tested casing to
es 3500 psi.
Displaced cement w/ full returns. Pressure tested liner to
Io 3200 psi.
es No losses noted. Bumped plug on calculated strokes.
es No losses notes, pressure tested casing to 3500 psi.
es Fully cemented Liner, Cement returns at liner hanger
es Spotted P&A plug.
es Spotted P&A plug.
es No losses noted. Pressure tested casing to 3000 psi.
o Openhole Competion.
Lost 25 bbls while displacing cement. Bumped plug on
e5 calculated strokes.
No losses noted. Bumped plug on calculated strokes and
's pressured up on casing to 4000 psi for 10 min.
No losses noted. Bumped plug on calculated strokes and
'-s pressure tested casing to 4000 psi.
Displaced cement w/ full returns and bumped plug on
's calculated strokes. Pressure tested casing to 4000 psi.
Displaced cement w/ full returns and bumped plug on
's calculated strokes. Pressure tested casing to 4000 psi.
No losses noted. Bumped plug on calculated strokes and
!s pressured tested casing to 4000 psi.
'S No losses noted. Pressure tested casing to 3000 psi.
W,Vw 6i>80OC
609= 6100DO 611000 61--ICOO 61300() 614000
.......... .......... ..............
615000 616000 61 ?666 618000 61 GCOO 62000C 62110m
............ 6--"006
13EECHST-01
S-10211
O5-124
S-1020
5
S-107
0 S-102
S-122Pe.1 0 S -122P82
S-122PBI N-121PB1
Ob
S-1 03
-S-114A
48 S-121PI31
S-103
S-121
S-104
0 S-104
P.
S-100
V-200
NKUPST
S-105 i 0 NKUPST
S-11
0 0
-
100"S 113A
S-23 S-108 S-11'-
-S-(j3
200'W
• !-113A
S-44A/S-34
R
8,S-15 0 S-4
S 4 OS -16
- S -24A Os-
-120 S-21 lb S-21 I S-16 S-32
35' E
S- 3D 85'
SW
0 S -22B S-240 S-11
i
180'W
40, w
42 a
S-24 0
S-112 S-1-
4DS-1120 S.10
5-101
S!
-117 925 S-42,* S-4 5-1s.0,
0 "1B
O:S
S-1 1 BL1
00, w
so
S�11 S -42P�133-1
S-
S-12SP81
is 181, S-26 5-123
230'W
is
S-134 S-04 OS -12
-126
0 S-125PB1
S-13 •
145' S
%-125
17 5-2
S-128
S-11 4 is
S-1260132 S
-129W#1
• S-128
0 S -116A $-06
S-1136LI THRZ
0 -q-116 S-27 S -1a
S-02
-116 40 S.
S-1 16A
S07
Elevation
Elevation depth jm]
S-135
•
-C.400.00
0
5-123882
-SILM.DO
-65W.00
S-1
S-29
sS-18
Map Legend TW -C
0 TW -C
Red dots are TKUP penetration
Blue dots are THRZ penetrations
2640 5280ftUS
t
J. = 25'
6c6DOC SOW" 610000 Gil . WD 61?000 613000 614660 615Cw^ 616600
61
Davies, Stephen F (DOA)
From: Shriver, Tyson <Tyson.Shriver@bp.com>
Sent: Monday, November 21, 2016 12:46 PM
To: Davies, Stephen F (DOA)
Cc: Wages, David
Subject: RE: PBU S-113BL1 (PTD #215-218, Sundry #316-518) - Application to Fracture Stimulate
- Request for Additional Information
Attachments: S-113BL1_Sundry Answers.pptx
Steve,
Attached is a Power Point that has the requested information for BP's Application to Fracture Stimulate for well S-
113BL1.
Please let me know if you need anything else.
Tyson Shriver
BP Alaska Wells
o: (907) 564-4133
c: (406) 690-6385
From: Wages, David
From: "Davies, Stephen F (DOA)" <steve.davies@alaska.gov>
Date: October 18, 2016 at 9:11:31 AM AKDT
To: "david.wages@bp.com" <david.wages@bp.com>
Cc: "Bettis, Patricia K (DOA)" <patricia.bettis@alaska.eov>
Subject: PBU S-113BL1 (PTD #215-218, Sundry #316-518) - Application to Fracture Stimulate - Request
for Additional Information
David,
To speed adjudication of BP's sundry application to fracture stimulate PBU S-113BL1 , please submit the
following information that is required under 20 AAC 25.283 but was not provided in BP's initial sundry
application.
Regulation Deficient Information
20 AAC 25.283 (a)(9)(C) Measured depths for the fracturing zone and upper confining zone
20 AAC 25.283 (a)(9)(A), For lower confining zone(s): lithologic description, geological name, measured depth and
(B),(C), (D), (E) true vertical depth, measured and true vertical thickness, and estimated fracture pressure
for each zone. (Since the lower confining interval(s) were not penetrated by PBU S-
113BL1, provide estimate depths, thicknesses, and fracture pressures from a nearby well
or wells).
20 AAC 25.283(a)(2)(C) Since PBU S-113BL1 is a lateral well branch that is open to the parent wellbore that
20 AAC 25.283(a)(10) extends to the ground surface, the one-half mile radius Area of Review (AOR)
20 AAC 25.283(a)(11) encompasses both PBU S-113BL1 and the parent wellbore PBU S-1136, from TD to ground
surface. For that expanded AOR:
20 AAC 25.283(a)(2)(C) — identify each well penetration within one-half mile of the lateral
and parent wellbores;
Measured Depths of Upper Confining Zone
and Fracturing Zone
• THRZ (Top HRZ): 12,784' IVID
•
B
(Bottom
23"'0"131#017'
MD
�-I�7 7)
•Toe Fracturing Zone: 13,039' — 15,368' MD
■ Slotted liner in the toe
le Heel Fracturing Zone: 13,400' MD
■ Frac sleeve in the heel
Lower Confining Zone
• TMLV (Top Miluveach Shale): 6801 TVDss
(projected in from isopachs)
• Thickness: ^'980' Thick (determined from 5-01)
• Brumfield Shale Frac for TMLV in 5-1136L1
PPFG : 16-73ppg (0.87 psi/ft)
Davies, Stephen F (DOA)
From:
Davies, Stephen F (DOA)
Sent:
Tuesday, October 18, 2016 9:12 AM
To:
david.wages@bp.com
Cc:
Bettis, Patricia K (DOA)
Subject:
PBU S-11361_1 (PTD #215-218, Sundry #316-518) - Application to Fracture Stimulate -
Request for Additional Information
David,
To speed adjudication of BP's sundry application to fracture stimulate PBU S-113BL1 , please submit the following
information that is required under 20 AAC 25.283 but was not provided in BP's initial sundry application.
Regulation
Deficient Information
20 AAC 25.283 (a)(9)(C)
Measured depths for the fracturing zone and upper confining zone
20 AAC 25.283 (a)(9)(A),
For lower confining zone(s): lithologic description, geological name, measured depth and
(B),(C), (D), (E)
true vertical depth, measured and true vertical thickness, and estimated fracture pressure
for each zone. (Since the lower confining interval(s) were not penetrated by PBU S-
113BL1, provide estimate depths, thicknesses, and fracture pressures from a nearby well
or wells).
20 AAC 25.283(a)(2)(C)
Since PBU S-113131_1 is a lateral well branch that is open to the parent wellbore that
20 AAC 25.283(a)(10)
extends to the ground surface, the one-half mile radius Area of Review (AOR)
20 AAC 25.283(a)(11)
encompasses both PBU S-113BL1 and the parent wellbore PBU S-1136, from TD to ground
surface. For that expanded AOR:
20 AAC 25.283(a)(2)(C) — identify each well penetration within one-half mile of the lateral
and parent wellbores;
20 AAC 25.283(a)(10) — provide the location, the orientation, and a report on the
mechanical condition of each well that may transect the confining zones, and information
sufficient to support a determination that the well will not interfere with containment of
the hydraulic fracturing fluid; and
20 AAC 25.283(a)(11) — provide the location of, orientation of, and geological data for each
known or suspected fault or fracture that may transect the confining zones, and
information sufficient to support a determination that the known or suspected fault or
fracture will not interfere with containment of the hydraulic fracturing fluid.
Regards,
Steve Davies
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission (AOGCC)
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If
you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware
of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesC@alaska.gov.
rAP4 DEC 2 2 201
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North America - ALASKA - BP
Prudhoe Bay
PB S Pad
S-113
S-113BL1
500292309460
Design: S-113BL1
Final Survey Report
17 October, 2016
21 52 18
27714
Fe pp -_-
'A ka
BAKER
HUGHES
v -
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
S-113
Wellbore:
S-113BL1
Design:
S-113BL1
BP F/A9
Final Survey Report BAKER
HUGHES
Local Co-ordinate Reference: Well S-113
TVD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference: True
Survey Calculation Method: Minimum Curvature
Database: EDM R5K - Alaska PROD - ANCP1
Project Prudhoe Bay, GPB, PRUDHOE BAY
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site
PB S Pad, TR -12-12
Northing:
5,980,854.540 usft
Latitude:
70° 21'23.002 N
Site Position:
Map
Easting:
617,919.920 usft
Longitude:
1490 2'32.343 W
From:
Position Uncertainty:
0.00 usft
Slot Radius:
0.000 in
Grid Convergence:
0.90_
�
Well
S-113
Well Position
+N/ -S 0.00 usft
Northing:
5,980,744.910 usft
Latitude:
70° 21 21.767 N
+E/ -W 0.00 usft
Easting:
618,930.630 usft
Longitude:
1490 2'2.849 W
Position Uncertainty
0.00 usft
Wellhead Elevation:
37.48 usft
Ground Level:
35.96 usft
Wellbore
S-113BL1
Magnetics
Model Name Sample Date
Declination
Dip Angle Field Strength
(nT)
BGGM2016 10/1/2016
18.18
81.02
57,562
J
Design
5-113BL1
Audit Notes:
Version:
Phase:
ACTUAL
Tie On Depth: 12,989.77
Vertical Section:
Depth From (TVD)
+N/ -S
+E/ -W
Direction
(usft)
(usft)
(usft)
(°)
32.85
0.00
0.00
240.00
1011712016 11:32:24AM Page 2 COMPASS 5000.1 Build 81B
Survey Program
Date 10/17/2016
BP
IG&I
Obp
(usft) Survey (Wellbore)
Final Survey Report
BAKER
940.96
9,659.25 S-113 IIFR (S-113)
9,700.00
HUGHES
Company:
North America - ALASKA - BP
Local Co-ordinate Reference:
Well S-113
Project:
Prudhoe Bay
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site:
PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well:
S-113
North Reference:
True
Wellbore:
S-113BL1
Survey Calculation Method:
Minimum Curvature
Design:
S-113131-1
Database:
EDM RSK- Alaska PROD -ANCP1
Survey Program
Date 10/17/2016
From
To
(usft)
(usft) Survey (Wellbore)
132.00
861.10 S-113 Gyro (S-113)
940.96
9,659.25 S-113 IIFR (S-113)
9,700.00
12,989.77 S-1138 IIFR (S-1138)
13,039.00
15,325.85 BHI CTK MWD 3" (S-113BL1)
Tool Name Description
CB -GYRO -SS
Camera based gyro single shots
MWD+IFR+MS-WOCA
MWD + IFR + Multi Station W/O Crustal
MWD+IFR+MS-WOCA
MWD + IFR + Multi Station W/O Crustal
MWD
MWD - Standard
Survey
MD
Inc
Azi (azimuth)
TVD
TVDSS
N/S
ENV
Northing
Easting
DLeg
V. Sec
(usft)
V)
V)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(*/100usft)
(usft)
32.85
0.00
0.00
32.85
-37.48
0.00
0.00
5,980,744.910
618,930.630
0.00
0.00
115.00
0.62
78.00
115.00
44.67
0.09
0.44
5,980,745.009
618,931.064
0.76
-0.42
CONDUCTORI
132.00
0.75
78.00
132.00
61.67
0.13
0.63
5,980,745.055
618,931.262
0.76
-0.621
221.00
0.80
45.00
220.99
150.66
0.70
1.64
5,980,745.631
618,932.262
0.50
-1.77
311.00
1.15
348.00
310.98
240.65
2.02
1.90
5,980,746.963
618,932.498
1.09
-2.66
402.00
2.30
298.00
401.94
331.61
3.77
0.10
5,980,748.684
618,930.668
1.97
-1.971
491.00
4.25
280.00
490.79
420.46
5.18
-4.73
5,980,750.019
618,925.822
2.45
1.50
580.00
5.10
262.00
579.50
509.17
5.21
-11.89
5,980,749.927
618,918.657
1.89
7.70
668.00
7.75
264.00
666.94
596.61
4.04
-21.67
5,980,748.607
618,908.902
3.02
16.7,
765.00
11.50
267.50
762.56
692.23
2.94
-37.64
5,980,747.245
618,892.752
3.91
31.30
861.00
14.00
274.00
856.19
785.86
3.33
-58.99
5,980,747.302
618,871.602
3.00
49.42
940.96
15.61
289.24
933.52
863.19
7.55
-78.80
5,980,751.208
618,851.724
5.25
64.47
988.88
16.10
292.69
979.62
909.29
12.24
-91.02
5,980,755.701
618,839.434
2.22
72.71
1,085.76
20.09
292.69
1,071.69
1,001.36
23.84
-118.78
5,980,766.863
618,811.500
4.12
90.94
1,181.45
22.13
291.42
1,160.95
1,090.62
36.77
-150.72
5,980,779.276
618,779.357
2.18
112.15
1,276.95
23.60
289.38
1,248.95
1,178.62
49.68
-185.50
5,980,791.635
618,744.378
1.75
135.81
1,370.92
26.02
288.95
1,334.24
1,263.91
62.62
-222.75
5,980,803.978
618,706.936
2.58
161.60
1,464.24
27.86
287.15
1,417.43
1,347.10
75.70
-262.95
5,980,816.416
618,666.537
2.16
189.87
1,559.68
33.97
285.55
1,499.27
1,428.94
89.43
-309.99
5,980,829.403
618,619.287
6.46
223.74
10/17/2016 11:32:24AM Page 3 COMPASS 5000.1 Build 81B
BP
Obp Final Survey Report
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
S-113
Wellbore:
S-11361-1
Design:
S-113BL1
Survey
rel .2
BAKER
HUGHES
Local Co-ordinate Reference:
Well S-113
ND Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K - Alaska PROD - ANCP 1
MD
Inc
Azi (azimuth)
ND
TVDSS
N/S
E/W
Northing
Easting
DLeg
(usft)
V)
V)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
('/100usft)
1,655.51
34.81
285.36
1,578.35
1,508.02
103.86
-362.16
5,980,842.994
618,566.900
0.88
1,751.03
37.45
286.17
1,655.50
1,585.17
119.17
-416.35
5,980,857.443
618,512.475
2.81
1,847.41
42.52
286.69
1,729.32
1,658.99
136.69
-475.73
5,980,874.022
618,452.830
5.27
1,942.24
46.44
284.52
1,796.97
1,726.64
154.52
-539.72
5,980,890.829
618,388.574
4.43
2,038.60
48.17
284.33
1,862.31
1,791.98
172.16
-608.30
5,980,907.377
618,319.722
1.80
2,134.30
47.58
283.24
1,926.50
1,856.17
189.07
-677.23
5,980,923.194
618,250.536
1.05
2,230.37
48.77
283.64
1,990.56
1,920.23
205.72
-746.86
5,980,938.727
618,180.659
1.28
2,326.76
53.15
284.32
2,051.26
1,980.93
223.81
-819.49
5,980,955.665
618,107.760
4.58
2,422.29
54.73
281.24
2,107.50
2,037.17
240.87
-894.79
5,980,971.525
618,032.204
3.09
2,517.53
57.26
280.62
2,160.76
2,090.43
255.83
-972.30
5,980,985.254
617,954.468
2.71
2,614.39
59.87
279.99
2,211.27
2,140.94
270.61
-1,053.61
5,980,998.736
617,872.946
2.75
2,709.51
59.84
280.61
2,259.04
2,188.71
285.32
-1,134.54
5,981,012.156
617,791.800
0.56
2,806.36
59.13
279.36
2,308.22
2,237.89
299.79
-1,216.71
5,981,025.318
617,709.419
1.33
2,902.53
61.53
278.79
2,355.82
2,285.49
312.96
-1,299.22
5,981,037.179
617,626.718
2.55
2,998.20
62.26
278.81
2,400.89
2,330.56
325.87
-1,382.61
5,981,048.763
617,543.135
0.76
3,093.95
63.05
280.19
2,444.87
2,374.54
339.91
-1,466.49
5,981,061.469
617,459.050
1.52
3,189.79
62.48
283.43
2,488.74
2,418.41
357.34
-1,549.89
5,981,077.573
617,375.394
3.06
3,285.73
64.58
283.81
2,531.51
2,461.18
377.57
-1,633.35
5,981,096.469
617,291.629
2.22
3,381.29
70.71
285.36
2,567.84
2,497.51
399.84
-1,718.83
5,981,117.376
617,205.814
6.59
3,477.49
71.30
285.44
2,599.15
2,528.82
423.99
-1,806.52
5,981,140.134
617,117.754
0.62
3,572.56
69.33
284.38
2,631.17
2,560.84
447.03
-1,893.02
5,981,161.792
617,030.913
2.32
3,668.70
68.95
284.82
2,665.40
2,595.07
469.67
-1,979.95
5,981,183.052
616,943.635
0.58
3,764.47
68.23
285.09
2,700.36
2,630.03
492.68
-2,066,10
5,981,204.688
616,857.147
0.80
3,859.53
67.76
285.13
2,735.98
2,665.65
515.65
-2,151.18
5,981,226.306
616,771.713
0.50
3,956.90
66.63
285.52
2,773.72
2,703.39
539.38
-2,237.75
5,981,248.648
616,684.789
1.22
4,051.70
67.85
283.58
2,810.40
2,740.07
561.33
-2,322.36
5,981,269.254
616,599.848
2.28
4,148.03
68.11
283.76
2,846.52
2,776.19
582.43
-2,409.13
5,981,288.977
616,512.758
0.32
I
V. Sec
(usft)
261.-
300.9:
343.65
390.15
440.73
491.97
543.94
597.79
654.48
714.12
777.15
839.88
903.81
968.67
1,034.44
1,100.r
1,163.5,
1,225.74
1,288.63
1,352.50
1,415.89
1,479.86
1,542.95
1,605.15
1,668.26
1,730.56
1,795.15
10/17/2016 11:32:24AM Page 4 COMPASS 5000.1 Build 81B
Obp
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Site: PB S Pad
Well: S-113
Wellbore: 5-113BL1
Design: S-113BL1
BP
Final Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
reA.9
BAKER
HUGHES
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
EDM R5K - Alaska PROD - ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
ENV
Northing
Easting
DLeg
V. Sec
(usft) V)
V)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
("/7oousft)
(usft)
4,243.82
67.48
284.36
2,882.72
2,812.39
603.98
-2,495.16
5,981,309.151
616,426.406
0.88
1,858.88
4,340.11
67.95
282.74
2,919.23
2,846.90
624.85
-2,581.77
5,981,328.643
616,339.478
1.63
1,923.46
4,435.63
67.74
282.44
2,955.26
2,884.93
644.13
-2,668.11
5,981,346.552
616,252.850
0.36
1,988.59
4,531.09
66.50
282.37
2,992.37
2,922.04
663.03
-2,754.01
5,981,364.078
616,166.674
1.30
2,053.53
4,626.85
68.27
282.91
3,029.19
2,958.86
682.37
-2,840.26
5,981,382.050
616,080.135
1.92
2,118.55
4,721.47
69.26
283.41
3,063.46
2,993.13
702.45
-2,926.14
5,981,400.763
615,993.956
1.16
2,182.88
4,817.23
69.17
283.00
3,097.44
3,027.11
722.90
-3,013.30
5,981,419.826
615,906.490
0.41
2,248.14
4,912.74
69.60
283.28
3,131.07
3,060.74
743.23
-3,100.35
5,981,438.762
615,819.132
0.53
2,313.37
5,009.47
69.97
283.29
3,164.50
3,094.17
764.09
-3,188.69
5,981,458.214
615,730.477
0.38
2,379.45
5,104.21
69.32
283.10
3,197.45
3,127.12
784.36
-3,275.17
5,981,477.113
615,643.695
0.71
2,444.20
5,200.01
68.73
283.36
3,231.74
3,161.41
804.83
-3,362.25
5,981,496.198
615,556.311
0.67
2,509.38
5,295.57
68.51
283.40
3,266.58
3,196.25
825.42
-3,448.82
5,981,515.411
615,469.434
0.23
2,574.05
5,392.13
68.56
283.25
3,301.91
3,231.58
846.14
-3,536.26
5,981,534.729
615,381.680
0.15
2,639.42
5,487.61
69.52
284.36
3,336.07
3,265.74
867.41
-3,622.84
5,981,554.628
615,294.777
1.48
2,703.77
5,531.40
69.73
284.84
3,351.32
3.280.99
877.76
-3,662.57
5,981,564.343
615,254.897
1.13
2,733.00 L
5,587.19
69.06
284.22
3,370.95
3,300.62
890.86
-3,713.12
5,981,576.639
615,204.149
1.59
2,770.22
SURFACE CASING
5,611.20
68.77
283.95
3,379.59
3,309.26
896.31
-3,734.85
5,981,581.745
615,182.338
1.59
2,786.32 1
5,707.34
67.42
283.08
3,415.45
3,345.12
917.16
-3,821.57
5,981,601.212
615,095.301
1.64
2,851.00
5,801.99
67.80
284.52
3,451.51
3,381.18
938.04
-3,906.56
5,981,620.734
615,010.002
1.46
2,914.16
5,899.34
67.64
285.11
3,488.42
3,418.09
961.07
-3,993.64
5,981,642.380
614,922.568
0.58
2,978.06
5,994.17
67.33
284.71
3,524.73
3,454.40
983.61
-4,078.30
5,981,663.572
614,837.575
0.51
3,040.10
6,090.54
67.27
284.03
3,561.92
3,491.59
1,005.68
-4,164.42
5,981,684.265
614,751.120
0.65
3,103.65
6,185.79
67.40
283.29
3,598.63
3,528.30
1,026.43
-4,249.83
5,981,703.661
614,665.402
0.73
3,167.24
6,281.90
67.03
283.48
3,635.85
3,565.52
1,046.95
-4,336.03
5,981,722.801
614,578.891
0.43
3,231.64
6,379.04
66.32
283.96
3,674.31
3,603.98
1,068.10
-4,422.68
5,981,742.576
614,491.918
0.86
3,296.11
6,474.78
67.44
284.24
3,711.90
3,641.57
1,089.55
-4,508.08
5,981,762.667
614,406.200
1.20
3,359.34
10/17/2016 11 32:24AM Page 5 COMPASS 5000.1 Build 81B
Survey
BP
WSRI
p
Final Survey Report
BAKER
HUGHES
Company:
North America - ALASKA - BP
Local Co-ordinate Reference:
Well S-113
Project:
Prudhoe Bay
ND Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site:
PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well:
S-113
North Reference:
True
Wellbore:
S-113BL1
Survey Calculation Method:
Minimum Curvature
Design:
S-113BL1
Database:
EDM R5K - Alaska PROD - ANCP1
Survey
MD
Inc
Azi (azimuth)
ND
TVDSS
N/S
E/W
Northing
Easting
DLeg
V. Sec
(usft)
V)
V)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
6,570.32
68.22
284.98
3,747.95
3,677.62
1,111.87
-4,593.69
5,981,783.621
614,320.249
1.09
3,422.3'
6,666.91
68.86
285.28
3,783.29
3,712.96
1,135.33
-4,680.47
5,981,805.702
614,233.118
0.72
3,485.7,
6,761.91
68.48
284.88
3,817.85
3,747.52
1,158.36
-4,765.92
5,981,827.364
614,147.326
0.56
3,548.231
6,857.38
68.08
284.87
3,853.18
3,782.85
1,181.12
-4,851.64
5,981,848.767
614,061.263
0.42
3,611.08
6,953.23
67.51
284.90
3,889.40
3,819.07
1,203.92
-4,937.40
5,981,870.196
613,975.156
0.60
3,673.95
7,047.53
68.68
283.80
3,924.58
3,854.25
1,225.60
-5,022.16
5,981,890.526
613,890.069
1.65
3,736.52
7,144.07
68.43
282.97
3,959.88
3,889.55
1,246.40
-5,109.57
5,981,909.936
613,802.343
0.84
3,801.82
7,239.38
68.77
283.11
3,994.65
3,924.32
1,266.42
-5,196.02
5,981,928.581
613,715.593
0.38
3,866.68
7,332.89
69.55
283.46
4,027.92
3,957.59
1,286.51
-5,281.08
5,981,947.310
613,630.239
0.90
3,930.29
7,431.54
68.17
281.73
4,063.50
3,993.17
1,306.58
-5,370.87
5,981,965.949
613,540.151
2.15
3,998.02
7,527.39
67.78
279.76
4,099.45
4,029.12
1,323.14
-5,458.16
5,981,981.126
613,452.615
1.95
4,065.33
7,622.82
66.51
279.47
4,136.51
4,066.18
1,337.83
-5,544.86
5,981,994.436
613,365.700
1.36
4,133.07
7,717.78
66.86
279.01
4,174.10
4,103.77
1,351.83
-5,630.93
5,982,007.068
613,279.421
0.58
4,200.61
7,814.31
67.99
280.86
4,211.16
4,140.83
1,367.22
-5,718.72
5,982,021.054
613,191.406
2.12
4,268.95
7,910.55
68.10
281.80
4,247.14
4,176.81
1,384.75
-5,806.24
5,982,037.198
613,103.626
0.91
4,335.97
8,006.24
68.17
281.85
4,282.78
4,212.45
1,402.95
-5,893.16
5,982,054.012
613,016.434
0.09
4,402.11
8,101.80
68.38
281.25
4,318.15
4,247.82
1,420.72
-5,980.14
5,982,070.402
612,929.196
0.62
4,468.5
8,198.42
69.75
281.20
4,352.67
4,282.34
1,438.29
-6,068.65
5,982,086.559
612,840.422
1.42
4,536.46
8,294.79
70.36
280.65
4,385.54
4,315.21
1,455.46
-6,157.60
5,982,102.311
612,751.221
0.83
4,604.91
8,320.53
69.94
281.43
4,394.28
4,323.95
1,460.09
-6,181.36
5,982,106.569
612,727.390
3.28
4,623.17
8,416.62
70.33
280.59
4,426.94
4,356.61
1,477.35
-6,270.07
5,982,122.415
612,638.427
0.92
4,691.36
8,511.81
69.95
283.14
4,459.28
4,388.95
1,495.76
-6,357.67
5,982,139.424
612,550.546
2.55
4,758.03
8,607.56
68.53
281.34
4,493.22
4,422.89
1,514.74
-6,445.16
5,982,157.018
612,462.773
2.30
4,824.30
8,702.98
67.75
280.03
4,528.75
4,458.42
1,531.17
-6,532.18
5,982,172.055
612,375.511
1.51
4,891.45
8,798.56
66.88
282.93
4,565.62
4,495.29
1,548.71
-6,618.59
5,982,188.221
612,288.840
2.94
4,957.52
8,892.79
66.18
281.64
4,603.15
4,532.82
1,567.10
-6,703.05
5,982,205.269
612,204.114
1.46
5,021.46
8,988.34
66.24
284.79
4,641.70
4,571.37
1,587.08
-6,788.15
5,982,223.899
612,118.713
3.02
5,085.17
1011712016 11:32:24AM Page 6 COMPASS 5000.1 Build 81B
f"'
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Site: PB S Pad
Well: S-113
Wellbore: 5-113BL1
Design: 5-113BL1
BP
Final Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
reA.2
BAKER
CsNES
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
EDM R5K - Alaska PROD - ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
EIW
Northing
Easting
DLeg
V. Sec
(usft) V)
V)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
9,084.21
65.97
286.16
4,680.53
4,610.20
1,610.47
-6,872.62
5,982,245.938
612,033.887
1.34
5,146.6,
9,180.27
66.78
286.15
4,719.03
4,648.70
1,634.96
-6,957.15
5,982,269.078
611,948.983
0.84
5,207.59
9,276.72
67.27
287.42
4,756.68
4,686.35
1,660.60
-7,042.17
5,982,293.368
611,863.581
1.31
5,268.39
9,372.15
68.01
287.46
4,792.98
4,722.65
1,687.05
-7,126.36
5,982,318.476
611,778.981
0.78
5,328.09
9,465.97
68.83
287.66
4,827.49
4,757.16
1,713.37
-7,209.54
5,982,343.472
611,695.404
0.90
5,386.96
9,563.83
69.07
287.18
4,862.64
4,792.31
1,740.71
-7,296.68
5,982,369.424
611,607.847
0.52
5,448.75
9,659.25
68.44
286.36
4,897.21
4,826.88
1,766.38
-7,381.83
5,982,393.729
611,522.307
1.04
5,509.67
9,700.00
68.44
286.29
4,912.19
4,841.86
1,777.03
-7,418.20
5,982,403.802
611,485.774
0.16
5,535.84
9,731.79
65.12
285.75
4,924.72
4,854.39
1,785.09
-7,446.28
5,982,411.417
611,457.576
10.56
5,556.12
9,828.36
62.75
282.61
4,967.16
4,896.83
1,806.51
-7,530.32
5,982,431.493
611,373.210
3.67
5,618.20
9,924.05
61.60
280.09
5,011.83
4,941.50
1,823.31
-7,613.25
5,982,446.980
611,290.034
2.79
5,681.61
10,019.58
61.26
278.12
5,057.52
4,987.19
1,836.59
-7,696.08
5,982,458.940
611,207.006
1.85
5,746.71
10,114.67
60.63
275.08
5,103.71
5,033.38
1,846.15
-7,778.64
5,982,467.187
611,124.315
2.87
5,813.43
10,211.41
60.72
272.09
5,151.09
5,080.76
1,851.42
-7,862.80
5,982,471.121
611,040.085
2.70
5,883.68
10,306.01
59.81
268,44
5,198.03
5,127.70
1,851.81
-7,944.93
5,982,470.209
610,957.974
3.49
5,954.60
10,403.38
60.67
262.47
5,246.39
5,176.06
1,845.10
-8,029.13
5,982,462.162
610,873.895
5.39
6,030.8F -
10,498.70
61.58
256.20
5,292.46
5,222.13
1,829.65
-8,111.09
5,982,445.408
610,792.195
5.84
6,109.59
10,594.09
61.88
251.68
5,337.65
5,267.32
1,806.41
-8,191.79
5,982,420.895
610,711.879
4.18
6,191.10
10,691.60
62.02
248.04
5,383.52
5,313.19
1,776.78
-8,272.57
5,982,389.994
610,631.592
3.30
6,275.86
10,788.82
61.90
243.45
5,429.24
5,358.91
1,741.55
-8,350.77
5,982,353.525
610,553.964
4.17
6,361.21
10,883.33
61.25
239.38
5,474.24
5,403.91
1,701.80
-8,423.74
5,982,312.627
610,481.644
3.85
6,444.27
10,978.88
62.36
235.94
5,519.40
5,449.07
1,656.75
-8,494.87
5,982,266.458
610,411.247
3.38
6,528.39
11,075.09
62.03
234.09
5,564.28
5,493.95
1,607.96
-8,564.59
5,982,216.573
610,342.316
1.74
6,613.17
11,170.61
61.88
235.56
5,609.19
5,538.86
1,559.40
-8,633.49
5,982,166.925
610,274.194
1.37
6,697.12
11,266.04
61.18
234.18
5,654.68
5,584.35
1,511.13
-8,702.10
5,982,117.578
610,206.367
1.47
6,780.67
11,361.03
60.89
233.14
5,700.68
5,630.35
1,461.89
-8,769.04
5,982,067.279
610,140.219
1.01
6,863.27
11,457.88
60.99
234.10
5,747.73
5,677.40
1,411.67
-8,837.20
5,982,015.995
610,072.873
0.87
I
6,947.40 j
10/17/2016 11 32 24A
Page 7
COMPASS 5000.1 Build 81B
Obp
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Site: PB S Pad
Well: 5-113
Wellbore: S-113BL1
Design: S-113BL1
BP
Final Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
rrA.s
BAKER
HUGHES
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
EDM RSK- Alaska PROD -ANCP1
Survey
it
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
ENV
Northing
Easting
DLeg
V. Sec
(usft) V)
(`)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
11,553.64
61.18
235.33
5,794.03
5,723.70
1,363.26
-8,905.62
5,981,966.502
610,005.235
1.14
7,030.F
11,650.35
61.08
236.76
5,840.73
5,770.40
1,315.95
-8,975.87
5,981,916.095
609,935.754
1.30
7,115.3:
11,743.98
60.63
236.38
5,886.33
5,816.00
1,270.90
-9,044.12
5,981,871.970
609,868.237
0.60
7,196.98
11,839.63
60.60
236.07
5,933.26
5,862.93
1,224.57
-9,113.39
5,981,824.546
609,799.710
0.28
7,280.15
11,936.24
60.28
234.96
5,980.92
5,910.59
1,176.99
-9,182.66
5,981,775.879
609,731.213
1.05
7,363.92
12,032.23
59.67
235.43
6,028.95
5,958.62
1,129.55
-9,250.90
5,981,727.368
609,663.741
0.76
7,446.74
12,129.81
57.13
235.87
6,080.08
6,009.75
1,082.66
-9,319.51
5,981,679.394
609,595.890
2.63
7,529.60
12,225.46
54.09
236.26
6,134.10
6,063.77
1,038.60
-9,384.99
5,981,634.301
609,531.127
3.20
7,608.34
12,319.58
52.23
237.84
6,190.53
6,120.20
997.62
-9,448.18
5,981,592.330
609,468.595
2.39
7,683.56
12,415.09
47.43
239.47
6,252.12
6,181.79
959.64
-9,510.47
5,981,553.366
609,406.921
5.19
7,756.49
12,511.30
41.75
240.99
6,320.61
6,250.28
926.08
-9,569.05
5,981,518.884
609,348.888
6.01
7,824.00
12,606.61
37.24
241.92
6,394.14
6,323.81
897.10
-9,622.27
5,981,489.066
609,296.136
4.77
7,884.58
12,703.28
33.18
242.62
6,473.11
6,402.78
871.15
-9,671.59
5,981,462.345
609,247.241
4.22
7,940.27
12,798.31
30.11
245.63
6,554.01
6,483.68
849.35
-9,716.41
5,981,439.837
609,202.780
3.63
7,989.98
12,893.81
27.93
247.10
6,637.51
6,567.18
830.76
-9,758.84
5,981,420.577
609,160.655
2.40
8,036.02
12,989.77
26.54
246.27
6,722.83
6,652.50
813.39
-9,799.17
5,981,402.567
609,120.609
1.50
8,079.8 -
TIP
13,036.00
26.73
245.71
6,764.16
6,693.83
804.96
-9,818.10
5,981,393.835
609,101.817
0.68
8,100.24
7" Planned TOWS
13,039.00
26.74
245.67
6,766.84
6,696.51
804.40
-9,819.33
5,981,393.260
609,100.596
0.68
8,101.59
KOP Whipstock
13,054.68
29.77
244.77
6,780.65
6,710.32
801.29
-9,826.06
5,981,390.041
609,093.909
19.51
8,108.98
Interpolated Azimuth
13,087.06
39.96
243.55
6,807.18
6,736.85
793.21
-9,842.69
5,981,381.699
609,077.416
31.54
8,127.41
Interpolated Azimuth
13,115.57
50.26
242.83
6,827.27
6,756.94
784.10
-9,860.69
5,981,372.307
609,059.567
36.17
8,147.55
Interpolated Azimuth
1011712016 11:32:24AM Page 8 COMPASS 5000.1 Build 81B
by
WOWFinal
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Site: PB S Pad
Well: S-113
Wellbore: S-113BL1
Design: 5-113BL1
BP
Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Has
rias
HUGHES
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
EDM R5K - Alaska PROD - ANCP1
Survey
-- -
-
1
MD Inc
Azi (azimuth)
ND
TVDSS
NIS
ENV
Northing
Easting
DLeg
V. Sec
(usft) (')
(')
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
('1100usft)
(usft)
13,145.05
60.67
242.26
6,843.96
6,773.63
772.91
-9,882.20
5,981,360.780
609,038.232
35.35
81717F
Interpolated Azimuth
13,175.48
71.93
241.77
6,856.18
6,785.85
759.85
-9,906.77
5,981,347.335
609,013.881
37.03
8,199.58
Interpolated Azimuth
13,184.18
75.14
241.64
6,858.64
6,788.31
755.90
-9,914.11
5,981,343.265
609,006.600
36.92
8,207.92
13,214.20
85.73
241.69
6,863.62
6,793.29
741.87
-9,940.13
5,981,328.824
606,980.809
35.28
8,237.47
13,244.28
93.53
242.89
6,863.82
6,793.49
727.89
-9,966.74
5,981,314.429
608,954.428
26.24
8,267.50
13,274.29
98.57
243.08
6,860.65
6,790.32
714.34
-9,993.32
5,981,300.459
608,928.071
16.81
8,297.29
13,304.20
103.51
243.77
6,854.93
6,784.60
701.21
-10,019.56
5,981,286.915
608,902.039
16.67
8,326.59
13,334.43
107.40
246.43
6,846.87
6,776.54
688.94
-10,045.98
5,981,274.228
608,875.821
15.41
8,355.60
13,364.42
110.81
250.93
6,837.05
6,766.72
678.63
-10,072.36
5,981,263.503
608,849.608
18.17
8,383.61
13,394.47
112.85
251.14
6,825.88
6,755.55
669.57
-10,098.74
5,981,254.020
608,823.378
6.82
8,410.98
13,424.43
111.97
246.44
6,814.45
6,744.12
659.55
-10,124.55
5,981,243.592
608,797.732
14.80
8,438.35
13,454.54
111.33
242.46
6,803.34
6,733.01
647.48
-10,149.79
5,981,231.125
608,772.687
12.47
8,466.24
13,484.73
110.15
237.67
6,792.64
6,722.31
633.39
-10,174.25
5,981,216.652
608,748.461
15.34
8,494.46
13,514.61
108.49
233.34
6,782.76
6,712.43
617.42
•10,197.48
5,981,200.318
608,725.490
14.76
8,522.56
13,544.83
105.44
229.64
6,773.94
6,703.61
599.43
-10,220.09
5,981,181.965
608,703.175
15.46
8,551.1L
13,574.58
101.44
229.92
6,767.02
6,696.69
580.75
-10,242.18
5,981,162.939
608,681.386
13.48
8,579.61
13,603.23
97.25
228.72
6,762.37
6,692.04
562.32
-10,263.61
5,981,144.178
608,660.250
15.20
8,607.38
13,634.74
90.77
228.97
6,760.17
6,689.84
541.65
-10,287.26
5,981,123.132
608,636.929
20.58
8,638.21
13,671.20
90.52
224.14
6,759.76
6,689.43
516.58
-10,313.72
5,981,097.655
608,610.871
13.26
8,673.65
13,702.03
90.49
218.26
6,759.49
6,689.16
493.40
-10,334.02
5,981,074.151
606,590.946
19.07
8,702.83
13,739.73
89.39
214.62
6,759.53
6,689.20
463.07
-10,356.41
5,981,043.479
608,569.043
10.09
8,737.38
13,770.68
88.68
209.15
6,760.05
6,689.72
436.81
-10,372.75
5,981,016.959
608,553.123
17.82
8,764.66
13,801.03
89.39
204.12
6,760.56
6,690.23
409.69
-10,386.35
5,980,989.632
608,539.957
16.74
8,790.00
13,832.44
88.65
199.78
6,761.10
6,690.77
380.57
-10,398.09
5,980,960.331
608,528.685
14.01
8,814.72
13,860.73
85.48
195.81
6,762.55
6,692.22
353.68
-10,406.72
5,980,933.307
608,520.481
17.94
8,835.64
1011 71201 6 11.32.24AM Page 9 COMPASS 5000.1 Build 81B
BP W/aa
�p
IJ Final Survey Report BAKER
HUGHES
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Site: PB S Pad
Well: S-113
Wellbore: S-113BL1
Design: 5-11361-1
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
EDM R5K - Alaska PROD - ANCP1
Survey
I
MD Inc
Azi (azimuth)
ND
TVDSS
NIS
EIW
Northing
Easting
DLeg
V. Sec
(usft) V)
V)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
('HOOusft)
(usft)
13,890.73
82.30
191.34
6,765.74
6,695.41
324.69
-10,413.72
5,980,904.218
608,513.941
18.22
8,856.2
13,921.03
81.83
191.28
6,769.92
6,699.59
295.27
-10,419.61
5,980,874.704
608,508.524
1.56
8,876.0
13,962.41
80.68
196.50
6,776.22
6,705.89
255.58
-10,429.42
5,980,834.868
608,499.344
12.77
8,904.35
13,990.46
81.15
200.50
6,780.65
6,710.32
229.32
-10,438.21
5,980,808.473
608,490.975
14.18
8,925.09
14,020.61
80.72
204.39
6,785.40
6,715.07
201.81
-10,449.57
5,980,780.785
608,480.050
12.82
8,948.69
14,050.70
80.44
209.20
6,790.33
6,720.00
175.32
-10,462.95
5,980,754.090
608,467.096
15.80
8,973.52
14,080.28
80.91
213.86
6,795.12
6,724.79
150.44
-10,478.21
5,980,728.981
608,452.234
15.63
8,999.17
14,110.80
81.12
216.89
6,799.89
6,729.56
125.87
-10,495.66
5,980,704.132
608,435.178
9.83
9,026.571
14,140.54
83.48
220.79
6,803.88
6,733.55
102.92
-10,514.14
5,980,680.896
608,417.065
15.23
9,054.051
14,170.38
87.14
223.27
6,806.32
6,735.99
60.84
-10,534.05
5,980,658.500
608,397.512
14.80
9,082.33
14,200.25
93.78
228.78
6,806.08
6,735.75
60.12
-10,555.52
5,980,637.443
608,376.371
28.88
9,111.29
14,230.41
94.67
232.87
6,803.85
6,733.52
41.12
-10,578.83
5,980,618.081
608,353.366
13.84
9,140.98
14,261.15
90.68
234.34
6,802.42
6,732.09
22.90
-10,603.54
5,980,599.477
608,328.949
13.83
9,171.49
14,290.15
93.56
236.42
6,801.35
6,731.02
6.44
-10,627.39
5,980,582.640
608,305.371
12.25
9,200.37
14,320.41
90.55
233.72
6,800.26
6,729.93
-10.87
-10,652.18
5,980,564.938
608,280.863
13.36
9,230.49
14,350.31
94.46
233.39
6,798.96
6,728.63
-28.61
-10,676.20
5,980,546.819
608,257.125
13.12
9,260.17
14,380.63
92.18
231.10
6,797.20
6,726.87
-47.14
-10,700.13
5,980,527.912
608,233.496
10.65
9,290.
14,410.41
93.16
226.57
6,795.81
6,725.48
-66.72
-10,722.52
5,980,507.985
608,211.423
15.55
9,319.33
14,439.99
98.29
229.42
6,792.86
6,722.53
-86.41
-10,744.38
5,980,487.953
608,189.881
19.81
9,348.11
14,470.27
97.02
234.26
6,788.83
6,718.50
-104.94
-10,767.97
5,980,469.047
608,166.590
16.39
9,377.80
14,499.91
94.24
238.89
6,785.92
6,715.59
-121.18
-10,792.58
5,980,452.420
608,142.242
18.15
9,407.24
14.530.58
91.75
242.44
6,784.31
6,713.98
-136.16
-10,819.27
5,980,436.999
608,115.791
14.12
9,437.86
14,560.29
89.08
245.30
6,784.10
6,713.77
-14926
-10,845.94
5,980,423.497
608,089.337
13.17
9,467.49
14,590.45
89.11
249.37
6,784.57
6,714.24
-160.88
-10,873.76
5,980,411.440
608,061.706
13.49
9,497.39
14,626.85
90.83
253.84
6,784.59
6,714.26
-172.37
-10,908.29
5,980,399.411
608,027.365
13.16
9,533.04
14,657.07
93.01
256.00
6,783.58
6,713.25
-180.22
-10,937.45
5,980,391.092
607,998.337
10.15
9,562.221
14,686.73
94.58
260.76
6,781.62
- 6,711.29
-186.18
-10,966.43
5,980,384673
- 607,969.459
-16.87
9,590.30
10/17/2016 11:32:24AM Page 10 COMPASS 5000.1 Build 81B
Company:
North America - ALASKA- BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
5-113
Wellbore:
S-113BL1
Design:
S-113BL1
Survey
MD
Inc
(usft)
(')
14,711.04
94.36
14,740.51
94.55
14,770.11
96.21
14,800.35
98,19
14,830.46
97.95
14,859.93
98.46
14,890.30
97,82
14,923.19
97.70
14,950.43
97,67
14,981.29
97.99
15,012.07
97.70
15,040.33
97,79
15,070.21
97.63
15,099.87
97.41
15,130.45
96.36
15,165.45
97.00
15,188.05
97.25
15,220.05
95.14
15,250.37
92.73
15,281.31
92.18
15,314.83
92.24
15,325.85
92.03
15,368.00
92.03
Projection to TD - 2-3/8"
BP
w3as
Final Survey Report
BAKER
ENV
HUGHES
Local Co-ordinate Reference:
Well 5-113
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K-Alaska PROD -ANCP1
Azi (azimuth)
TVD
TVDSS
N/S
ENV
Northing
Easting
DLeg
M
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
('/100usft)
262.14
6,779.72
6,709.39
-189.79
-10,990.40
5,980,380.690
607,945.555
5.73
257.96
6,777.43
6,707.10
-194.86
-11,019.33
5,980,375.157
607,916.709
14.16
253.71
6,774.66
6,704.33
-202.07
-11,047.89
5,980,367.496
607,888.263
15.36
250.67
6,770.87
6,700.54
-211.24
-11,076.45
5,980,357.872
607,859.855
11.93
246.62
6,766.64
6,696.31
-222.10
-11,104.21
5,980,346.580
607,832.274
13.34
242.75
6,762.43
6,692.10
-234.57
-11,130.58
5,980,333.695
607,806.116
13.11
238.12
6,758.13
6,687.80
-249.40
-11,156.72
5,980,318.452
607,780.215
15.24
233.96
6,753.68
6,683.35
-267.60
-11,183.74
5,980,299.827
607,753.486
12.54
229.80
6,750.04
6,679.71
-284.26
-11,204.97
5,980,282.832
607,732.522
15.13
225,53
6,745.83
6,675.50
-304.84
-11,227.57
5,980,261.894
607,710.259
13.75
221.62
6,741.63
6,671.30
-326.93
-11,248.58
5,980,239.479
607,689.600
12.62
217.21
6,737.82
6,667.49
-348.56
-11,266.36
5,980,217.573
607,672.172
15.47
216.01
6,733.81
6,663.48
-372.32
-11,284.01
5,980,193.530
607,654.895
4.02
214.00
6,729.93
6;659.60
-396.41
-11,300.88
5,980,169.183
607,638.414
6.76
209.91
6,726.26
6,655.93
-422.16
-11,316.94
5,980,143,179
607,622.763
13.71
207.94
6,722.19
6,651.86
-452.59
-11,333.76
5,980,112.495
607,606.437
5.88
206.57
6,719.39
6,649.06
-472.52
-11,344.03
5,980,092.401
607,596.486
6.12
204.57
6,715.93
6,645.60
-501.22
-11,357.76
5,980,063.494
607,583.216
9.06
202.48
6,713.85
6,643.52
-528.95
-11,369.83
5,980,035.577
607,571.587
10.51
201.05
6,712.53
6,642.20
-557.65
-11,381.29
5,980,006.694
607,560.584
4.95
198.87
6,711.23
6,640.90
-589.14
-11,392.72
5,979,975.038
607,549.653
6.50
200.83
6,710.82
6,640.49
-599.49
-11,396.46
5,979,964.623
607,546.079
17.88
200.83
6,709.33
6,639.00
-638.86
-11,411.44
5,979,925.024
607,531.728
0.00
V. Sec
(usft)
9,612.8E
9,640.45
9,668.79
9,698.11
9,727.58
9,756.64
9,786.70
9,819.20
9,845.92
9,875.78
9,905.02
9, 931.23
9,958.41
9,985.05
10,011.84 1
10,041.6'
10, 060.48
10, 086.71
10,111.03
10,135.31
10,160.95
10,169.37
10, 202.03
1011712016 11:32.24AM Page 11
COMPASS 5000,1 Build 818
'� b BP
1"' Final Survey Report
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
S-113
Wellbore:
S-113131-1
Design:
S-11361-1
Casing Points
rel &2
BAKER
HUGHES
Local Co-ordinate Reference:
Well S-113
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K - Alaska PROD - ANCP1
Measured
Depth
(usft)
13,036.00
15,368.00
Vertical
Depth
(usft)
6,764.16
6,709.33
7' Planned TOWS
2-3/8"
Name
Casing
Diameter
(in)
7.000
2.375
Hole
Diameter
(in)
8.500
4.250
Design Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/ -S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
12,989.77
6,722.83
813.39
-9,799.17
TIP
13,039.00
6,766.84
804.40
-9,819.33
KOP Whipstock
13,054.68
6,780.65
801.29
-9,826.06
Interpolated Azimuth
13,087.06
6,807.18
793.21
-9,842.69
Interpolated Azimuth
13,115.57
6,827.27
784.10
-9,860.69
Interpolated Azimuth
13,145.05
6,843.96
772.91
-9,882.20
Interpolated Azimuth
13,175.48
6,856.18
759.85
-9,906.77
Interpolated Azimuth
15,368.00
6,709.33
-638.86
-11,411.44
Projection to TD
Prepared By: Yosha Ragbirsingh Survey Manager Baker Hughes
10/17/2016 11:32:24AM Page 12 COMPASS 5000.1 Build 81B
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMI` `N
WELL- OMPLETION OR RECOMPLETION REPG. _. AND LOG
NOV 092016
1a. Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
1b. Well Class:
20AAC 25.105 20AAC 25.110
GINJ ❑ WINJ ❑ WAG ❑ WDSPL [INo. of Completions: One
Development Cif Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
6. Date Comp., Susp., or Aband.:
14. Permit to Drill Number/Sundry
BP Exploration (Alaska), Inc
10/16/2016
215-218
3. Address:
7. Date Spudded:
15. API Number:
P.O. Box 196612 Anchorage, AK 99519-6612
10/7/2016
50-029-23094-60-00 ,
4a. Location of Well (Governmental Section):
8. Date TD Reached:
16. Well Name and Number:
10/13/2016
PBU S-113BL1 '
Surface: 4542' FSL, 4496' FEL, Sec. 35, T1 2N, R1 2E, UM
9 Ref Elevations KB 70.33 '
17. Field/Pool(s):
Top of Productive Interval: 63' FSL, 3746' FEL, Sec. 28, T12N, R12E, UM
GL 35.96 BF 37.48
PRUDHOE BAY, AURORA OIL -
Undefined
10. Plug Back Depth(MD/TVD):
18. Property Designation:
Total Depth: 1387' FNL, 69' FEL, Sec. 32, T12N, R12E, UM
15368'/ 6709'
ADL 028257, 028258 & 028259
4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27):
11. Total Depth (MD/TVD):
19. Land Use Permit:
Surface: x- 618931 y- 5980745 Zone - ASP 4
15368'/ 6709' '
83-47
TPI: x- 609109 y- 5981397 Zone - ASP 4
12. SSSV Depth (MD/TVD):
20 Thickness of Permafrost MD/TVD:
Total Depth: x- 607531 y- 5979924 Zone - ASP 4
None
1900' (Approx.)
5. Directional or Inclination Survey: Yes ® (attached) No ❑
13. Water Depth, if Offshore:
21. Re-drill/Lateral Top Window
Submit electronic and printed information per 20 AAC 25.050
N/A (ft MSL)
MD/TVD
13039'/ 6767'
22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper,
resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record.
Acronyms may be used. Attach a separate page if necessary
MWD/GR/RES, GR/CCL/RPM
23. CASING, LINER AND CEMENTING RECORD
CASING
WT. PER
FT.
GRADE
SETTING DEPTH MD
SETTING DEPTH TVD
HOLE SIZEAMOUNT
CEMENTING RECORD
PULLED
TOP BOTTOM
TOP BOTTOM
20"
91.5#
H40
33' 113'
33' 113'
42"
260 sx Arctic Set (Approx.)
10-3/4"
45.5#
L-80
33' 5586'
33' 3370'
13-1/2"
784 Arctic Set III Lite, 750 sx Class'G'
7"
26#
L-80
31' 13039'
31' 6767'
9-7/8"
504 sx Class'G'
2-3/8"
4.7#
L-ao
12838' 15368'
6588' 6709' 1
344" x 3"
Uncemented Solid / Slotted Liner
24. Open to production or injection? Yes H No ❑
25. TUBING RECORD
If Yes, list each interval open (MD/TVD of Top and Bottom, Perforation
Size and Number):
GRADE DEPTH SET (MD) PACKER SET (MD/TV
3-1/2" 9.2# L-80 12942' 12884'/ 6629'
2-3/8" Slotted Liner
15240'-15366' 6714'- 6709'
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
COIOIPLLTiOi�4
SATE
Was hydraulic fracturing used during completion?
Yes ❑ No Q ,
Per 20 AAC 25.283 (i)(2) attach electronic and printed
information
VERIFIED
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
Lu
3300' Freeze Protect w/ 35 Bbls Diesel, 10 Bbls Meth
27. PRODUCTION TEST
Date First Production: October 28, 2016
Method of Operation (Flowing, gas lift, etc.): Gas Lift
Date of Test:
Hours Tested:
Production for
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Test Period -1110.
Flow Tubing
Press
Casinq Press:
Calculated
24 Hour Rate ♦
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravitv - API (corn):
Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only
17 V' L- RBDMS L - NOV 1 6 2016
28. CORE DATA Conventional Core(s) Yes ❑ No H Sidewall Cores Yes ❑ No 0 ,
If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water
(submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071.
29. GEOLOGIC MARKERS (List all formations and markers encountered):
30. FORMATION TESTS
NAME
MD
TVD
Permafrost - Top
Well Tested? Yes ❑ No Z
Permafrost - Base
If yes, list intervals and formations tested, briefly summarizing test results. Attach
Top of Productive Interval
13017'
6747'
separate sheets to this form, if needed, and submit detailed test information per 20
AAC 25.071.
KUPARUK C
13017'
6747'
Kicked off from Parent Well
13039'
6767'
(S -113B)
Formation at total depth:
Kuparuk C
13017
6767'
31. List of Attachments: Summary of Daily Drilling Reports, Survey, Wellbore Schematic Diagram
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production
or well test results, per 20 AAC 25.070.
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact: Browning, Zachary H Email: Zachary.Browning@bp.com
Printed Name: .toe Last 'ca Title: Drilling Technologist
Signature: Phone: +1 907 564 4091 Date:
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit
a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.
All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item Ia. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is
a completion.
Item 1 b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other.
Item 4b. TPI (Top of Producing Interval).
Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain).
Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and
analytical laboratory information required by 20 AAC 25.071.
Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests
as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 11/2015 Submit ORIGINAL Only
WELHEAD =
135/8" 5M FMC
ACTUATOR =
--
OKB. ELEV =
70.33'
REF ELEV =
70.33'
BF. ELEV =
37.48'
KOP =
700'
_
Max Angle =
113" @ 13394'
Datum MD =
6700'
Datum TVD =
6700' SS
10-3/4" CSG, 45.5#, L-80, D = 9.950" 1—{ 5587'
Minimum ID = 1.92" @ 12838'
2.63" DEPLOYMENT SLEEVE
TOP OF CEMENT SHEATH 1-i 12868' - 12942'
TBG, 9.2#, L-80_0087 bpf, D = 2.992" 1--j 12942'
3-1/2" MONOBORE WHPSTOCK (10/07/16) 13039'
PERFORATION SUMMARY
REF LOG: BAKER RPM ON 10/15/16
ANGLEATTOPPERF: NA
Note: Refer to Production DB for historical perf data
SQE I SPF I INTERVAL I Opn/Sgz I SHOT SQZ
S -113B
2-1/2" 6 13014 - 13038 S 07/28/02109118/16
2-1/2" 6113018-130 38 S 11/08/02 09/18/16
2-1/2" 6 113038 - 13098 S 06/29/14 09/18/16
OH 113039 - 13044 O 10/07/16
S-113BL1
SLTD 115240 - 153681 SLOT 110/13/161
ISTD 13404'
7' CSG, 26#, L-80 BTC, ID = 6.276' 13491'
S-1 13 B S/ YNOTES: 3-112" CHROME NIPPLES. WELL
L1 ANGLE> 70" @ 5009'. MAX DLS:37" @ 13175'.
2367' f—j 31/2" HES X NP, D = 2.813-
1026-112 11T, ILI z '1
.813"
CO21910i151z'1
ST
MD
TVD
DEV
TYPE
VLV
LATCH PORT
DATE
4
6713
3800
69
MMG
DOME
RK
16
10/23/16
3
11147
5598
62
MMG
SO
RK
20
10/23/16
2
12712
6480
33
MMG
DW
RK
0
07/12/02
1
12802
6557
30
MMG
SO
RK
22
09/18/15
12838' -i2.63" DEPLOYMENTSLEEVF- D= 1.92"
12862 3 112' HES X NP, D = 2.813" BEHIND
CT LNR
12884' 7" X 4-1/2" BAKER S-3 PKR, D = 3.875"
12910' 1-{ 3-1/2" HES X NP, D = 2.813"
12930' j --j 3-1/2" HES X NP, D = 2.813"
12939' FLOW PLUG #3
(2.64" FLOW COLLAR, D = 1.930")
12942' J13-1/2" WLEG, D = 2.992" (BEN ND CT LNR)
12932' ELMD TT (LOGGED 07/28/02)
12971 FLOW PLUG #2
(2.64' FLOW COLLAR, D = 1.930')
MLLOUT WINDOW (S-11313 L7) 13039'-13044-
13695
3039'-13044'13695 H FLOW PLUG #1
(2.64" FLOW COLLAR, D = 1.930")
14600' PUP JT w /RA TAG
15240' 1 JT MACHINED SLTD
< LNR w /30 X.5" HOLES
2-3/8" SOLD LNR 12845' - 15240'
4.7#, L-80 TH511,
.0039 bpf, ID = 1.995"
2-3/8" SLTD Ltd 15240' -15368'
4.7#, L-80 TH511, S -113B L1
_0039 bpf, D = 1.995"
DATE REV BY
COMMENTS DATE REV BY COMMENTS
07/13/02 DACIKK 0111GINAL COMPLETION 11/07/16 ZB/JMD FINAL ODEAPPROVAL
10/16(16 NOREIIC2
CTD ML (S -113B 11-1) 11/09/16 JNL/JMD RXED SLTD LNR DEPTH
10/21/16 JMD
DRLG HO CORREC'110NS
10/25/16 JNUJMD
RE=&BF ELEV - MB OH DEPTHS PERF SUM
10/27/16 JAW/
GLV C/O (10/23/16)
1 1/031161CMJhq
ADDED CMFUMNOR CORRECTIONS
AURORA UNIT
WELL: S -113B L1
PERMIT No: "`1152180
AR No: 50-029-23094-02160
SEC 35, T12K R12E 739 FNL & 783' FWL
BP Exploration (Alaska)
Printed 10/24/2016 9:42:16AM 'All depths reported in Drillers Depths`
North America - ALASKA - BP
Page 1 of 19
Operation Summary Report
Common Well Name: S-113
AFE No
Event Type: RE-ENTER- ONSHORE
(RON)
Start Date: 10/2/2016 End Date:
10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
Task Code NPT NPT Depth
Phase
Description of Operations
(hr)
(usft)
10/2/2016 19:00 19:30
0.50
MOB P
PRE
PREPARE RIG TO BACK OFF WELL
19:30 20:30
1.00
MOB P
PRE
PJSM WITH ALL INVOLVED PARTIES.
DISCUSS LIGHT POLE PROXIMITY
-TESTED AND VERIFIED ESD WAS
FUNCTIONALAND IS MANNED BY
TOOLPUSHER
-VERIFIED 12 X 12 WHEEL CHOCK IN PLACE
-ASSIGNED SPOTTERS TO AREA OF
RESPONSIBILITY
-AGREED ON STOP WAS THE COMMAND TO
STOP RIG.
-PERFORMED RADIO CHECK PRIOR TO
MOVING RIG.
-DISCUSSED WITH CREW THAT THERE WAS
NO BPV INSTALLED
20:30 - 21:30
1.00
MOB
P
PRE
STAGE RIG
CLEANUP AROUND WELLHEAD. PICKUP
:MATS
DRILLER / TOURPUSHER PERFORMED
ROUTE DRIVE
21:30 - 23:00
1.50
MOB
P
PRE
MOVE RIG FROM W -PAD TO MOBILE PAD.
STAGE FOR RIG MAT SHUFFLE.
23:00 00:00
1.00
MOB N WAIT
PRE
STAND-BY FOR RIG MATS TO BE SHUFFLED
10/3/2016 00:00 - 03:00
3.00
MOB N WAIT
PRE
CONTINUE TO WAIT FOR MATS.
03:00 - 06:00
3.00
MOB P
PRE
CONTINUE MOVE TO S -PAD.
06:00 08:00
1 2.00
MOB P
PRE
MOVE UP ACCESS ROAD AND STAGE AT
S-113.
LOCK OUT ADJACENT WELLS PER WELL
PLAN
PJSM FOR PULLING OVER WELL.
EMPHASIZE THAT PLUG IS NOT IN WELL,
PROXIMITY OF ADJACENT WELLS. DISCUSS
VISUAL SIGNALS AND AUDIBLE COMMANDS.
ASSIGN PERSON TO 12X12 BLOCKAND ESD.
FUNCTION ESD.
PULL OVER WELL. RIG ACCEPTAT 0800
--
HRS. —
08:00 12:30
4.50
MOB P
PRE
BEGIN RIG UP OPERATIONS
STAGE SUPPORT EQUIPMENT
OPEN UP SSV, CYCLE TREE VALVES PER
WELL PLAN
TEST AND ND TREE CAP
NU BOP: ANNULAR ELEMENT, BLIND/SHEAR
RAMS, UPPER 2" COMBI RAMS, 2-3/8" COMBI
RAMS, LOWER 2" COMBI RAMS
TAKE ON WATER FOR BOP TEST, FLUID
PACK LINES
PRE -SPUD FOR WELL WITH ENTIRE TEAM.
CONDUCT H2S RIG EVAC DRILL WITH TEAM.
CONDUCTAAR.
PJSM FOR BEGINNING BOP TEST
Printed 10/24/2016 9:42:16AM 'All depths reported in Drillers Depths`
North America - ALASKA - BP
Operation Summary Report
Page 2 of 19
Common Well Name. a-113
118:30 - 19:30
1.00
AFE No
Event Type: RE-ENTER- ONSHORE (RON)
Start Date: 10/2/2016
End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PBS Pad
BOPSUR
BOPSUR
P
P
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002
12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs
Task Code NPT
NPT Depth
Phase
Description of Operations
_ (hr)
12:30 - 18:30 6.00
__
BOPSUR
� P
�(usft )
PRE
BODY TEST BOP WITH AOGCC REP BRIAN
BIXBY ON LOCATION. GOOD TEST.
BEGIN BOP TEST PER PERMITAND WELL
PLAN. TEST TO AOGCC, NORDIC, BP
REGULATIONS AND REQUIREMENTS.
23:45 - 00:00 0.25 BOPSUR P
10/4/2016 00:00 - 00:25 0.42 CONDHL P
00:25
118:30 - 19:30
1.00
BOPSUR
I P
422:30
:30 - 22:00
:00 - 22:30
- 2310
2.50
0.50
0.67
BOPSUR
P
BOPSUR
BOPSUR
P
P
I
23:10 - 23:45
0.58
BOPSUR
P
23:45 - 00:00 0.25 BOPSUR P
10/4/2016 00:00 - 00:25 0.42 CONDHL P
00:25
- 02:00 I
1.58
EVAL
N SFAL
02:00
05:00
3.00
CONDHL
P
05:00
- 06:30
1.50
EVAL
P
TEST ALL COMPONENTS TO 250 PSI LOW/
3500 PSI HIGH, FUNCTION RAMS FROM
DRILLERS CONSOLE.
TEST WITH 2" AND 2-3/8" TEST JOINTS
CONDUCT ACCUMULATOR DRAWDOWN
TEST WHILE FUNCTIONING RAMS FROM COIL
TUBING CONSOLE
STAB ON WITH COIL, PRESSURE TEST
INNER REEL VALVE AND PACKOFFS TO 250
PSI LOW / 3500 PSI HIGH
PRE POP OFF AND INSTALL FLOATS. TEST TO 300
LOW / 3500# HIGH GOOD
PRE STAB ON. TEST QTS. SWAP COIL OVER TO
METHAANOL SPEAR / 1 % KCL FOR ENTRY.
PRE PRESPUD / RIG EVACUATION DRILL WITH
NIGHT CREW — —
PRE PJSM, DISCUSS OPEN WELL UP FOR FLOW
CHECK. PJSM FOR BHA MAKEUP
PRE OPEN WELL WITH 30#. BLEED TO
FLOWBACK TANK. IMMEDIATELY DROPPED
OFF. PERFORM 10 FLOW CHECK. WELL
STATIC
PRE MAKE UP 2-3/8" MILLING BHA#1
- PICK UP 2-3/8" XTREME MOTOR (0.9 DEG
AKO) AND 2-3/8"" COILTRAK TOOLS
MAKE UP 2.80" HUGHES D331GEB MILL.
SMOOTH GAUGE. 2.81" GO / 2.80" NOGO
SURFACE TESTED TOOL. GOOD TEST.
PRESSURE TEST QTS TO 300 PSI LOW FOR
5 MINUTES / 3500 PSI HIGH FOR 5 MINUTES
- INJECTOR ON: 23:59
WEXIT ESTABLISH CIRCULATION.
START IN HOLE, TAKING RETURNS TO
FLOWBACK TANK.
BHI COUNTER NOT TRACKING.
WEXIT BHI COUNTER NOT TRACKING BHI
TROUBLESHOOT_.
WEXIT START IN HOLE
- DISPLACE WELL FLUIDS TO FLOW BACK
TANK WITH WARM 8.33 PPG KCL WHILE
HOLDING 100 PSI BACK PRESSURE
- NO ISSUES WITH INITIAL DISPLACEMENT,
NO GASEOUS RETURNS
WEXIT LOG FOR PRIMARY DEPTH CONTROL TIE-IN.
- CONTINUE DISPLACING WITH WARM 8.33
PPG KCL TO FLOW BACK TANK HOLDING
BACK PRESSURE
- INITIAL CORRECTION OF -31.5' TO PDC LOG
BUT HAVING DIFFICULTY ALIGNING WITH LOG
PROVIDED TO GEOLOGIST
TAG TOP OF CEMENT AT 12,900'
UNCORRECTED DEPTH
'All depths reported in Drillers Depths'
North America - ALASKA - BP
Operation Summary Report
Page 3 of 19
Common Well Name: S-113
AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PBS Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs Task Code NPT NPT Depth Phase
Description of Operations
—_ (hr) - (usft)
06:30 - 07:45 1.25 CONDHL P WEXIT
DISPLACE TO HI -VIS KCL MILLING FLUID
GEO CONFIDENT THAT LOG CORRELATES
TO PREVIOUS CALIPER LOG PROVIDED BY
PDS BEFORE CEMENTING. RECORD -32'
CORRECTION.
LOG CCL WHILE CONTINUING TO DISPLACE
TO THE 8.4 PPG VIS KCL
GOOD KCLALL THE WAY AROUND
SEND DATA TO TOWN TEAM, WAIT ON
'CONFIRMATION TO PROCEED
07:45 09:00 1.25 STMILL N WAIT WEXIT
CONSULTED WITH TOWN, VERIFIED AND
AGREED UPON DEPTH SHIFTAND TOC.
109:00 14:00 5.00 STMILL P WEXIT
MOVE DOWN TO TOP OF CEMENT.
INITIAL PARAMETERS: MM IN 1.72 BPM, MM
OUT 1.71 BPM, MW IN 8.46 PPG, MW OUT 8.43
PPG, WOB .2K
MILL FROM 12,870' WITH SEVERAL STALLS
TO START OFF. MAKE PROGRESS DOWN TO
12,875' BUT HAVE A COUPLE OF QUICK
STALLS WITH SLOW ROP. THIS
CORRELATES TO WHERE PACKER IS SET.
PICK UP, TURN 180° OUT AND RE-ENGAGE
MILLING. MAKE PROGRESS, ROP AND WOB
PICKED UP INDICATING THAT MILL IS NOT ON
METAL.
PICK UP, REAM AROUND EDGES TO CLEAN
IT UP. MOVE BACK DOWN WITH MILLAT 15°
ORIENTATION TO CONTINUE MILLING HIGH
SIDE.
CONTINUE MILLING PILOTAT 15° ROHS.
ATTEMPT TO MAINTAIN 1.5 TO 2.5 K WOB.
MULTIPLE STALLS WHILE DRILLING. ROP
- ECD CLIMBING, RATTY PICKUP WEIGHTS.
PUMPED 10 BBLS HIVIS SWEEP.
14:00 16:00 2.00 STMILL P WEXIT
- STARTED PACKING OFF. PUMP SWEEP.
DISCUSS ADDITION OF CFS -520 WITH ODE
AND BAROID.
-WIPER UP TO 12500'. RIH AT 100 FPM TO
ACCELERATE CUTTINGS.
-INCREASE AV TO 452 FPM.
RIH AND RE-ENGAGE DRILLING
16:00 17:00 1.00 STMILL P WEXIT
CALL ODE AND DISCUSS ISSUES WITH
MILLING FLUID, STICK SLIP ISSUES, PUMP
PRESSURE IS HIGH, CARRYING CAPACITY OF
THE FLUID IS NOT KEEPING THE HOLE
CLEAN BECAUSE WE ARE PACKING OFF AND
HAVE TO PU TO PULL FREE AND ESTABLISH
RETURNSAGAIN
17:00 18:30 1.50 STMILL P WEXIT
STOP MILLING AND PU TO ENSURE THE
HOLE BEHIND US IS CLEAN BEHIND US
PU 2000' TO 10900'
12500' ECD'S ARE STARTING TO CLIMB AND
THE COIL WEIGHT IS CYCLING. LOOKS LIKE
THE CMT IS FALLING OUT OF THE FLUID AND
PACKING OFF THEN CLEARING CAUSING THE
WEIGHT TO CYCLE
PUMP A 10 BBL HIGH VIS PILL
HIGH VIS PILL BROUGHT UP A FAIR AMOUNT
-- - -- —_- - —_ _—
OF CMT CUTTINGS, RIH
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths'
North America - ALASKA - BP
Operation Summary Report
Common Well Name: S-113 AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations
- -(hr) (usft)
18:30 - 19.30 1.00 STMILL P WEXIT BACK ON BOTTOM MILLING
Page 4 of 19
3.33 STMILL P WEXIT MILL 2.80" CEMENT PILOT HOLE IN 7.0" LINER
PER WELL PROGRAM FROM 13010" MD TO
13070' MD
RATE: 1.80 BPM IN, 1.80 BPM OUT
MUD WEIGHT: 8.56 PPG IN, 8.51 PPG OUT
3.33 STMILL P
06:40 06:50 1 0.17 STMILL
06:50 - 07:05 0.25 STMILL
07:05 - 10:00 2.92 STMILL
I
P
P
P
- 10:00 - 10:10 0.17 STMILL P
DWOB: 1.5 - 2.0 KLBS
FREE SPIN 3680# @ 1.80 BPM
CIRC PRESSURE: 3940 PSI
WT TRANSFER IS LOW BUT THE WOB IS
RELATIVELY CONSISTENT ROP OF 15-20
FPH.
0.5% ADDITION OF NXS LUBRICANT HELPED
STAYING CONSISTENT TO MILL THE PILOT
SLIDE
WEXIT
PERFORM REAMING PASSES 45° LOHS /45°
ROHS MADE TWO PASSES. 12960' UP TO
HOLE
19:30
20:00
0.50
STMILL
P
WEXIT
MADE 5' WITH CONSISTENT WOB AVG
LOG CCL FROM 12800' TO 13050' FOR LINER.
PUMP 10 BBLS HI VIS SWEEP. TAG
CORRECTED TD OF 13084'
1_5-2.OK WOB AT 25-30 FPH ROP
PERFORM 10 MIN DYNAMIC FLOW CHECK
WEXIT
GOOD FLOW CHECK, POOH TO TOP OF
PILOT HOLE PUMPING THROUGH THE MILL
WEXIT
START 80 BBL PILL OF 0.5% NXS LUBE DOWN
AND POOH PUMPING AT MAX RATE PUMPING
2 HIGH VIS PILLS ON THE WAY OUT
FIRST PILL HAD A SLIGHT INCREASE IN CMT
THE COIL
120,00
20:40
0.67
STMILL
P
WEXIT
ROP SLOWING DOWN TO -20 FPH AND STILL
_
CHECK WELL
_
WEXIT
FLOW CHECK WELL
ABLE TO MILL WITH CONSISTENT WOB
120:40
20:50 1
0.17
STMILL
P
WEXIT
NXS LUDE AT SURFACE AND SURFACE
WEIGHT HAS INCREASED FROM 4.5 - 5.5K TO
5.5K - 6.5K WHILE MILLING
20:50
- 00:00
3.17
STMILL
P
WEXIT
ECD SLOWLY INCREASING. PUMP SWEEP.
LET 10 BBLS OUT. CHASE UP TO 11,000'
OPEN EDC ONCE ABOVE TOC. CHASE AT
MAX RATE.
SWEEP BROUGHT BACKAN INCREASED
AMOUNT OF CUTTINGS.
RIH AT 100' /MIN TO ACCELERATE CUTTINGS.
INCREASE AV TO 580 FPM.
STOP AT 12800' CLOSE EDC
3.33 STMILL P WEXIT MILL 2.80" CEMENT PILOT HOLE IN 7.0" LINER
PER WELL PROGRAM FROM 13010" MD TO
13070' MD
RATE: 1.80 BPM IN, 1.80 BPM OUT
MUD WEIGHT: 8.56 PPG IN, 8.51 PPG OUT
3.33 STMILL P
06:40 06:50 1 0.17 STMILL
06:50 - 07:05 0.25 STMILL
07:05 - 10:00 2.92 STMILL
I
P
P
P
- 10:00 - 10:10 0.17 STMILL P
`All depths reported in Drillers Depths'
DWOB: 1.5 - 2.0 KLBS
FREE SPIN 3680# @ 1.80 BPM
CIRC PRESSURE: 3940 PSI
RELATIVELY CONSISTENT ROP OF 15-20
FPH.
0.5% ADDITION OF NXS LUBRICANT HELPED
WITH MAINTAINING CONSISTENT WOB AND
SLIDE
WEXIT
PERFORM REAMING PASSES 45° LOHS /45°
ROHS MADE TWO PASSES. 12960' UP TO
TUBING TAIL
REAMED TUBING TAIL. RAN TO BOTTOM.
REAM TUBING TAIL.
LOG +15' CORRECTION TO PDC
LOG CCL FROM 12800' TO 13050' FOR LINER.
PUMP 10 BBLS HI VIS SWEEP. TAG
CORRECTED TD OF 13084'
WEXIT
PERFORM 10 MIN DYNAMIC FLOW CHECK
WEXIT
GOOD FLOW CHECK, POOH TO TOP OF
PILOT HOLE PUMPING THROUGH THE MILL
WEXIT
ABOVE THE PILOT HOLE, OPEN THE EDC
AND POOH PUMPING AT MAX RATE PUMPING
2 HIGH VIS PILLS ON THE WAY OUT
FIRST PILL HAD A SLIGHT INCREASE IN CMT
CUTTINGS, 2ND PILL HAD A LOT OF METAL
SHAVINGS
HOLDA PJSM WHILE POOH TO LD THE
MILLING BHAAND MU THE LOGGING BHA
JOG IN HOLE THEN PU TO 200' AND FLOW
CHECK WELL
_
WEXIT
FLOW CHECK WELL
`All depths reported in Drillers Depths'
North America - ALASKA - BP Page 5 of 19
Operation Summary Report
Common Well Name: 5-113 AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs Task Code NPT NPT Depth j Phase Description of Operations
(hr) (usft)
10:10 10:35 0.42 STMILL P WEXIT iGOOD NO FLOW, TAG UPAND REMOVE THE
— — - INJECTOR
10:35 10:45 0.17 STMILL P WEXIT BHA OOH, MILL IN GAUGE AT 2.80 NO GO
10:4511:00
13:50
0.25
T STMILL
P
11:00
11:15
0.25
STMILL
P
14:15
- 15:05
0.83
STMILL
I
STMILL
I P
P
�
11:15
11:30
0.25
STMILL
P
11:30
13:50
2.33
STMILL
P
13:50
- 14:15
0.42
t
STMILLTP
11:15 INJECTOR ON
14:15
- 15:05
0.83
STMILL
I
STMILL
I P
P
�
15:05 - 17:15
�
2.17
I
[17:15 - 17:25 0.17 STMILL
17:25 17:35 0.17 i STMILL
17:35 19:00 1.42 STMILL
I
PERFORM 5 MIN PULL TEST ON RED TUGGER
FOR ANNUAL TEST
WEXIT
LOAD PDS CALIPER TOOL ON RIG
WEXIT
MU LOGGING BHA
11:15 INJECTOR ON
WEXIT
ONLINE WITH PUMP
TEST- PURGE AIR FROM LUBRICATOR WITH
LIQUID TO SEE IF WE CAN DO THIS WHEN
WE HAVE GAS AT SURFACE
CONNECT 1/2" HP HOSE FROM LUBRICATOR
WHITEY TO CHOKE VALVE 18 WHITEYAND
OPEN VALVES
AIR WAS PURGED FROM THE LUBRICATOR
WITH FLIUD IN JUST UNDER A MINUTE.
THIS PROCESS CAN BE USED WHEN WE
HAVE GAS TO SURFACE TO REMOVE ALL
FREE GAS FROM THE RIG AND SEND OUT TO
THE TIGER TANK
THIS WILL HELP ENSURE WE DO NOT ALLOW
ANY FREE GAS TO ENTER THE RIG PIT_ AREA
WEXIT
RIH WITH LOGGIN BHA
WEXIT
LOG TIE IN
WEXIT
i CORRECT DEPTH -30 CORRECTION, RIH TO
BOTTOM
STACKING WT AT 12893' PU AND R
WEXIT
10 ATTEMPTS TO GET PAST 12892 WERE
UNSUCCESSFUL. CALL ODE AND DISCUSS
LIMITED OPTIONS AS THE CALIPER ARMS
ARE SET TO OPEN AT 15:37
'POOH TO 11,000' ABO BEFORE THE CALIPER
ARMS OPEN
DECISION MADE TO POOH FOR CLEAN OUT
BHA WITH A 2.80 STRING MILL
P WEXIT FLOW CHECK WELL
P WEXIT GOOD NO FLOW, TAG UP AND PULL THE BHA
N HMAN WEXIT BHA OOH, WAIT ON STRING REAMER FROM
19:00 - 19:25 0.42 STMILL P
BAKER THRU TUBING, MIS COMMUNICATION
BETWEEN BTT TOWN ENGINEER AND SLOPE
SHOP
WEXIT MAKE UP 2-3/8" DRILLING BHA #3
- PICK UP 2-3/8" XTREME MOTOR (0.6 DEG
AKO) AND 2-3/8"" COILTRAK TOOLS
- MAKE UP 2.80" STRING REAMER / 2.80 "
D331GEB MIL (HUGHES CHRISTENSEN)
SURFACE TESTED TOOL. GOOD TEST.
PRESSURE TEST QTS TO 300 PSI LOW FOR
5 MINUTES / 3500 PSI HIGH FOR 5 MINUTES
INJECTOR ON: 19:25
'All depths reported in Drillers Depths`
North America - ALASKA - BP
Operation Summary Report
Page 6 of 19
Common Well Name: S-113
08:45
AFE No
Event Type: RE-ENTER- ONSHORE (RON)
Start Date: 10/2/2016 End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad
STMILL
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs
Task Code NPT NPT Depth Phase
Description of Operations
(hr)
(usft) -
19:25 - 22:20 2.92
STMILL P WEXIT
RIH WITH 2-3/8" MILLING BHA#3 FROM
2220 - 0000 1.67 STMILL
10/6/2016 00:00 - 0600 6.00 STMILL
P -
P
06:00
08:45
2.75
STMILL
P
08:45
09:20
0.58
STMILL
P
SURFACE' MD TO 12770' MD
- RATE: 0.6 BPM IN, 0.98 BPM OUT. CIRC
PRESSURE: 1100 PSI
MUD WEIGHT: 8.61 PPG IN, 8.53 PPG OUT
LOG DOWN FOR TIE-IN FROM 12770' TO
12791' MD (FORMATION) WITH -30'
CORRECTION
WEXIT RIH TO DRY TAG
DRY TAG 12877' WITH 0° TOOLFACE
PICKUP AND ROTATE TO 180° TOOLFACE.
TAG SAME PLACE.
PICKUP AND ATTEMPT MINIMUM RATE. NO
LUCK.
PICKUP BRING UP TO 1.80 BPM (MILLING
RATE). STALLED.
PICKUP AND RIH AT 30 FPH. SMALL
INCREASE IN MOTOR WORK. BUT WENT
RIGHT BY.
INCREASED TO 60 FPH REAMING PASS
'DOWN AT 180° TOOLFACE.
WEXIT 1.80 BPM IN / 1.81 BPM OUT 8.60 PPG IN /
8.53 PPG OUT
'- CONTINUE REAMING IN THE HOLE AT 60
FPH AT 180° TOOLFACE. NOTHING SEEN TO
TUBING TAIL. ROLL TOOLFACE TOO'. RUN
DOWN TO 12974'.
- BACK REAM AT 0° TOOLFACE FROM
TRANSITION AREA UP TO 12960' AT -70 FPH.
NOTHING SEEN.
- RUN BACK TO 12974' MAINTAINING HIGH
SIDE ORIENTATION. NOTHING SEEN
-BACK REAM AT 45° LOHS FROM 12974' TO
TUBING TAIL AT 12932'. ROLL TOOLFACE TO
90° LOHS AND CONTINUE BACKREAMING AT
60FPH TO 12960'. NO ISSUES
RUN BACK TO 12975'. MAINTAINING AO°
TOOLFACE. NO ISSUES.
- BACK REAM AT 45° ROHS FROM 12975' TO
TUBING TAIL AT 12932', ROLLTOOLFACE TO
900 ROHS AND CONTINUE BACKREAMING AT
60 FPH TO 12960'
- RUN BACK TO 12932' (TUBING TAIL). BACK
REAM AT 180° TOOLFACE AT 60 FPH.
WEXIT CONTINUE FINAL BACKREAM UP PASS UP TO
12860
07:15 - CLEAN PASS UP, RIH TO TD AND
PUMP 15 BBL HIGH VIS PILLAND CHASE
OOH TO TOC
07:30 - DRIFT TO TD WAS CLEAN, PUMP HIGH
VIS PILL
08:25 - ABOVE TOC JOG IN HOLE 100' AND
OPEN EDC TO FINISH CIRC OUT OF HIGH VIS
PILL
WEXIT BOTTOMS UP HAD A LITTLE INCREASE IN
CUTTINGS ANDA LITTLE METAL.
CLOSE THE EDC AND PREP TO DRY DRIFT TO
12900' PAST THE PACKER DEPTH AS PER
DISCUSSION FROM MORNING CALL ATALL 4
QUADRANTS 0°, 90°, 180° AND 270°
ALL 4 QUADRANTS HAD CLEAN DRIFTS
RIH TO TO WITH A 00 TF
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths*
North America - ALASKA - BP
Operation Summary Report
Page 7 of 19
Common Well Name: S-113 AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations
(hr) - — (usft) --
09:20 - 09:50 0.50 STMILL P WEXIT TAG HAD BOTTOM
PU AND BRING PUMP ONLINE AT MAX RATE
AN PUH TO 12000' (60° HOLE INCLINATION)
JOG IN HOLE 150' THEN SHUT DOWN TO
—'I -— OPEN THE EDC
09:50 - 10:00 0.17 STMILL P WEXIT EDC OPEN DYNAMIC FLOW CHECK WELL TO
-- ---1POOH
10:00 - 12:15 2.25 STMILL P WEXIT GOOD FLOW CHECK, POOH
HOLD PJSM TO LD THE MILLING BHA AND
MU THE CALIPER DRIFT BHA
_ L ATR SURFACE JOG IN HOLE 150'
12:15 - 12:25 0.17 STMILL PWEXIT IFLOW CHECK WELL
12:25 - 12:45 0.33 STMILL P WEXIT GOOD NO FLOW, TAG UP, REMOVE
INJECTOR AND LD THE BHA
12:35 INJECTOR OFF
_ MILLS IN GAUGE
12:45 - 12:55 0.17 STMILL P WEXIT BHA OOH
MU PDS CALIPER TOOLAND INITIATE TOOL
_ FOR SURFACE TEST
12:55 - 13:10 0.25 STMILL N DFAL WEXIT DS TOOL FAILED, CALIPER ARMS OPENED,
STARTED CLOSING THEN STOPPED WITH
l
ARMS -30% OPEN
_ SWAP OUT TOOL
13:10 - 13:40 0.50 STMILL P WEXIT MU TOOLAND INITIATE FOR SURFACE TEST
i I
GOOD TEST, MU BHA
TIME DELAY SET FOR 3 -HRS & 45 MIN FROM
13:25
I NEED TO BE STOPPED BY 17:07, FINGERS
SET TO OPEN AT 17:10
BEGIN LOGGING UP AT 17:16
FINGERS CLOSED AT 17:34
13:40- - 15:55 2.25 STMILL P WEXIT RIH
15:55 - 16:15 0.33 STMILL P WEXIT LOG TIE IN
16:15 - 17:15 1.00 STMILL P WEXIT CORRECT DEPTH -31.5' AND RIH
17:15 17:35 0.33 STMILL P WEXIT CALIPER ARMS ARE OPEN START LOGGING
UP 17:35 - 19:45 2.17 STMLOGGING P WEXIT LOGGINGNG COMPLETED, POOH
PJSM FOR BHA PICKUP / LAYDOWN.
PERFORM 10 MIN FLOW CHECK. WELL
STATIC. TAG UP
19:45 21:05 1.33 STMILL P WEXIT INJECTOR OFF: 19:45
LAY DOWN PDS CALIPER /DRIFT ASSEMBLY.
PDS DOWNLOAD AND VERIFIED DATA WHILE
PICKING UP WHIPSTOCK.
GOOD DATA. PDS UPLOADED TO HOUSTON
FOR PROCESSING.
MAKE UP 2.625" WHIPSTOCK AND 2-3/8"
COI LTRAK TOOLS.
SURFACE TESTED TOOL. GOOD TEST.
PRESSURE TEST QTS TO 300 PSI LOW FOR
5 MINUTES / 3500 PSI HIGH FOR 5 MINUTES
INJECTOR ON: 20:45
Printed 10/24/2016 9:42:16AM `All depths reported in Drillers Depths'
Printed 10/24/2016 9:42:16AM 'All depths reported in Drillers Depths`
North America - ALASKA - BP
Page 8 of 19
Operation Summary Report
Common Well Name: S-113
AFE No
Event Type: RE-ENTER- ONSHORE
(RON)
Start Date: 10/2/2016 End Date:
10/14/2016
X3-017VQ-C: (2,843,222.00)
Project. Prudhoe Bay
Site: PB
S Pad
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft
(above Mean Sea Level)
Date From - To
Hrs
Task
Code NPT NPT Depth
Phase
Description of Operations
--- -- -
(hr) -
(usft
21:05 - 23:30
2.42
STMILL
P
WEXIT
RIH WITH 2.625" WHIPSTOCK BHA #5 FROM
SURFACE TO 12850' MD
RATE: 0.4 BPM IN, 0.79 BPM OUT. CIRC
PRESSURE: 1300 PSI
MUD WEIGHT: 8.56 PPG IN, 5.58 PPG OUT
LOG DOWN FOR TIE-IN FROM 12850' TO
12915" MD (FORMATION) WITH -33'
_ _ — -
CORRECTION
23:30 - 00:00
0.50
STMILL
P
WEXIT
LOG CCL FROM 12881' TO 13080'
10/7/2016 00:00 - 00:15
0.25
WHIP
P
WEXIT
CONTINUE LOGGING CCL TO 13080'
,REVIEW PDS LOG TO CCL LOG. LOOKING
I LIKE +6' TO CCL LOG.
00:15 01:30
1.25
WHIP
P
WEXIT
DISCUSS WITH ODE THE CORRELATION
I BETWEEN CCLAND PDS.
DECISION TO SHIFT TOWS DOWN TO 13038'
- --
--
TOWS @ 10° ROHS.
01:30 - 02:00
0.50
WHIP
P
WEXIT
PU HOLE ABOVE SET DEPTH 36K PICKUP
WEIGHT.
CLOSE EDC. RIH TO SET DEPTH OF 13046.72'
-8.72' =13038' TOWS SET DEPTH. RIH
WEIGHT 7K.
ORIENTATION SET TO 10° ROHS
PICKUP TO NEUTRAL WEIGHT. COME
ONLINE WITH PUMP DOWN COIL.
PRESSURE UP TO 4300#, SHEARED. GOOD
INDICATION WITH WOB. STACKED 5K.
GOOD.
PICKED OFF WHIPSTOCK CLEAN
02:00 02:10
0.17
WHIP
P
WEXIT
PERFORMED 10 MIN FLOW CHECK. WELL
STATIC.
02:10 - 03:55
1.75
WHIP
P
WEXIT
MUD WEIGHT: 8.58 PPG IN, 8.58 PPG OUT
RATE: 1.07 BPM IN, 0.60 BPM OUT
POH FROM 13038' MD TO SURFACE' MD
RATE: 1.08 BPM. CIRC PRESSURE: 1761 PSI
PJSM FOR BHA SWAP AT 2500'
03:55 - 04:15
0.33
WHIP
P
WEXIT
LD BHA
MONITOR WELL FOR 10 MINUTESAT BHA:
STATIC
INJECTOR OFF: 04:15
04:15 - 04:45
0.50
WHIP
P
WEXIT
MAKE UP 2.80" WINDOW MILLING BHA #6
- PICK UP 2-3/8"" XTREME MOTOR (0.6 DEG
AKO) AND 2-3/8"" COILTRAK TOOLS
- MAKE UP 2.80" WINDOW MILLAND 2.79"
STRING REAMER
SURFACE TESTED TOOL. GOOD TEST.
PRESSURE TEST QTS TO 300 PSI LOW FOR
5 MINUTES / 3500 PSI HIGH FOR 5 MINUTES
_
- INJECTOR ON: 04:45
04:45 - 07:00
2.25
WHIP
P
WEXIT
RIH WITH 2-3/8" "MILLING ASSEMBLY BHA #6
FROM SURFACE' MD TO 12870' MD
- RATE: 1.39 BPM IN, 1.77 BPM OUT. CIRC
PRESSURE: 2263 PSI
MUD WEIGHT: 8.59 PPG IN, 8.59 PPG OUT
07:00 07:25
0.42
WHIP
P
WEXIT
LOG TIE IN
SWAP TO NEW MUD
0725 08:25
1.00
WHIP
P
WEXIT
CORRECT DEPTH -31', CONTINUE SWAPPING
WELL OVER TO NEW MUD
Printed 10/24/2016 9:42:16AM 'All depths reported in Drillers Depths`
North America - ALASKA - BP
Operation Summary Report
Common Well Name: S-113
AFE No
Page 9 of 19
Event Type: RE-ENTER- ONSHORE (RON)
Start Date: 10/2/2016
End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM 'Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
Task Code NPT
NPT Depth Phase Description of Operations
-
(hr)
(usft)
08:25 08:30
0.08
STWHIP P
WEXIT WELL SWAPPED TO NEW MUD, RIH TO TAG
PINCH POINT
PARAMETERS BEFORE SWAPPING TO NEW
MUD
RIH AT 100 FPM = 2-3K SURFACE WT
PU WT = 32K
LOGGING SPEED 2.5 FPM = 5.5K
PARAMETERS AFTER SWAPPING TO NEW
MUD
RIH AT 100 FPM = 6-7K
PU WT = 28K
LOGGING SPEED 2.5 FPM =_8K
08:30 - 08:40
0.17
STWHIP P
WEXIT
DRY TAG WS AT 13039, PU AND BRING THE
PUMP ONLINE AND WORK DOWN TO THE
PINCH POINT
FS = 3757 AT 1.75 BPM
08:40 - 11:35
2.92
STWHIP
P
WEXIT
TAG WS AT 13,088.9, START MILLING THE
WINDOW
MILL 2.80" WINDOW IN 7" CASING PER BAKER
REP FROM 13,038.9' MD TO 13,044.V MD
RATE: 1.75 BPM IN, 1.76 BPM OUT
MUD WEIGHT: 8.64 PPG IN, 8.56 PPG OUT
DWOB: 1.65 - 3.50 KLBS
-
CIRC PRESSURE: 4040 PSI
-
11:35 13:00
-
1.42
--
STWHIP P
WEXIT
CONTINUE TO MILL 2.80" WINDOW IN 7"
CASING PER BAKER REP FROM 13,038.9' MD
TO 13,044.1' MD
RATE: 1.74 BPM IN, 1.76 BPM OUT
MUD WEIGHT: 8.63 PPG IN, 8.56 PPG OUT
DWOB: 2.35 - 2.65 KLBS
_
CIRC PRESSURE: 3915 PSI
13:00 13:45
0.75
STWHIP P
WEXIT CONTINUE TO MILL 2.80" WINDOW IN 7"
CASING PER BAKER REP FROM 13,038.9' MD
TO 13,044.1' MD
RATE: 1.74 BPM IN, 1.75 BPM OUT
MUD WEIGHT: 8.60 PPG IN, 8.55 PPG OUT
DWOB: 2.00 - 2.45 KLBS
-
__-_CIRC PRESSURE: 3918 PSI
13:45 15:10
1.42
STWHIP P
WEXIT LOOKS LIKE WE EXITED THE BOTTOM OF
THE WINDOWAT 13,0437, WINDOW LENGTH
= 4.8'OUT OF 5.2'
CONTINUE REAMING TO 13,045' (1.3') TO
DRESS THE BOTTOM OF THE WINDOW WITH
THE STRING MILL THEN START MILLING 10'
OF RAT HOLE TO 13,055-
15:10 - 15:45
0.58
STWHIP P
WEXIT MILL 10' OF RAT HOLE
15:45 16:55
1.17
STWHIP P
WEXIT RAT HOLE DRILLED, PU AND BACKREAM AS
PER OCN #4
START LOW & HIGH VIS PILLS
GEO IS SEEING SAND IN THE SAMPLES
START UP PASSES 1 EACH AT 1 FPM
AS MILLED = 10° ROHS
15° LEFT OF AS MILLED
15° RIGHT OF AS MILLED
Printed 10/24/2016 9:42:16AM "All depths reported in Drillers Depths'
North America - ALASKA - BP Page 10 or 19
Operation Summary Report
Common Well Name: S-113
AFE No
Event Type: RE-ENTER- ONSHORE
(RON)
Start Date: 10/2/2016 End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site. PB S Pad
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
Task Code NPT NPT Depth Phase
Description of Operations
- -
(hr)
- - - (usft)
1655 17:10
0.25
STWHIP P WEXIT
DRY DRIFTS IN BOTH DIRECTIONS WERE
CLEAN
PERFORM 10 MIN DYNAMIC FLOW CHECK TO
POOH
'17:10 19:35
2.42
STWHIP P WEXIT
GOOD FLOW CHECK, POOH
19:35 - 20:10
0.58
STWHIP P WEXIT
MONITOR WELL FOR 10 MINUTES AT BHA:
STATIC
CLOSE EDC, POWER DOWN
INJECTOR OFF: 20:00
GAUGE WINDOW MILL 2.81" GO / 2.80"
NOGO
GAUGE STRING REAMER 2.80" GO / 2.79"
- -
--
- __
NOGO
20:10 - 20:30
0.33
DRILL P PROD1
MAKE UP 2-3/8" DRILLING BHA #7
- PICK UP 2-3/8" LOW SPEED MOTOR (2.48
DEG AKO) AND 2-3/8" COILTRAK TOOLS
MAKE UP 3-1/4" <HUGHES CHRISTENSEN,
TALON> BICENTER BIT
SURFACE TESTED TOOL. GOOD TEST.
PRESSURE TEST QTS TO 300 PSI LOW FOR
5 MINUTES / 3500 PSI HIGH FOR 5 MINUTES
-
- -- - - - - - -
INJECTOR ON: 20:30
20:30 23:30
3.00
- -
DRILL P PROD1
RIH WITH 2-3/8" DRILLING BHA #7 FROM
SURFACE TO 12850' MD
RATE: 1.15 BPM IN, 1.53 BPM OUT. CIRC
PRESSURE: 2120 PSI
MUD WEIGHT: 8.62 PPG IN, 8.57 PPG OUT
MUD ENGINEER TREATING MUD TO GET
CALCIUM DOWN FOR EP MUD LUBE PILL ON
WAY IN HOLE.
- LOG DOWN FOR TIE-IN FROM 12870' TO
12907' MD (FORMATION) WITH -33.5'
CORRECTION
PU 30 KLBS @ 30 FPM, SO 7 KLBS AT 12870'
MD
23:30 00:00
0.50 1
DRILL P PROD1
DRILL 3-1/4" BUILD FROM 13057' MD TO 13074'
FREE SPIN: 4000 PSI, 1.65 BPM
RATE: 1.65 BPM IN, 1.67 BPM OUT. CIRC
PRESSURE: 4000-4200 PSI
- MUD WEIGHT: 8.70 PPG IN, 8.63 PPG OUT,
ECD: 11.65 PPG
ROP: 70 FT/HR, WOB: 2.0-2.5 KLB
10/8/2016 00:00 06:00
6.00
DRILL P PROD1
DRILL 3-1/4" BUILD FROM 13074'
FREE SPIN: 4000 PSI, 1.65 BPM
RATE: 1.65 BPM IN, 1.67 BPM OUT. CIRC
PRESSURE: 4000 - 4200 PSI
MUD WEIGHT: 8.70 PPG IN, 8.63 PPG OUT,
ECD: 11.65 PPG
- ROP: 10-20 FPH. WOB: 2.5- 3.5 KLB
-ROP SLOWED AT 13150' TO 13200'
-ROP INCREASING TO 60 FPH.
FIRST CLEAN SURVEY WAS 13184'
06:00 - 07:20
1.33
DRILL P PROD1
SLOW ROP DRILLING, BIT MIGHT BE WORN
OUT OR BALLED UP, GEO SAYS NO CLAY IN
SAMPLES
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths*
North America - ALASKA - BP
Operation Summary Report
Page 11 of 19
Common Well Name: S-113 AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
Task
Code
NPT
NPT Depth Phase Description of Operations
-
07:20 - 07:50
(hr)
0.50
DRILL
P
(usft)
PROD1 WE ARE DOWN TO -5 FPH, CHECK WITH DD
TO SEE IF WE CAN STILL REACH OUR
OBJECTIVE IF WE PULLAND COME BACK IN
WITH THE LATERAL BHA PULLING 12° DL'S
LOOKS LIKE WE WILL LOOSE -30-40 OF THE
UPPER C3 WITH 12° DLS, TALK TO GEO TO
SEE IF THEY CAN AFFORD TO GIVE UP THAT
MUCH
0.25
DRILL
P
07:50 08:05
PROD1 GEO'SARE GOOD WITH GIVING UP LITTLE
OF THE C3, DYNAMIC FLOW CHECK WELL TO
_IPOOH _
0.33
DRILL
P
08:05 08.25
PROD1 GOOD FLOW CHECK, POOH
08:25 08:30
PROD1 TRIP TO WINDOW IS CLEAN, JOG IN HOLE
0.08
DRILL
P
-
ITHEN PULL THROUGH WINDOW
2.08
DRILL
P
08:30 - 10:35
PROD1 EDC IS OPEN, POOH PUMPING A LOW HIGH
VIS COMBO HALF WAY UP THE TANGENT
ISECTION
HOLD A PJSM TO LD & PU DRILLING BHA'S
0.25
DRILL
P
110:35 10:50
PROD1 FLOW CHECK WELL
110:50 11:10
PROD1 GOOD NO FLOW, TAG UP AND SWAP BHA'S,
0.33
DRILL
P
0.58
DRILL
P
INJECTOR OFF
PROD, TBHA OOH
11:10 11:45
BIT GRADE = 1-2 (2 BROKEN CUTTERS ON
THE WING)
i PROD1 INJECTOR ON, SHALLOW TEST TOOLS, OPEN
11:45 11:55
0.17
DRILL
P
i EDC AND RIH
11:55 14:05
2.17
DRILL
P
PROD1 EDC OPEN RIH
PROD1 LOG TIE IN
14:05 - 14:20
0.25
DRILL
P
PROD1 CORRECT DEPTH -32' AND RIH
PROD1 DRILL LATERAL FROM 13230' MD- 13680'
14:20 14:45
14:45 22:30
0.42
DRILL
P
7.75
DRILL
P
FREE SPIN: 3885 PSI, 1.65 BPM
RATE: 1.654 BPM IN, 1.65 BPM OUT. CIRC
PRESSURE: 3999 PSI
- MUD WEIGHT: 8.72 PPG IN, 8.65 PPG OUT,
ECD: 11.70 PPG
ROP: 46 - 58 FT/HR, WOB: 1.92 - 3.25 KLBS
ALLOW BIT TO START A PATTERN THEN
INCREASE ROP
DD WANTS TO MAINTAIN -3K WOB
DRILLED AHEAD WITH ROP -100 FPH. ECD
CLIMBING ABOVE 12.0 PPG
22:30 00:00 1.50 DRILL P PROD1 PERFORM LONG WIPER TRIP TO WINDOW
FROM 13680'M D TO 11 800'MD
RATE: 1.64 BPM IN, 1.54 BPM OUT. CIRC
PRESSURE: 3900 PSI
OPEN EDC AT WINDOW, WIPE HOLE UP TO
TANGENT SECTION
LOG DOWN FOR TIE-IN RA TAG WITH +07'
CORRECTION.
RIH AT 100' FPM TO INCREASE AVS TO FLUSH
HOLE.
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths`
North America - ALASKA - BP
Operation Summary Report
Page 12 of 19
Common Well Name: S-113
AFE No
Event Type: RE-ENTER- ONSHORE
(RON)
Start Date: 10/2/2016 End Date:
10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:OO:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
Task Code NPT NPT Depth
Phase
Description of Operations
(hr)-
(usft)
10/9/2016 00:00 07:00
7.00
DRILL P
PROD1
DRILL 3.0" LATERAL FROM 13680' MD TO'
13933MD
FREE SPIN: 4000 PSI, 1.58 BPM
RATE: 1.58 BPM IN, 1.58 BPM OUT. CIRC
I PRESSURE: 4000 - 4300 PSI
MUD WEIGHT: 8.81 PPG IN, 8.83 PPG OUT,
ECD: 12.27 PPG
I -ROP IS VERIED. 50-100 FPH. MULTIPLE
WIPERS
UTILIZING 5 BBL LOVIS / 5 BBL HIVIS PILLS
AS NEEDED. CUTTINGS
-BRING PIT 1 INTO CIRCULATION. THIS
HELPED DROP ECDS FOR A LITTLE WHILE.
07:00 07:55
0.92
DRILL P
PROD1
DRILL LATERAL
FREE SPIN: 3920 PSI, 1.57 BPM
RATE: 1.56 BPM IN, 1.56 BPM OUT. CIRC
PRESSURE: 4080 PSI
MUD WEIGHT: 8.80 PPG IN, 8.79 PPG OUT,
ECD: 12.33 PPG - SWAPPING MUD
ROP: 20 FT HR, WOB: 2.8 KLBS
07:55 09:10
1.25
DRILL P
PROD1
SWAP TO NEW MUD
DRILL LATERAL
FREE SPIN: 3920 PSI, 1.57 BPM
RATE: 1.57 BPM IN, 1.56 BPM OUT. CIRC
PRESSURE: 4190 PSI
MUD WEIGHT: 8.82 PPG IN, 8.79 PPG OUT,
ECD: 12.36 PPG - SWAPPING MUD
ROP: 20 FT/HR, WOB: 2.79 KLBS
09:10 10:15
1.08
DRILL P
PROD1
NEW MUD ALL THE WAYAROUND
DRILL LATERAL
FREE SPIN: 3920 PSI, 1.57 BPM
RATE: 1.77 BPM IN, 1.75 BPM OUT. CIRC
PRESSURE: 4204 PSI
MUD WEIGHT: 8.58 PPG IN, 8.59 PPG OUT,
ECD: 11.87 PPG
ROP: 45 FT/HR, WOB: 2.72 KLBS
UNMAPPED FAULT AT 13850', NO LOSSES,
DTW -35', NEED TO COME UP 20' TVD TO
6715'
10:15 11:10
0.92
DRILL P
PROD1
DRILLED 450' WIPE TO THE WINDOW
11:10 12:10
1.00
DRILL P
PROD1
OPEN EDC AND PUMP AT MAX RATE UP TO
11800' PUMPING SWEEPS
12:10 12:20
0.17
DRILL P
PROD1
LOG TIE IN
12:20 12:50
0.50
DRILL P
PROD1
CORRECT DEPTH +20' AND RIH TO BOTTOM
112:50 15:30
2.67
DRILL P
PROD1
BACK ON BOTTOM DRILLING LATERAL
FREE SPIN: 3856 PSI, 1.70 BPM
RATE: 1.70 BPM IN, 1.70 BPM OUT. CIRC
PRESSURE: 3981 PSI
- MUD WEIGHT: 8.58 PPG IN, 8.59 PPG OUT,
ECD: 11.67 PPG
ROP: 30 FT/HR, WOB: 3.81 KLBS
Printed 10/24/2016 9:42:16AM 'All depths reported in Drillers Depths'
Printed 10/24/2016 9:42:16AM `All depths reported in Drillers Depths`
North America - ALASKA - BP
Page 13 of 19
Operation Summary Report
Common Well Name: S-113
AFE No
Event Type: RE-ENTER- ONSHORE
(RON) Start Date: 10/2/2016 End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs Task Code NPT NPT Depth Phase
Description of Operations
-
(hr) (usft)
1530 1830
_
3.00 DRILL P PROD1
CONTINUE DRILLING AHEAD
HAVING TROUBLE KEEPING PIPE MOVING
AFTER TAG, DROP PUMP AND GET WOB,
BRING PUMP UP IT DRILLS
FLUID STRATEGY CALLS FOR STICKLESS
BEADS IF MAINTAINING WOB BECOMES AN
ISSUE
OPEN HP FILTER BYPASS, PUMP 1 CT
VOLUME +20 BBLS TO ENSURE NOTHING
GOT PUMPED DOWN HOLE AND PLUGS OFF
BHA
COIL IS CLEAR, STARTADDING STICKLESS
BEADS AS PER FLUID STRATEGY AT 1 SACK
EVERY 30 MIN.
ONCE CIRCULATION COMPLETE. STILL -10K
SURFACE WEIGHT, HELPED KEEP STEADY
WOB.
18:30 00:00
5.50 DRILL P PROD1
'DRILL 3.0" LATERAL FROM 14200' MD TO
14427'
- FREE SPIN: 4000 PSI, 1.75 BPM
RATE: 1.75 BPM IN, 1.75 BPM OUT. CIRC
PRESSURE: 4000-4200 PSI
MUD WEIGHT: 8.66 PPG IN, 8.61 PPG OUT,
ECD: 11.73 PPG
ROP: 20 FT/HR, WOB: 2.5— 3.5KLBS
ATTEMPTING TO CLIMB UP IN SECTION AT
14385' TO 14410', HAD TO GO O° TOOLFACE
TO CLIMB THROUGH.
DROP RATE AND INCREASE WOB TO HELP
WITH THE CLIMB.
NEAR BIT CLIMBING. BROKE THROUGH.
PREPARE TO WIPER TO SURFACE
10/10/2016 00:00 00:15
0.25 DRILL P PROD1
PERFORM 10 MIN DYNAMIC FLOW CHECK
0.46 BPM IN / 0.41 BPM OUT
PPG IN / 8.64 PPG OUT
00:15 02:40
2.42 DRILL P PROD1
PERFORM LONG WIPER TO SURFACE.
MUD WEIGHT: 8.72 PPG IN, 8.62 PPG OUT
RATE: 2.31 BPM IN, 1.84 BPM OUT
OPEN EDC, POH FROM 13700' MD TO
SURFACE' MD
RATE: 2.31 BPM. CIRC PRESSURE: 4215 PSI
PUMP 5 BBL LOW/ 5 BBL HIVIS PILLS
COMING OFF BOTTOM AND TO SWEEP FROM
3500' OUT.
- NO INCREASE IN CUTTINGS. HOLE
CLEANING LOOKS GOOD.
02:40 03:00
0.33 DRILL P PROD1
MONITOR WELL FOR 10 MINUTES AT BHA:
STATIC
CLOSE EDC, POWER DOWN
INJECTOR OFF: 03:00
- STAND -BACK BHA.
03:00 - 04:30
1.50 BOPSUR P PROD1
PERFORM BOPE WEEKLY FUNCTION TEST
WITH 2" AND 2-3/8" TEST JOINTS
REPLACE PACKOFF / FLOATS. RETEST
300PSI LOW/ 3500 PSI HIGH
Printed 10/24/2016 9:42:16AM `All depths reported in Drillers Depths`
North America - ALASKA - BP
Operation Summary Report
Common Well Name: S-113
AFE No
Page 14 of 19
tvent type: RE-tN I ER- ONSHORE (RON)
Start Date: 10/2/2016 End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad -
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
Task Code NPT NPT Depth
Phase
Description of Operations
(hr)
(usft)
104:30 06:20
1.83
-
DRILL P
PROD1
MU BHA
MAKE UP 2-3/8" DRILLING BHA #9
PICK UP 2-3/8" LOW SPEED MOTOR (0.98
DEG AKO) AND 2-3/8" COILTRAK TOOLS
MAKE UP 3.0"" HYCALOG BICENTER BIT
SURFACE TESTED TOOL. GOOD TEST.
PRESSURE TEST QTS TO 300 PSI LOW FOR
5 MINUTES / 3500 PSI HIGH FOR 5 MINUTES
- INJECTOR ON: 06:00
06:20 - 08:45
2.42
DRILL P
PROD1
BHA MU, RIH
PUMP/TIME EP LUBE PILL WHILE RIH TO
COME OUTAS WE ARE LOGGING OUT TIE IN
GET RIH & PU WT'S
100 FPM @ 0.2 BPM = 6.6K RIH, 37K POH
2.4 FPM @ 0.2 BPM = 6.6 - 9K RIH, 30K POH
08:45 09:55
1.17
DRILL P
PROD1
LOG TIE IN WHILE PUMPING EP LUBE PILL
I OUTAT 1.0 BPM_
09:55 10:20
0.42
DRILL P
_
PROD1
CORRECT DEPTH -31', CONTINUE
CIRCULATING EP LUBE PILL WHILE
_ _
RECIPROCATING PIPE
10:20 - 11:20
1.00
DRILL P
PROD1
WEIGHT CHECKS AFTER EP LUBE
100 FPM @ 0.2 BPM = 6.4K RIH, 37K POH NO
(CHANGE
2.4 FPM @ 0.2 BPM = 6.6 - 9K RIH, 30K POH
NO CHANGE AS WELL
RIH TO CONTINUE DRILLING
11:20 14:40
3.33
DRILL P
PROD1
DRILL LATERAL
FREE SPIN: 4058 PSI, 1.70 BPM
RATE: 1.7 BPM IN, 1.75 BPM OUT. CIRC
PRESSURE: 4204 PSI
MUD WEIGHT: 8.65 PPG IN, 8.59 PPG OUT,
ECD: 11.88 PPG
ROP: 15 FT/HR, WOB: 2.55-2.72 KLBS
ACTS LIKE WE ARE DRILLING A THICK SHALE,
CALL OUT FOR SCREEN CLEAN IN CASE THE
BIT IS BALLED UP
PULLED A SAMPLE FROM THE SHALE AND
GEO SAYS IS MOSTLY SILTSTONE, DRILL
CLOSE TO MAX WOB TO PUSH THROUGH
SHALE
14:40 15:35
0.92
DRILL P
PROD1
LOOKS LIKE WE ARE DRILING OUT OF THE
SHALE, ROP STARTING TO INCREASE
15:35 15:50
0.25
DRILL P
PROD1
DRILLED TO 14500', PUH FOR A SHORT
WIPER TO CLEAR THE OH BEFORE DRILING
IN TO FAULTAREA STARTING AT 14510'
15:50 17:50
2.00
DRILL P
PROD1
BACK ON BOTTOM DRILLING LATERAL
FREE SPIN: 4058 PSI, 1.70 BPM
RATE: 1.72 BPM IN, 1.72 BPM OUT. CIRC
PRESSURE: 4358 PSI
MUD WEIGHT: 8.71 PPG IN, 8.72 PPG OUT,
ECD: 12.16 PPG
ROP: 75 FT/HR, WOB: 2.45 - 2.85 KLBS
-.
-
SURFACE WT -SK TO -12K
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths*
North America - ALASKA - BP
Operation Summary Report
Page 15 of 19
common Well Name: 5-113
AFE No
Event Type: RE-ENTER- ONSHORE
(RON) Start Date: 10/2/2016 End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs Task Code NPT NPT Depth Phase
Description of Operations
(hr) (usft)
17:50 - 22:30
4.67 DRILL P PROD1
DRILLING LATERAL
FREE SPIN: 4058 PSI, 1.70 BPM
RATE: 1.62 BPM IN, 1.62 BPM OUT. CIRC
PRESSURE: 4142 PSI
MUD WEIGHT: 8.71 PPG IN, 8.72 PPG OUT,
ECD: 12.16 PPG
ROP: 50 FT/HR, WOB: 2.45 - 2.85 KLBS
SURFACE WT -5K TO -9k
22:30 00:00
1.50 DRILL P PROD1
DRILL LATERAL. ROP DOWN TO UNDER 10
FPH.
PUMPING 1 PPB BEADS INTO SUCTION PIT.
INCREASING IN ANGLE.
CIRCULATION PRESSURE CLIMBING ABOVE
WHAT WE HAD YESTERDAY ON BEAD.
CIRCULATING PRESSURE AT 4500#, CUT
BEADS. PRESSURES FALLING BACK TO
- _-
-
CLOSE TO WERE THEY WERE.
10/11/2016 00:00 - 01:00
1.00 DRILL N HMAN 14,658.00 PROD1
MUD LOOKING LIKE GREASING OUT. CALL
MUD ENGINEER. STARTED GETTING
PUDDING CONSISTENCY MUD INTO POSSUM
BELLY. CIRCULATION AND WELLHEAD
CLIMBING DO TO PUSHING THROUGH MM.
GO ON BYPASS. PICK OFF BOTTOM AND
PERFORM SHORT WIPER. MONITOR WEIGHT
MANUALLY. AFTER DIVERTING 50 BBLS TO
CUTTINGS BOX. VISCOSITY DROPPED.
BRING FLUID BACK IN. MONITOR MUD
WEIGHT OUT. 8.6 PPG. START TRIP SHEET
AND WIPE TO WINDOWAND GET HANDLE
ON MUD PROBLEM. OPEN EDC AT WINDOW.
COME ON AT A MAX RATE OF 2.0 BPM IN /
OUT 8.70 PPG IN / 8.67 PPG OUT.
01:00 02:00
1.00 DRILL N HMAN 14,658.00 PROD1
OPEN EDC AT WINDOW. COME ON AT A MAX
RATE OF 2.0 BPM IN / OUT
8.70 PPG IN / 8.67 PPG OUT.
CIRCULATE BOTTOMS UP. DISCUSS WITH
ODE AND MUD ENGINEER. MUD NEEDS
SWAP.
START PREPARING FOR MUD SWAP.
02:00 - 03:30
1.50 DRILL N HMAN 14,658.00 PROD1
LOG TIE IN FROM 12850'- 12985'. WITH +15'
CORRECTION.
CLOSE EDC, RIH TO BOTTOM FOR MUD
SWAP.
03:30 05:00
1.50 DRILL N HMAN 14,658.00 PROD1
CIRCULATE NEW MUD TO BIT.
22 BBLS IN. HAD TO BACK RATE DOWN.
CONTINUE TO CIRCULATE NEW MUD
AROUND.
05:00 08:50
3.83 DRILL P PROD1
ESTABLISH PARAMETERS AND CONTINUE TO
DRILL 3.0" LATERAL FROM 14658' MD
FREE SPIN: 3915 PSI, 1.60 BPM
RATE: 1.59 BPM IN, 1.59 BPM OUT. CIRC
PRESSURE: PSI
- MUD WEIGHT: 8.62 PPG IN, 8.58 PPG OUT,
ECD: 11.94 PPG
08:50 12:10
3.33 DRILL P PROD1
DRILL LATERAL
FREE SPIN: 4058 PSI, 1.70 BPM
RATE: 1.60 BPM IN, 1.62 BPM OUT. CIRC
PRESSURE: 4189 PSI
MUD WEIGHT: 8.68 PPG IN, 5.59 PPG OUT,
ECD: 12.11 PPG
ROP: 40-60 FT/HR, WOB: 1.97 KLBS
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths*
North America - ALASKA - BP Page 16 of 19
Operation Summary Report
- ---- -
Common Well Name: 5-113 AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations
(hr) (usft)
12:10 - 12:15 0.08 DRILL P PROD1 DRILL LATERAL
r:15 - 13:15 1.00
- 14:10 r 0.92
14:10 - 14:45 0.58
14:45 - 17:30 2.75
17:30 - 21:00 1 3.50
21:00 - 21:40 1 0.67
1
21:40 00:00 2.33
(FORMATION 34 5' C
FREE SPIN: 4029 PSI, 1.70 BPM
RATE: 1.65 BPM IN, 1.65 BPM OUT. CIRC
'PRESSURE: 4138 PSI
- MUD WEIGHT: 8.68 PPG IN, 5.59 PPG OUT,
�-ROP:
ECD: 12.11 PPG
40 FT/HR, WOB: 2.21 KLB_S
DRILL
P
PF ODJPUMP
A 15 BBL LOW VIS PILL
DRILL P
PROD1
LOW VIS PILL DROPPED THE ECD'S FROM
12.1 TO 11.6 AND ISALLOWIGN US TO DRILL
STOP ADDING LUBES AND START THINNING
MUD BACK TO 26K LSRV 1 PIT AT A TIME
HEN PUMP- -
DRILL
P
PROD1
�-
START LOW LSRV MUD DOWN HOLE, 8.55
PPG
DRILL
P
PROD1
LOW VIS MUD AT THE BIT ECD AT 12.02 PPG.
_
DRILL TO 15,076 FT, DIFFICULT SLIDING.
DRILL
P
PROD1
MONITOR WELL FOR 10 MINUTES WITH
DYNAMIC FLOW CHECK, GOOD.
0.48 / 0.43 BPM IN / OUT.
- MUD WEIGHT: 8.66 PPG IN, 8.64 PPG OUT
RATE: 1.77 BPM IN, 1.62 BPM OUT
OPEN EDC, POH FROM 13,020' MD TO
SURFACE.
RATE: 2.25 BPM. CIRC PRESSURE: 4,090 PSI
PU 25 KLBS ABOVE PILOT HOLE.
KEEP AS DRILLED TF, 0.5 BPM WHILE
+_
PULLING UP THROUGH PILOT HOLE.
DRILL P PROD1
MONITOR WELL FOR 10 MINUTES AT BHA:
STATIC
CLOSE EDC, POWER DOWN
INJECTOR OFF: 21:00
BIT GRADE IS 1-1
MAKE UP 2-3/8" DRILLING BHA#X
1
PICK UP 2-3/8" XTREME MOTOR (0.89 DEG
AKO) AND 2-3/8" COILTRAK TOOLS
MAKE UP REBUILT 2.74 x 3.25" HYC
DURAFORCE BICENTER BIT
- SURFACE TESTED AGITATOR TOOL, GOOD
TEST AT 1.7 BPM
- PRESSURE TEST QTS TO 250 PSI LOW FOR
5 MINUTES / 3800 PSI HIGH FOR 5 MINUTES
- INJECTOR ON: 21:40
_
DRILL P
PROD1
RIH WITH 2-3/8" DRILLING BHA #10 FROM
SURFACE TO 12,860' MD
- RATE: 1.17 BPM IN, 1.53 BPM OUT. CIRC
PRESSURE: 1,990 PSI THROUGH OPEN EDC.
MUD WEIGHT: 8.61 PPG IN, 8.61 PPG OUT
LOG DOWN FOR TIE-IN FROM 12,860' MD
WITH
ORRECTION
10/12/2016 00:00 01:50 1.83 DRILL P PROD1 CONTINUE RIH WITH BHA#10.
01:50 - 04:30 2.67 DRILL P PROD1 DRILL 3.25" LATERAL FROM 15,090' MD
FREE SPIN: 4,150 PSI, 1.58 BPM
RATE:1.58 BPM IN, 1.56 BPM OUT. CIRC
PRESSURE: 4,150 - 4,280 PSI
MUD WEIGHT: 8.68 PPG IN, 8.62 PPG OUT,
ECD: 11.46 PPG
ROP: 10 FT/HR, WOB: 1-2 KLBS
DIFFICULT SLIDING, DRILLING WITH -12 TO
-- - -- 15K STRING WEIGHT.
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths*
North America - ALASKA - BP Page 17 of 19
Operation Summary Report
Common Well Name: 5-113 AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations
(hr) (usft)
04:30 - 04:45 0.25 DRILL P I PROD1 DRILL 3.25" LATERAL FROM 15120' AT 98°
04:45 - 05:00 1 0.25 F DRILL N STUC
05:00 06:25 1.42 DRILL P
06:25 09:00 2.58 DRILL P
09:00 - 10:00 1 1.00 1 DRILL P
100013:15 3.25
13:15 14:30 1.25
-- 14:30 15:25 0.92
15:25 16:10 0.75
DRILL P
DRILL N STUC
DRILL I N I STUC
DRILL N STUC
*All depths reported in Drillers Depths*
FREE SPIN: 4,150 PSI, 1.58 BPM
RATE:1.61 BPM IN, 1.61 BPM OUT. CIRC
PRESSURE: 4193 - 4272 PSI
I- MUD WEIGHT: 8.70 PPG IN, 8.62 PPG OUT,
ECD: 11.59 PPG
ROP: 5 FT/HR, WOB: 1-2 KLBS
DIFFICULT SLIDING, DRILLING WITH -12 TO
-15K STRING WEIGHT
PU'S GETTING STICKY, NEED TO PU A SOON
AS DIFF PRESSURE STARTS COMING OFF 2
PU'S AT 67 & 70K
PROD1
PU AFTER SEEING DIFF PRESSURE DRILLING
OFF
PULLED TO 74KAND WE ARE
DIFFERENTIALLY STUCK
SLACK OFF AND PU, NO MOVEMENT,
HOLDING -72K, NO CHANGE TO WOB SUB,
DIFF STUCKABOVE WOB SENSOR
PUMP 12 BBLS TO CLEAR THE OH OF
CUTTINGS THEN SHUT DOWN THE PUMP
PUMP DOWN, NO CHANGE IN WOB OR
SURFACE WT
RIH TO MAX ALLOWABLE NEGATIVE WEIGHT
TO SEE IF WE GET CHANGE IN WOB
SHOWING 1.28K WOB, PULL TO MAX WEIGHT
PULLED FREE AT 43K
PU 300' FOR A SHORT WIPER
PROD1
BACK ON BOTTOM DRILLING
PROD1
DRILL 3.25" LATERAL FROM 15120' AT 98°
FREE SPIN: 4,150 PSI, 1.58 BPM
RATE:1.61 BPM IN, 1.61 BPM OUT. CIRC
PRESSURE: 4193 - 4272 PSI
- MUD WEIGHT: 8.70 PPG IN, 8.62 PPG OUT,
ECD: 11.59 PPG
ROP: 15 FT/HR, WOB: 1-2 KLBS
DIFFICULT SLIDING, DRILLING WITH -12 TO
PROD1
-15K STRING WEIGHT
DRILL 3.25" LATERAL FROM 15120' AT 98°
FREE SPIN: 4,150 PSI, 1.58 BPM
RATE:1.61 BPM IN, 1.61 BPM OUT. CIRC
PRESSURE: 4193 - 4272 PSI
- MUD WEIGHT: 8.70 PPG IN, 8.62 PPG OUT,
ECD: 11.59 PPG
ROP: 16 FT/HR, WOB: 1-2 KLBS
DIFFICULT SLIDING, DRILLING WITH -12 TO
-15K STRING WEIGHT
PROD1
ADD LUBES TO MUD
STARTING TO SEE MORE HEAVY PU'S,
PROD1
PU AFTER DRILL OFF, CAME UP 60', TURN
AROUND AND WE ARE STUCK
MIX UP 30 BBLS OF 3% KCL AND PREP TO
PUMP MINERAL OIL
-
PROD1
PUMP 15 BBLS OF KCL, 20 BBLS MINERAL
OIL, 15 BBLS OF KCL
PROD1
10 BBLS OUT, ALLOW TO SOAK
PU AND PULLED FREE AT 36K, PU AND CIRC
OUT THE REST OF THE MINERAL OILAND
KCL TEHN GO BACK TO DRILLING
*All depths reported in Drillers Depths*
North America - ALASKA - BP
Operation Summary Report
Page 18 of 19
Common Well Name: 5-113
WAIT FOR 170 BBLS 3% SLICK KCL AND 290
AFE No
Event Type: RE-ENTER- ONSHORE (RON)
Start Date: 10/2/2016
End Date: 10/14/2016
X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay
Site: PB S Pad
PER OCN #6.
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
BOTTOM WITH CT. CIRCULATE OLD MUD OUT
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
KCL, TIME IT SO IT EXITS THE BIT JUST
Date From - To Hrs
Task Code NPT
NPT Depth Phase
Description of Operations
- - - - - (hr)
-
(usft)
16:10 16:25 0.25
DRILL N FLUID
15,300.00 PROD1
BACK ON BOTTOM DRILLING
16:25 - 17:30 1.08
DRILL N FLUID
15,300.00 PROD1
PU OFF BOTTOM CIRC PRESSURE AND ECD
IS CLIMBING, MUD MIGHT BE GREASED OUT
FROM THE MINERAL OIL
'CONTINUE POOH HAVING TO REDUCE OUR
RATE TO KEEP THE ECD'S LOW
17:30 - 19:00 1.50 DRILL N FLUID 15,300.00 PROD1 ABOVE THE WINDOW
I VERY THICK SLUG CAME OUT OF THE WELL
'ORDER OUT FLUIDS TO CLEAN UP WELL
BEFORE SWAPPING TO NEW MUD AND
CONTINUE DRILLING
TIE-IN DEPTH, CORRECT+32 FT.
19:00 - 00:00 5.00 DRILL I N FLUID 15,300.00 PROD1
WAIT FOR 170 BBLS 3% SLICK KCL AND 290
BBLS 1% KCL TO CLEAN OUT OLD MUD AND
PERFORM MUD SWAP.
FLUIDS ARRIVE BY 23:00. PUT 3% IN PIT #2
AND ORGANIZE FLUID TRUCKS TO PUMPAS
PER OCN #6.
10/13/2016 00:00 - 02:00 2.00 DRILL N FLUID 15,300.00 PROD1
CONDUCT PJSM FOR PUMPING MUD
DISPLACEMENT. CLOSE EDC AND RIH TO
BOTTOM WITH CT. CIRCULATE OLD MUD OUT
'OF WELL AS PER OCN #6. PUMP 150 BBLS 3%
KCL, TIME IT SO IT EXITS THE BIT JUST
PRIOR TO TAGGING BOTTOM. TAG BOTTOM
AT 15,321 FT.
02:00 06:20 4.33 DRILL N FLUID 15,300.00 F PROD1
PULL BACK TO WINDOW, PUMP 140 BBLS 3%
KCL AT 1.45 BPM / 2,725 PSI. PULL UP TO
12,000 FT, PUMP 290 BBLS 1% KCL WITH
BARACLEAN ADDED. TAKE KCL RETURNS TO
TIGER TANK.
06:20 - 07:45 1.42 DRILL N FLUID 15,300.00 PROD1
13% KCLAT THE BIT, CALL OD AND DISCUSS
RIH TO BOTTOM SINCE WE HAVE THE SAME
FLUID AT THE BIT THAT IS IN THE HOLE TO TD
AND SWAP THE WELL TO NEW MUD AT TD.
THIS WOULD REDUCE THE AMOUNT OF
STAIGHT 3% KCL THAT WOULD BE ADDED TO
THE SYSTEM. ODE AGREES, RIH TO FINISH
DISPLACEMENT ON BOTTOM
07:45 08:25 0.67 DRILL N FLUID 15,300.00 PROD1
TAG TD, PUMP 15 BBLS OF MUD OUT THEN
_
CONTINUE DRILLING
08:25 08:35 0.17 DRILL N FLUID 15,300.00 PROD1
DRILLED 9' WITH A SEVERAL PU'S AND WE
ARE DIFFERENTIALLY STUCK SHUT DOWN
THE PUMP AND ALLOW THE WELLBORE TO
_
RELAX FOR 10 -MIN
08:35 09:15 0.67 DRILL N FLUID 15,300.00 PROD1
PULLED FREE, CALL ODE AND DISCUSS
FLUIDS, DO NOT WANT TO ADD THE LAST 1%
LUBES, IF WE GIT STUCKAND PUMP
MINERAL OIL IT COULD GREASE OUTAGAIN
09:15 10:20 1.08 DRILL N FLUID 15,300.00 PROD1
_
STARTADDING BEADS TO THE MUD THEN
PUMP
10:20 10:50 0.50 DRILL P PROD1
10 BBLS OF MUD WITH BEADS OUT ATTEMPT
TO GO BACK TO DRILLING DRILL 3.25"
j
LATERAL FROM 15330' AT 93° - FREE SPIN:
4200 PSI, 1.66 BPM - RATEA.66 BPM IN, 1.66
BPM OUT. CIRC PRESSURE: 4548 PSI - MUD
WEIGHT: 8.65 PPG IN, 8.58 PPG OUT, ECD:
11.12 PPG-- ROP: 25 FT/HR, WOB: 1.73 KLBS
Printed 10/24/2016 9:42:16AM *All depths reported in Drillers Depths*
North America - ALASKA - BP
Operation Summary Report
Page 19 of 19
Common Well Name: S-113 AFE No
Event Type: RE-ENTER- ONSHORE (RON) Start Date: 10/2/2016 End Date: 10/14/2016 X3-017VQ-C: (2,843,222.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations
(hr) (usft)
10:50 - 12:00 1.17 DRILL N STUC PROD1 15350 - STUCK, SHUT DOWN PUMP WO
DIFFERENT FLUID STRATEGY FOR SPACERS
AND MINERAL OIL PILLS
12:00 - 12:20 0.33 DRILL P PROD1 TD CALLED SHUT DOWN PUMP AND RELAX
FORMATION FOR 20 MIN
12:20 - 13:45 1.42 DRILL P PROD1 ATTEMPT TO PULL FREE NO MOVEMENT
RECEIVED SPACER FLUID DESIGN FROM
_ TOWN LOAD PIT 4 AND MIX SPACER PILLS
13:45 - 14:45 1.00 DRILL P PROD1 PUMP 20 BBLS OF SPACER, 20 BBLS OF
MINERAL OIL, 20 BBLS SPACER AND CHASE
WITH MUD
14:45 15:20 0.58 DRILL P PROD1 10 BBLS OF MINERAL OIL IN PLACE ALLOW
Printed 10/24/2016 9:42:16AM `All depths reported in Drillers Depths'
TO SOAK PU TO MAX WEIGHT NO
MOVEMENT, SLACK OFF AND A LLOW TO
SOAK LITTLE LONGER
15:20 15:40 0.33 DRILL
P
PROD1
5 ATTEMPTS TO PULL MAX WEIGHT AND WE
j
ARE STILL STUCK, PUMP 5 MORE BBLS OF
MINERAL OIL OUT
15:40 15:50 0.17 DRILL
P
PROD1
PU AND PULLED FREE, STAY CLOSE TO
BOTTOM AND CIRC OUT ALL THE MINERAL
OILAND KCL
,15:50 - 17:40 1.83 DRILL
P
PROD1
ALL MINERAL OILAND KCL OUT, WIPER TO
WINDOW
17:40 17:50 0.17 DRILL
P
PROD1
BELOW THE WINDOW, JOG IN HOLE 100'
17:50 - 19:30 1.67 DRILL
P
PROD1
PULL THROUGH WINDOWAND OPEN THE
EDC PUH TO 12000' AND CIRC A BOTTOMS UP
UNTIL CLEAN AS PER WELL PLAN
19:30 20:50 1.33 DRILL
P
PROD1
RETURNS HAVE CLEANED UP. LOG TIE-IN,
CORRECT+31 FT. RIH TO BOTTOM, CLEAN
PASS. DISCUSS WITH ODE, DECIDE NOT TO
MAKE A SECOND WIPER TRIP BASED ON
VERY CLEAN PASS TO BOTTOM. TAG AT
15,368', CORRECTED DRILLED DEPTH.
20:50 - 00:00 3.17 DRILL
P
PROD1
DYNAMIC FLOW CHECK FOR 10 MIN, GOOD.
j
0.52 BPM IN / 0.46 BPM OUT WITH 5 FT/MIN
POOH SPEED. MUD WEIGHT: 8.57 PPG IN,
8.58 PPG OUT. POOH TO WINDOW, LAY IN
BEAD PILL WHILE POOH. CLEAN PASS UP.
PULL THROUGH WINDOWAND OPEN EDC.
JET WHIPSTOCK THEN PULL UP ABOVE
PILOT HOLE, SWAP WELLABOVE PILOT HOLE
OVER TO 3% KCL WITH INHIBITOR. POOH,
PUMP 2.3 BPM PSI.
.FLAG PIPE WHILEEPO POOH.
10/14/2016 00:00 - 03:00 3.00 DRILL
P
PROD1
CONTINUE POOH AFTER TD WELLAND
CONDITIONING HOLE FOR LINER.
MONITOR WELL FOR 10 MINUTES AT BHA:
STATIC
CLOSE EDC, POWER DOWN
INJECTOR OFF: 02:20
BIT GRADE 1-2
ALL FURTHER ENTRIES FOR TODAY ON
CON REPORT.
Printed 10/24/2016 9:42:16AM `All depths reported in Drillers Depths'
North America - ALASKA - BP Page 1 of 3
Operation Summary Report
Common Well Name: S-113 AFE No
Event Type: COM- ONSHORE (CON) Start Date: 10/14/2016 End Date: 10/16/2016 IX3-017VQ-C: (1,979,871.00 )
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date
10/14/2016
From - To
3:00 04:20
t
Hrs
(hr)
1.33
0.67
Task
CASING
CASING
Code NPT
P
P j
NPT Depth
(usft)
Phase
RUNPRD
RUNPRD
Description of Operations
REMOVE BHI UQC.
PUMP 225 FT OF EXCESS CABLE SLACK OUT
AND CUT IT OFF.
INSTALL BOOT ON THE E -LINE.
INSTALL CT CONNECTOR, PULL TEST TO 35K
AND PRESSURE TEST 250 / 3800 PSI IS
GOOD.
PUMP 3/4" DRIFT BALLAROUND, AND
04:20 - 05:00
RECOVER.
05:00
07:00
2.00
CASING
P
RUNPRD
SET INJECTOR ON LEGS.
RIG UP FARR TONGS.
PREP RIG FLOOR FOR RUNNING LINER.
WALK THROUGH PIPE TALLY WITH DRILLER,
BTT & WSL _
07:00
07:20
0.33
CASING
P
RUNPRD
PJSM TO MU LINER
07:20
12:00
4.67
CASING
P
RUNPRD
I MU LINER AS PER PLAN & SUMMARY
12:00
13:30
1.50
CASING
P
_
RUNPRD
RIH WITH LINER
13:30
- 13:50 1
0.33
CASING
P
RUNPRD
WT CHECKABOVE TOC
PU WT = 37K, RIH WT = 10K
'CIRC OUT 11 BBLS OF KCL IN HE LINER WITH
I MUD FOR LOGGING RUN
13:50
14:35
0.75
CASING
P
_
RUNPRD
'STOP AT 10200 EOP FLAG AND CORRECT
-43.75'
FLAG = 10200', BHA = 2726.4'= 12926.4'
ELEC DEPTH = 12970.17'- 12926.42 = MINUS
43.75' CORRECTION TO 12926.4'
RIH TO LAND LINER ON BOTTOM
14:35
14:50
0.25
CASING
P
RUNPRD
TAG AT 15290, PU AND WORK DOWN
14:50
15:10
0.33
CASING
P
-RUNPRD
TAGGING AT 15354' WITH SOLID TAGS
ROLL PUMP WHILE IN COMPRESSION
SHUT DOWN PUMP, PU AND PUMP WHILE GS
IS IN TENSION
SHUT DOWN PUMP AND RIH
STACKED OUT, WAIT FOR OUT RATE TO
DROP OFF
RIH AND TAGGED AGAIN AT 15354', TRY
WORKING DOWN
15:10
15:20
0.17
CASING
P
RUNPRD
NOT GETTING ANY DEEPER -10-14'
SHALLOW, CALL ODE
15:20
15:30
0.17
CASING
P
RUNPRD
ODE IS GOOD WITH THIS DEPTH
PUMP OFF AND FLOW CHECK WELL
15:30
15:40
0.17
CASING
P
RUNPRD
FLOW CHECK WELL
15:40
18:00
2.33
CASING
P
RUNPRD
GOOD NO FLOW, POOH
17:00 HOLDA PJSM TO LD THE LINER
RUNNING BHA
MONITOR WELL FOR 10 MIN AT BHA, STATIC.
LAY DOWN LINER RUNNING TOOLS AND 6
JTS OF CSH.
TOOLS LOOK NORMAL.
Printed 10/24/2016 9:42:57AM 'All depths reported in Drillers Depths"
North America - ALASKA - BP
Page 2 of 3
Operation Summary Report
Common Well Name: S-113
AFE No
Event Type: COM- ONSHORE (CON) Start Date: 10/14/2016 End Date: 10/16/2016
X3-017VQ-C: (1,979,871.00)
Project: Prudhoe Bay Site: PB S Pad
Rig Name/No.: NORDIC 2 Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
_ _
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
(hr)
Task Code NPT NPT Depth Phase
(usft)
Description of Operations
18:00 - 00:00
6.00
EVAL P RUNPRD
PJSM FOR MAKING UP LOGGING BHA.
MAKE UP RPM LOGGING BHAAS PER BHA
#12.
RATTLE 1" CSH WITH BRASS HAMMER AS IT
IS PICKED UP.
CIRCULATE THROUGH CSH AFTER 30,60 AND
86 JTS ARE PICKED UP.
_
CONDUCT KICK WHILE TRIPPING DRILL WITH
O_RLOFF'S CREW, AND AAR AFTERWARDS.
I
10/15/2016 00:00 03:30
3.50
EVALRUNPRD
—RIH WITH LOGGING BHA #12 FROM 2950'M D
TO 12,500' MD
i
RATE: 0.55 BPM IN, 0.60 BPM OUT. CIRC
PRESSURE 1670 PSI
MUD WEIGHT: 8.57 PPG IN, 8.59 PPG OUT
- -
LOG DOWN FROM 12,550' AT 30 FT/MIN.
LIGHT TAG AT 15,395' UNCORRECTED.
03:30 06:40
3.17
EVAL p RUNPRD
LOG UP AT 20 FT/MIN
06:40 07.00
0.33
EVAL P RUNPRD
END LOGGING RUN, FLOW CHECK WELL
07:00 08:35
1.58 EVAL
PRU
NPR D
GOOD NO FLOW, POOH
08:3508:500.25 EVAL P RUNPRD
FLOW CHECKAT SURFACE
- -- -
08:50 - 13:10 4.33 EVAL P RUNPRD
-
GOOD NO FLOW, TAG UP, REMOVE THE
INJECTOR AND LD THE UPPER BHA AND ALL
'THE CSH SIDEWAYS
HOLD A PJSM MEETING AT THE MARKER
JOINT TO PULL THE LAST 10 JOINTS TO GET
TO THE TOOLS. TOOL HAS BEEN SHUT
DOWN SINCE 08:21 AND ONLY REQUIRES 30
MIN TO COOL DOWN. THE BAKER ATLAS
ENGINEER HAS A GEIGER COUNTER TO
_._.�
13:10 14:00 0.83 EVAL P RUNPRD
DETECT IF THE TOOL IS STILL HOT
TOOL AT SURFACE AND NO READING ON
GEIGER COUNTER, LD TOOLS AND CHECK
FOR DATA
HOLD A PJSM TO PREP FOR NOZZLE RUN
CUT EXCESS WIRE AND RESEAL
14:00 14:30 0.50 EVAL P RUNPRD
GOOD DATA, MU NOZZLE BHA AND STAB ON
14:30 15:00 0.50 WHSUR P POST
RIH TO FREEZE PROTECT WELL
PUMP 35 BBLS OF DIESELAND 10 BBLS OF
METHANOL INTO THE REEL WHILE RIH TO
3300' MD / 2500' TVD
PT N2 LINE FOR REEL BLOW DOWN TO 250
LOWAND 4500 HIGH
GOOD PT, HOLD 150OPSI ON THE LINE
15:00 16:05 1.08 RIGD—� P POST
TAGGED UP, SERVIE TREE VALVES
_
16:05 16:15 0.17 RIGID POST
-TT THE MASTER &SWAB VALVES WITH
NEAT METHANOL TO 3500 PSI
16:15 16:35 0.33 RIGID P POST
GOOD LTT, HOLD PRESSURE AND HOLD A
PJSM TO PUMP N2
16:35 17:20 0.75 i RIGIDP POST
PUMP INHIBITED WATER AND METHANOL
17:20 18:00 0.67 RIGID POST
SHUTDOWN N2 AND ALLOW TO BLEED OFF
18:00 20:00 2.00 RIGID P POST
PJSM WITH SLB AND NORDIC FOR RIGGING
DOWN CT.
LIFT INJECTOR, REMOVE CT CONNECTOR.
INSTALL GRAPPLE AND PULL TEST.
PULL CT BACK TO REEL HOUSE, SECURE IT
WITH SHIPPING BAR.
Printed 10/24/2016 9:42:57AM *All depths reported in Drillers Depths*
North America - ALASKA - BP
Operation Summary Report
Page 3 of 3
Common Well Name: 5-113
AFE No
Event Type: COM- ONSHORE (CON)
Start Date: 10/14/2016 End Date: 10/16/2016
X3-017VQ-C: (1,979,871,00)
Project: Prudhoe Bay
Site: PB S Pad —
Rig Name/No.: NORDIC 2
Spud Date/Time: 6/17/2002 12:00:OOAM
Rig Release: 10/16/2016
Rig Contractor: NORDIC CALISTA
UWI: 500292309400
Active datum: Kelly Bushing / Rotary Table @70.33usft (above Mean Sea Level)
Date From - To
Hrs
Task Code NPT NPT Depth
Phase
Description of Operations
(hr)
(usft)
20:00 23:00
3.00
RIGID P
POST
PREP TO LOWER REEL DOWN.
REMOVE 1502 LINE FROM INSIDE REEL.
REMOVE GOOSENECKAND CT STRIPPER.
SIMOPS: OPEN BOP DOORS TO INSPECT
CAVITES AND CHANGE RAMS.
TRACTION INCIDENT #2016 -IR -5354848:
DRILLER OPENED THE DRAIN VALVE ON THE
MUD GAS SEPARATOR THINKING IT WAS
LINED UP TO THE PITS AS NORMAL.
HOWEVER THE LINE FROM THE DRAIN
TROUGH TO THE CUTTINGS BOX WAS OPEN,
ALLOWING FLUID FROM THE MGS TO GO
DOWN THE CHUTE TO THE CUTTINGS BOX,
WHICH HAD BEEN PULLED AWAY EARLIER.
AROUND 40 GAL OF FRESH WATER THAT
WAS IN THE MGS WENT DOWN THE
'CUTTINGS BOX CHUTE ONTO THE PAD.
NOTIFICATIONS MADE TO PAD OP, X5700,
AND WELL OPS SPECIALIST (ALSO HAS WELL
--
—_
- —
SUPT DUTY).
23:00 00:00
1.00
RIGID P
POST
PJSM WITH CH2, NORDIC AND SLB FOR
LOWERING REEL DOWN.
LOWER REEL DOWN ONTO TRAILER AND
SECURE IT IN PLACE.
10/16/2016 00:00 09:00
9.00
RIGD P
POST
CONTINUE RIGGING DOWN.
I
OPEN BOP DOORS INSPECT CAVITES
CHANGE RAMS OUT TO 2-3/8"
CONFIGURATION.
'BUTTON DOORS BACK UP.
START ROLLING TIRES, WARM UP DRIVE
,SYSTEM.
INSTALL TREE CAP AND TEST.
RIG RELEASED AT 09.00.
Printed 10/24/2016 9:42:57AM `All depths reported in Drillers Depths`
n b
kow
p
North America - ALASKA - BP
Prudhoe Bay
PB S Pad
S-113
S-113BL1
500292309460
Design: S-113BL1
Final Survey Report
17 October, 2016
F PF-_
BAKER
HUGHES
BP rel .s
Final Survey Report BAKER
HUGHES
Local Co-ordinate Reference: Well 5-113
TVD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference: True
Survey Calculation Method: Minimum Curvature
Database: EDM R5K-Alaska PROD -ANCP1
Project Prudhoe Bay, GPB, PRUDHOE BAY
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 • Using geodetic scale factor
Site PB S Pad, TR -12-12
Site Position:
From: Map
Position Uncertainty: 0.00 usft
Well 5-113
Northing:
5,980,854.540 usft
:,,.,,;
bp
p
Easting:
617,919.920 usft
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
S-113
Wellbore:
S-113BL1
Design:
S-113BL1
BP rel .s
Final Survey Report BAKER
HUGHES
Local Co-ordinate Reference: Well 5-113
TVD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference: True
Survey Calculation Method: Minimum Curvature
Database: EDM R5K-Alaska PROD -ANCP1
Project Prudhoe Bay, GPB, PRUDHOE BAY
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 • Using geodetic scale factor
Site PB S Pad, TR -12-12
Site Position:
From: Map
Position Uncertainty: 0.00 usft
Well 5-113
Northing:
5,980,854.540 usft
Latitude:
70° 21'23.002 N
Easting:
617,919.920 usft
Longitude:
1490 2'32.343 W
Slot Radius:
0.000 in
Grid Convergence:
0.90 °
Well Position
+NI -S 0.00 usft
Northing:
5,980,744.910 usft Latitude:
+E/ -W 0.00 usft
Easting:
618,930.630 usft Longitude:
Position Uncertainty
0.00 usft
Wellhead
Elevation:
37.48 usft Ground Level:
Wellbore
S-113BL1
Magnetics
Model Name Sample Date
Declination
Dip Angle Field Strength
(nT)
BGGM2016 10/1/2016
18.18
81.02 57,562
Design
S-113BL1
—
—
Audit Notes:
Version:
Phase:
ACTUAL
Tie On Depth: 12,989.77
Vertical Section:
Depth From (TVD)
+N/ -S
+EI -W
Direction
(usft)
(usft)
(usft)
(I
32.85
0.00
0.00
240.00
70° 21'21.767 N
149° 2'2.849 W
35.96 usft
10/17/2016 11.32:24AM Paye 2 COMPASS 5000.1 Build 818
e16 by
Date 10/17/2016
From
To
Company:
NorthAmerica- ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
5-113
Wellbore:
5-113BL1
Design:
S-113BL1
Survey Program
Date 10/17/2016
From
To
(usft)
(usft) Survey (Wellbore)
132.00
861.10 S-113 Gyro (S-113)
940.96
9,659.25 S-113 IIFR (S-113)
9,700.00
12,989.77 5-113B IIFR (S -113B)
13,039.00
15,325.85 BHI CTK MWD 3" (S-113BL1)
BP
//.Fag
Final Survey Report
BAKER
HUGHES
Local Coordinate Reference:
Well S-113
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K-Alaska PROD -ANCP1
Tool Name Description
CB -GYRO -SS Camera based gyro single shots
MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal
MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal
MWD MWD - Standard
Survey
MD
Inc
Azi (azimuth)
TVD
TVDSS
NIS
EM
Northing
Easting
DLeg
V. Sec
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°I100usft)
(usft)
32.85
0.00
0.00
32.85
-37.48
0.00
0.00
5,980,744.910
618,930.630
0.00
0.00
115.00
0.62
78.00
115.00
44.67
0.09
0.44
5,980,745.009
618,931.064
0.76
-0.42
CONDUCTOR 1
132.00
0.75
78.00
132.00
61.67
0.13
0.63
5,980,745.055
618,931.262
0.76
-0.62
221.00
0.80
45.00
220.99
150.66
0.70
1.64
5,980,745.631
618,932.262
0.50
-1.77
311.00
1.15
348.00
310.98
240.65
2.02
1.90
5,980,746.963
618,932.498
1.09
-2.66
402.00
2.30
298.00
401.94
331.61
3.77
0.10
5,980,748.684
618,930.668
1.97
-1.97
491.00
4.25
280.00
490.79
420.46
5.18
-4.73
5,980,750.019
618,925.822
2.45
1.50
580.00
5.10
262.00
579.50
509.17
5.21
-11.89
5,980,749.927
618,918.657
1.89
7.70
668.00
7.75
264.00
666.94
596.61
4.04
-21.67
5,980,748.607
618,908.902
3.02
16.74
765.00
11.50
267.50
762.56
692.23
2.94
-37.84
5,980,747.245
618,892.752
3.91
31.30
861.00
14.00
274.00
856.19
785.86
3.33
-58.99
5,980,747.302
618,871.602
3.00
49.42
940.96
15.61
289.24
933.52
863.19
7.55
-78.80
5,980,751.208
618,851.724
5.25
64.47
988.88
16.10
292.69
979.62
909.29
12.24
-91.02
5,980,755.701
618,839.434
2.22
72.71
1,085.76
20.09
292.69
1,071.69
1,001.36
23.84
-118.78
5,980,766.863
618,811.500
4.12
90.94
1,181.45
22.13
291.42
1,160.95
1,090.62
36.77
-150.72
5,980,779.276
618,779.357
2.18
112.15
1,276.95
23.60
289.38
1,248.95
1,178.62
49.68
-185.50
5,980,791.635
618,744.378
1.75
135.81
1,370.92
26.02
288.95
1,334.24
1,263.91
62.62
-222.75
5,980,803.978
618,706.936
2.58
161.60
1,464.24
27.86
287.15
1,417.43
1,347.10
75.70
-262.95
5,980,816.416
618,666.537
2.16
189.87
1,559.68
33.97
285.55
1,499.27
1,428.94
89.43
-309.99
5,980,829.403
618,619.287
6.46
223.74
10/17/2016 11:32:24AM
Page 3
COMPASS
5000.1 Build 81B
by
BP
••
ihNra
Final
Survey
Report
BAKER
HUGHES
Company:
North America
- ALASKA- BP
Local Co-ordinate Reference:
Well S-113
Project:
Prudhoe Bay
ND Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site:
PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well:
S-113
North Reference:
True
Wellbore:
5-113BL1
Survey Calculation Method:
Minimum Curvature
Design:
S-113BL1
Database:
EDM R5K-Alaska PROD -ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
E/W
Northing
Easting
DLeg
V. Sec
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°I100usft)
(usft)
1,655.51
34.81
285.36
1,578.35
1,508.02
103.86
-362.16
5,980,842.994
618,566.900
0.88
261.71
1,751.03
37.45
286.17
1,655.50
1,585.17
119.17
-416.35
5,980,857.443
618,512.475
2.81
300.991
1,847.41
42.52
286.69
1,729.32
1,658.99
136.69
-475.73
5,980,874.022
618,452.830
5.27
343.65
1,942.24
46.44
284.52
1,796.97
1,726.64
154.52
-539.72
5,980,890.829
618,388.574
4.43
390.151
2,038.60
48.17
284.33
1,862.31
1,791.98
172.16
-608.30
5,980,907.377
618,319.722
1.80
440.73
2,134.30
47.58
283.24
1,926.50
1,856.17
189.07
-677.23
5,980,923.194
618,250.536
1.05
491.97
2,230.37
48.77
283.64
1,990.56
1,920.23
205.72
-746.86
5,980,938.727
618,180.659
1.28
543.94
2,326.76
53.15
284.32
2,051.26
1,980.93
223.81
-819.49
5,980,955.665
618,107.760
4.58
597.79
2,422.29
54.73
281.24
2,107.50
2,037.17
240.87
-894.79
5,980,971.525
618,032.204
3.09
654.48
2,517.53
57.26
280.62
2,160.76
2,090.43
255.83
-972.30
5,980,985.254
617,954.468
2.71
714.12
2,614.39
59.87
279.99
2,211.27
2,140.94
270.61
-1,053.61
5,980,998.736
617,872.946
2.75
777.15
2,709.51
59.84
280.61
2,259.04
2,188.71
285.32
-1,134.54
5,981,012.156
617,791.800
0.56
839.88
2,806.36
59.13
279.36
2,308.22
2,237.89
299.79
-1,216.71
5,981,025.318
617,709.419
1.33
903.81
2,902.53
61.53
278.79
2,355.82
2,285.49
312.96
-1,299.22
5,981,037.179
617,626.718
2.55
968.67
2,998.20
62.26
278.81
2,400.89
2,330.56
325.87
-1,382.61
5,981,048.763
617,543.135
0.76
1,034.44
3,093.95
63.05
280.19
2,444.87
2,374.54
339.91
-1,466.49
5,981,061.469
617,459.050
1.52
1,100.06
3,189.79
62.48
283.43
2,488.74
2,418.41
357.34
-1,549.89
5,981,077.573
617,375.394
3.06
1,163.57
3,285.73
64.58
283.81
2,531.51
2,461.18
377.57
-1,633.35
5,981,096.469
617,291.629
2.22
1,225.74
3,381.29
70.71
285.36
2,567.84
2,497.51
399.84
-1,718.83
5,981,117.376
617,205.814
6.59
1,288.63
3,477.49
71.30
285.44
2,599.15
2,528.82
423.99
-1,806.52
5,981,140.134
617,117.754
0.62
1,352.50
3,572.56
69.33
284.38
2,631.17
2,560.84
447.03
-1,893.02
5,981,161.792
617,030.913
2.32
1,415.89
3,668.70
68.95
284.82
2,665.40
2,595.07
469.67
-1,979.95
5,981,183.052
616,943.635
0.58
1,479.86
3,764.47
68.23
285.09
2,700.36
2,630.03
492.68
-2,066.10
5,981,204.688
616,857.147
0.80
1,542.95
3,859.53
67.76
285.13
2,735.98
2,665.65
515.65
-2,151.18
5,981,226.306
616,771.713
0.50
1,605.15
3,956.90
66.63
285.52
2,773.72
2,703.39
539.38
-2,237.75
5,981,248.648
616,684.789
1.22
1,668.26
4,051.70
67.85
283.58
2,810.40
2,740.07
561.33
-2,322.36
5,981,269.254
616,599.848
2.28
1,730.56
4,148.03
68.11
283.76
2,846.52
2,776.19
582.43
-2,409.13
5,981,288.977
616,512.758
0.32
1,795.15
10/1712016
11:32:24AM
Page 4
COMPASS 5000.1 Build 818
0"'w
by
BF
rias
;NI
Final
Survey Report
BAKER
HUGHES
Company: North America
- ALASKA - BP
Local Co-ordinate
Reference:
Well 5-113
Project: Prudhoe Bay
ND Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site: PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well: 5-113
North Reference:
True
Wellbore: S-113BL1
Survey Calculation
Method:
Minimum Curvature
Design: S-113BL1
Database:
EDM R5K-Alaska PROD -ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
E/W
Northing
Easting
DLeg
V. Sec
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
4,243.82
67.48
284.36
2,882.72
2,812.39
603.98
-2,495.16
5,981,309.151
616,426.406
0.88
1,858.68
4,340.11
67.95
282.74
2,919.23
2,848.90
624.85
-2,581.77
5,981,328.643
616,339.478
1.63
1,923.46
4,435.63
67.74
282.44
2,955.26
2,884.93
644.13
-2,668.11
5,981,346.552
616,252.850
0.36
1,988.59
4,531.09
66.50
282.37
2,992.37
2,922.04
663.03
-2,754.01
5,981,364.078
616,166.674
1.30
2,053.53
4,626.85
68.27
282.91
3,029.19
2,956.86
682.37
-2,840.26
5,981,382.050
616,080.135
1.92
2,118.55
4,721.47
69.26
283.41
3,063.46
2,993.13
702.45
-2,926.14
5,981,400.763
615,993.956
1.16
2,182.88
4,817.23
69.17
283.00
3,097.44
3,027.11
722.90
-3,013.30
5,981,419.826
615,906.490
0.41
2,248.14
4,912.74
69.60
283.28
3,131.07
3,060.74
743.23
-3,100.35
5,981,438.762
615,819.132
0.53
2,313.37
5,009.47
69.97
283.29
3,164.50
3,094.17
764.09
-3,188.69
5,981,458.214
615,730.477
0.38
2,379.45
5,104.21
69.32
283.10
3,197.45
3,127.12
784.36
-3,275.17
5,981,477.113
615,643.695
0.71
2,444.20
5,200.01
68.73
283.36
3,231.74
3,161.41
804.83
-3,362.25
5,981,496.198
615,556.311
0.67
2,509.38
5,295.57
68.51
283.40
3,266.58
3,196.25
825.42
-3,448.82
5,981,515.411
615,469.434
0.23
2,574.05
5,392.13
68.56
283.25
3,301.91
3,231.58
846.14
-3,536.26
5,981,534.729
615,381.680
0.15
2,639.42
5,487.61
69.52
284.36
3,336.07
3,265.74
867.41
-3,622.84
5,981,554.628
615,294.777
1.48
2,703.77
5,531.40
69.73
284.84
3,351.32
3,280.99
877.76
-3,662.57
5,981,564.343
615,254.897
1.13
2,733.00
5,587.19
69.06
284.22
3,370.95
3,300.62
890.86
-3,713.12
5,981,576.639
615,204.149
1.59
2,770.22
SURFACE CASING
5,611.20
68.77
283.95
3,379.59
3,309.26
896.31
-3,734.85
5,981,581.745
615,182.338
1.59
2,786.32
5,707.34
67.42
283.08
3,415.45
3,345.12
917.16
-3,821.57
5,961,601.212
615,095.301
1.64
2,851.00
5,801.99
67.80
284.52
3,451.51
3,381.18
938.04
-3,906.56
5,981,620.734
615,010.002
1.46
2,914.16
5,899.34
67.64
285.11
3,488.42
3,418.09
961.07
-3,993.64
5,981,642.380
614,922.568
0.58
2,978.06
5,994.17
67.33
284.71
3,524.73
3,454.40
983.61
-4,078.30
5,981,663.572
614,837.575
0.51
3,040.10
6,090.54
67.27
284.03
3,561.92
3,491.59
1,005.68
-4,164.42
5,981,684.265
614,751.120
0.65
3,103.65
6,185.79
67.40
283.29
3,598.63
3,528.30
1,026.43
-4,249.83
5,981,703.661
614,665.402
0.73
3,167.24
6,281.90
67.03
283.48
3,635.85
3,565.52
1,046.95
-4,336.03
5,981,722.801
614,578.891
0.43
3,231.64
6,379.04
66.32
283.96
3,674.31
3,603.98
1,068.10
-4,422.68
5,981,742.576
614,491.918
0.86
3,296.11
6,474.78
67.44
284.24
3,711.90
3,641.57
1,089.55
-4,508.08
5,981,762.667
614,406.200
1.20
3,359.34
10/17/2016 11.32:24AM
Page 5
COMPASS 5000.1 Build 61B
�N
BP
�II ��
I Jp
ti�NT
Final
Survey Report
BAKER
HUGHES
Company: North America
- ALASKA - BP
Local Co-ordinate Reference:
Well S-113
Project: Prudhoe Bay
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site: PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well: S-113
North Reference:
True
Wellbore: S-113BL1
Survey Calculation Method:
Minimum Curvature
Design: S-113BL1
Database:
EDM R5K-Alaska PROD -ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
E/W
Northing
Easting
DLeg
V. Sec
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°1100usft)
(usft)
6,570.32
68.22
284.98
3,747.95
3,677.62
1,111.87
-4,593.69
5,981,783.621
614,320.249
1.09
3,422.32
6,666.91
68.86
285.28
3,783.29
3,712.96
1,135.33
-4,680.47
5,981,805.702
614,233.118
0.72
3,485.74
6,761.91
68.48
284.88
3,817.85
3,747.52
1,158.36
-4,765.92
5,981,827.364
614,147.326
0.56
3,548.23
6,857.38
66.08
284.87
3,853.18
3,782.85
1,181.12
-4,851.64
5,981,848.767
614,061.263
0.42
3,611.08
6,953.23
67.51
284.90
3,889.40
3,819.07
1,203.92
-4,937.40
5,981,870.196
613,975.156
0.60
3,673.95
7,047.53
68.68
283.80
3,924.58
3,854.25
1,225.60
-5,022.16
5,981,890.526
613,890.069
1.65
3,736.52
7,144.07
68.43
282.97
3,959.88
3,889.55
1,246.40
-5,109.57
5,981,909.936
613,802.343
0.84
3,801.82
7,239.38
68.77
283.11
3,994.65
3,924.32
1,266.42
-5,196.02
5,981,928.581
613,715.593
0.38
3,866.68
7,332.89
69.55
283.46
4,027.92
3,957.59
1,286.51
-5,281.08
5,981,947.310
613,630.239
0.90
3,930.29
7,431.54
68.17
281.73
4,063.50
3,993.17
1,306.58
-5,370.87
5,981,965.949
613,540.151
2.15
3,998.02
7,527.39
67.78
279.76
4,099.45
4,029.12
1,323.14
-5,458.16
5,981,981.126
613,452.615
1.95
4,065.33
7,622.82
66.51
279.47
4,136.51
4,066.18
1,337.83
-5,544,86
5,981,994.436
613,365.700
1.36
4,133.07
7,717.78
66.86
279.01
4,174.10
4,103.77
1,351.83
-5,630.93
5,982,007.068
613,279.421
0.58
4,200.61
7,814.31
67.99
280.86
4,211.16
4,140.83
1,367.22
-5,718.72
5,982,021.054
613,191.406
2.12
4,268.95
7,910.55
68.10
281.80
4,247.14
4,176.81
1,384.75
-5,806.24
5,982,037.198
613,103.626
0.91
4,335.97
8,006.24
68.17
281.85
4,282.78
4,212.45
1,402.95
-5,893.16
5,982,054.012
613,016.434
0.09
4,402.15
8,101.80
68.38
281.25
4,318.15
4,247.82
1,420.72
-5,980.14
5,982,070.402
612,929.196
0.62
4,468.59
8,198.42
69.75
281.20
4,352.67
4,282.34
1,438.29
-6,068.65
5,982,086.559
612,840.422
1.42
4,536.46
8,294.79
70.36
280.65
4,385.54
4,315.21
1,455.46
-6,157.60
5,982,102.311
612,751.221
0.83
4,604.91
8,320.53
69.94
281.43
4,394.28
4,323.95
1,460.09
-6,181.36
5,982,106.569
612,727.390
3.28
4,623.17
8,416.62
70.33
280.59
4,426.94
4,356.61
1,477.35
-6,270.07
5,982,122.415
612,638.427
0.92
4,691.36
8,511.81
69.95
283.14
4,459.28
4,388.95
1,495.76
-6,357.67
5,982,139.424
612,550.546
2.55
4,758.03
8,607.56
68.53
281.34
4,493.22
4,422.89
1,514.74
-6,445.16
5,982,157.018
612,462.773
2.30
4,824.30
8,702.98
67.75
280.03
4,528.75
4,458.42
1,531.17
-6,532.18
5,982,172.055
612,375.511
1.51
4,891.45
8,798.56
66.88
282.93
4,565.62
4,495.29
1,548.71
-6,618.59
5,982,188.221
612,288.840
2.94
4,957.52
8,892.79
66.18
281.64
4,603.15
4,532.82
1,567.10
-6,703.05
5,982,205.269
612,204.114
1.46
5,021.46
8,988.34
66.24
284.79
4,641.70
4,571.37
1,587.08
-6,788.15
5,982,223.899
612,118.713
3.02
5,085.17
10/17/2016 11:32:24AM
Page 6
COMPASS 5000.1 Build 81B
',
bp
BP
//, ��
Final
Survey Report
BAKER
HUGHES
Company: North America
- ALASKA - BP
Local Coordinate Reference:
Well S-113
Project: Prudhoe Bay
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site: PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well: 5-113
North Reference:
True
Wellbore: S-113BL1
Survey Calculation
Method:
Minimum Curvature
Design: S-113131-1
Database:
EDM RSK- Alaska PROD -ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
EIW
Northing
Easting
DLeg
V. Sec
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°I100usft)
(usft)
9,084.21
65.97
286.16
4,680.53
4,610.20
1,610.47
-6,872.62
5,982,245.938
612,033.887
1.34
5,146.63
9,180.27
66.78
286.15
4,719.03
4,648.70
1,634.96
-6,957.15
5,982,269.078
611,948.983
0.84
5,207.59
9,276.72
67.27
287.42
4,756.68
4,686.35
1,660.60
-7,042.17
5,982,293.368
611,863.581
1.31
5,268.39
9,372.15
68.01
287.46
4,792.98
4,722.65
1,687.05
-7,126.36
5,982,318.476
611,778.981
0.78
5,328.09
9,465.97
68.83
287.66
4,827.49
4,757.16
1,713.37
-7,209.54
5,982,343.472
611,695.404
0.90
5,386.96
9,563.83
69.07
287.18
4,862.64
4,792.31
1,740.71
-7,296.68
5,982,369.424
611,607.847
0.52
5,448.75
9,659.25
68.44
286.36
4,897.21
4,826.88
1,766.38
-7,381.83
5,982,393.729
611,522.307
1.04
5,509.67
9,700.00
68.44
286.29
4,912.19
4,841.86
1,777.03
-7,418.20
5,982,403.802
611,485.774
0.16
5,535.84
9,731.79
65.12
285.75
4,924.72
4,854.39
1,785.09
-7,446.28
5,982,411.417
611,457.576
10.56
5,556.12
9,828.36
62.75
282.81
4,967.16
4,896.83
1,806.51
-7,530.32
5,982,431.493
611,373.210
3.67
5,618.20
9,924.05
61.60
280.09
5,011.83
4,941.50
1,823.31
-7,613.25
5,982,446.980
611,290.034
2.79
5,681.61
10,019.58
61.26
278.12
5,057.52
4,987.19
1,836.59
-7,696.08
5,982,458.940
611,207.006
1.85
5,746.71
10,114.67
60.63
275.08
5,103.71
5,033.38
1,846.15
-7,778.64
5,982,467.187
611,124.315
2.87
5,813.43
10,211.41
60.72
272.09
5,151.09
5,080.76
1,851.42
-7,862.80
5,982,471.121
611,040.085
2.70
5,883.68
10,306.01
59.81
268.44
5,198.03
5,127.70
1,851.81
-7,944.93
5,982,470.209
610,957.974
3.49
5,954.60
10,403.38
60.67
262.47
5,246.39
5,176.06
1,845.10
-8,029.13
5,982,462.162
610,873.895
5.39
6,030.88
10,498.70
61.58
256.20
5,292.46
5,222.13
1,829.65
-8,111.09
5,982,445.408
610,792.195
5.84
6,109.59
10,594.09
61.88
251.68
5,337.65
5,267.32
1,806.41
-8,191.79
5,982,420.895
610,711.879
4.18
6,191.10
10,691.60
62.02
248.04
5,383.52
5,313.19
1,776.78
-8,272.57
5,982,389.994
610,631.592
3.30
6,275.86
10,788.82
61.90
243.45
5,429.24
5,358.91
1,741.55
-8,350.77
5,982,353.525
610,553.964
4.17
6,361.21
10,883.33
61.25
239.38
5,474.24
5,403.91
1,701.80
-8,423.74
5,982,312.627
610,481.644
3.85
6,444.27
10,978.88
62.36
235.94
5,519.40
5,449.07
1,656.75
-8,494.87
5,982,266.458
610,411.247
3.38
6,528.39
11,075.09
62.03
234.09
5,564.28
5,493.95
1,607.96
-8,564.59
5,982,216.573
610,342.316
1.74
6,613.17
11,170.61
61.88
235.56
5,609.19
5,538.86
1,559.40
-8,633.49
5,982,166.925
610,274.194
1.37
6,697.12
11,266.04
61.18
234.18
5,654.68
5,584.35
1,511.13
-8,702.10
5,982,117.578
610,206.367
1.47
6,780.67
11,361.03
60.89
233.14
5,700.68
5,630.35
1,461.89
-8,769.04
5,982,067.279
610,140.219
1.01
6,863.27
11,457.88
60.99
234.10
5,747.73
5,677.40
1,411.67
-8,837.20
5,982,015.995
610,072.873
0.87
6,947.40
10/17/2016 11:32:24AM
Page 7
COMPASS 5000.1 Build 81B
11001= by
BP FS as
Final Survey Report BAKER
HUGHES
Company: North America - ALASKA - BP
Local Coordinate Reference:
Well 5-113
Project: Prudhoe Bay
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site: PB S Pad
MD Reference:
Kelly Bushing / Rotary
Table @ 70.33usft
(DOYON 14)
Well: 5-113
North Reference:
True
Wellbore: S-113BL1
Survey Calculation
Method:
Minimum Curvature
Design: S-113BL1
Database:
EDM R5K - Alaska PROD - ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
EIW
Northing
Easting
DLeg
V. Sec
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
11,553.64
61.18
235.33
5,794.03
5,723.70
1,363.26
-8,905.62
5,981,966.502
610,005.235
1.14
7,030.87
11,650.35
61.08
236.76
5,840.73
5,770.40
1,315.95
-8,975.87
5,981,918.095
609,935.754
1.30
7,115.35
11,743.98
60.63
236.38
5,886.33
5,816.00
1,270.90
-9,044.12
5,981,871.970
609,868.237
0.60
7,196.98
11,839.63
60.60
236.07
5,933.26
5,862.93
1,224.57
-9,113.39
5,981,824.546
609,799.710
0.28
7,280.15
11,936.24
60.28
234.96
5,980.92
5,910.59
1,176.99
-9,182.66
5,981,775.879
609,731.213
1.05
7,363.92
12,032.23
59.67
235.43
6,028.95
5,958.62
1,129.55
-9,250.90
5,981,727.368
609,663.741
0.76
7,446.74
12,129.81
57.13
235.87
6,080.08
6,009.75
1,082.66
-9,319.51
5,981,679.394
609,595.890
2.63
7,529.60
12,225.46
54.09
236.26
6,134.10
6,063.77
1,038.60
-9,384.99
5,981,634.301
609,531.127
3.20
7,608.34
12,319.58
52.23
237.84
6,190.53
6,120.20
997.62
-9,448.18
5,981,592.330
609,468.595
2.39
7,683.56
12,415.09
47.43
239.47
6,252.12
6,181.79
959.64
-9,510.47
5,981,553.366
609,406.921
5.19
7,756.49
12,511.30
41.75
240.99
6,320.61
6,250.28
926.08
-9,569.05
5,981,518.884
609,348.888
6.01
7,824.00
12,606.61
37.24
241.92
6,394.14
6,323.81
897.10
-9,622.27
5,981,489.066
609,296.136
4.77
7,884.58
12,703.28
33.18
242.62
6,473.11
6,402.78
871.15
-9,671.59
5,981,462.345
609,247.241
4.22
7,940.27
12,798.31
30.11
245.63
6,554.01
6,483.68
849.35
-9,716.41
5,981,439.837
609,202.780
3.63
7,989.98
12,893.81
27.93
247.10
6,637.51
6,567.18
830.76
-9,758.84
5,981,420.577
609,160.655
2.40
8,036.02
12,989.77
26.54
246.27
6,722.83
6,652.50
813.39
-9,799.17
5,981,402.567
609,120.609
1.50
8,079.63
TIP
13,036.00
26.73
245.71
6,764.16
6,693.83
804.96
-9,818.10
5,981,393.835
609,101.817
0.68
8,100.24
7' Planned TOWS
13,039.00
26.74
245.67
6,766.84
6,696.51
804.40
-9,819.33
5,981,393.260
609,100.596
0.68
8,101.59
KOP Whipstock
13,054.68
29.77
244.77
6,780.65
6,710.32
801.29
-9,826.06
5,981,390.041
609,093.909
19.51
8,108.98
Interpolated Azimuth
13,087.06
39.96
243.55
6,807.18
6,736.85
793.21
-9,842.69
5,981,381.699
609,077.416
31.54
8,127.41
Interpolated Azimuth
i
13,115.57
50.26
242.83
6,827.27
6,756.94
784.10
-9,860.69
5,981,372.307
609,059.567
36.17
8,147.55
Interpolated Azimuth
10/17/2016 11:32:24AM Page 8 COMPASS 5000.1 Build 81B
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
5-113
Wellbore:
5-1136L1
Design:
5-113BL1
Survey
MD I
(usft) 1
13,145.05
Interpolated Azimuth
13,175.48
Interpolated Azimuth
13,184.18
13,214.20
13, 244.28
13,274.29
13,304.20
13,334.43
13,364.42
13,394.47
13,424.43
13,454.54
13,484.73
13,514.61
13, 544.83
13, 574.58
13, 603.23
13, 634.74
13, 671.20
13, 702.03
13, 739.73
13, 770.68
13, 801.03
13, 832.44
13, 860.73
In
60.67
71.93
75.14
85.73
93.53
98.57
103.51
107.40
110.81
112.85
111.97
111.33
110.15
108.49
105.44
101.44
97.25
90.77
90.52
90.49
89.39
88.68
89.39
88.65
85.48
Azi (azimuth)
1°1
242.26
241.77
241.64
241.69
242.89
243.08
243.77
246.43
250.93
251.14
246.44
242.46
237.67
233.34
229.64
229.92
228.72
228.97
224.14
218.26
214.62
209.15
204.12
199.78
195.81
BP FUM
Final Survey Report BAKER
HUGHES
Local Coordinate Reference: Well 5-113
TVD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference: Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference: True
Survey Calculation Method: Minimum Curvature
Database: EDM R5K - Alaska PROD - ANCP1
TVD
TVDSS
NIS
E/W
Northing
Easting
DLeg
V. Sec
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°1100usft)
(usft)
6,843.96
6,773.63
772.91
-9,882.20
5,981,360.780
609,038.232
35.35
8,171.78
6,856.18
6,785.85
759.85
-9,906.77
5,981,347.335
609,013.881
37.03
8,199.58
6,858.64
6,788.31
755.90
-9,914.11
5,981,343.265
609,006.600
36.92
8,207.92
6,863.62
6,793.29
741.87
-9,940.13
5,981,328.824
608,980.809
35.28
8,237.47
6,863.82
6,793.49
727.89
-9,966.74
5,981,314.429
608,954.428
26.24
8,267.50
6,860.65
6,790.32
714.34
-9,993.32
5,981,300.459
608,928.071
16.81
8,297.29
6,854.93
6,784.60
701.21
-10,019.56
5,981,286.915
608,902.039
16.67
8,326.59
6,846.87
6,776.54
688.94
-10,045.98
5,981,274.228
608,875.821
15.41
8,355.60
6,837.05
6,766.72
678.63
-10,072.36
5,981,263.503
608,849.608
18.17
8,383.61
6,825.88
6,755.55
669.57
-10,098.74
5,981,254.020
608,823.378
6.82
8,410.98
6,814.45
6,744.12
659.55
-10,124.55
5,981,243.592
608,797.732
14.80
8,438.35
6,803.34
6,733.01
647.48
-10,149.79
5,981,231.125
608,772.687
12.47
8,466.24
6,792.64
6,722.31
633.39
-10,174.25
5,981,216.652
608,748.461
15.34
8,494.46
6,782.76
6,712.43
617.42
-10,197.48
5,981,200.318
608,725.490
14.76
8,522.56
6,773.94
6,703.61
599.43
-10,220.09
5,981,181.965
608,703.175
15.46
8,551.14
6,767.02
6,696.69
580.75
-10,242.18
5,981,162.939
608,681.386
13.48
8,579.61
6,762.37
6,692.04
562.32
-10,263.61
5,981,144.178
608,660.250
15.20
8,607.38
6,760.17
6,689.84
541.65
-10,287.26
5,981,123.132
608,636.929
20.58
8,638.21
6,759.76
6,689.43
516.58
-10,313.72
5,981,097.655
608,610.871
13.26
8,673.65
6,759.49
6,689.16
493.40
-10,334.02
5,981,074.151
608,590.946
19.07
8,702.83
6,759.53
6,689.20
463.07
-10,356.41
5,981,043.479
608,569.043
10.09
8,737.38
6,760.05
6,689.72
436.81
-10,372.75
5,981,016.959
608,553.123
17.82
8,764.66
6,760.56
6,690.23
409.69
-10,386.35
5,980,989.632
608,539.957
16.74
8,790.00
6,761.10
6,690.77
380.57
-10,398.09
5,980,960.331
608,528.685
14.01
8,814.72
6,762.55
6,692.22
353.68
-10,406.72
5,980,933.307
608,520.481
17.94
8,835.64
10/17/2016 11:32:24AM Page 9 COMPASS 5000.1 Build BIB
.%'"0
BP
Ss�NTb p
Final
Survey Report
BAKER
HUGHES
Company: North America - ALASKA - BP
Local Coordinate Reference:
Well S-113
Project: Prudhoe Bay
TVD Reference:
Kelly Bushing / Rotary
Table @ 70.33usft (DOYON 14)
Site: PB S Pad
MD Reference:
Kelly Bushing / Rotary
Table @ 70.33usft (DOYON 14)
Well: S-113
North Reference:
True
Wellbore: S-113BL1
Survey Calculation
Method:
Minimum Curvature
Design: S-11361-1
Database:
EDM R5K-Alaska PROD -ANCP1
Survey
MD Inc
Azi (azimuth)
TVD
TVDSS
N/S
E/W
Northing
Easting
DI -eq
V. Sec
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
13,890.73
82.30
191.34
6,765.74
6,695.41
324.69
-10,413.72
5,980,904.218
608,513.941
18.22
8,856.20
13,921.03
81.83
191.28
6,769.92
6,699.59
295.27
-10,419.61
5,980,874.704
608,508.524
1.56
8,876.01
13,962.41
80.68
196.50
6,776.22
6,705.89
255.58
-10,429.42
5,980,834.868
608,499.344
12.77
8,904.35
13,990.46
81.15
200.50
6,780.65
6,710.32
229.32
-10,438.21
5,980,808.473
608,490.975
14.18
8,925.09
14,020.61
80.72
204.39
6,785.40
6,715.07
201.81
-10,449.57
5,980,780.785
608,480.050
12.82
8,948.69
14,050.70
80.44
209.20
6,790.33
6,720.00
175.32
-10,462.95
5,980,754.090
608,467.096
15.80
8,973.52
14,080.28
80.91
213.86
6,795.12
6,724.79
150.44
-10,478.21
5,980,728.981
608,452.234
15.63
8,999.17
14,110.80
81.12
216.89
6,799.89
6,729.56
125.87
-10,495.66
5,980,704.132
608,435.178
9.83
9,026.57
14,140.54
83.48
220.79
6,803.88
6,733.55
102.92
-10,514.14
5,980,680.896
608,417.065
15.23
9,054.05
14,170.38
87.14
223.27
6,806.32
6,735.99
80.84
-10,534.05
5,980,658.500
608,397.512
14.80
9,082.33
14,200.25
93.78
228.78
6,806.08
6,735.75
60.12
-10,555.52
5,980,637.443
608,376.371
28.88
9,111.29
14,230.41
94.67
232.87
6,803.85
6,733.52
41.12
-10,578.83
5,980,618.081
608,353.366
13.84
9,140.98
14,261.15
90.68
234.34
6,802.42
6,732.09
22.90
-10,603.54
5,980,599.477
608,328.949
13.83
9,171.49
14,290.15
93.56
236.42
6,801.35
6,731.02
6.44
-10,627.39
5,980,582.640
608,305.371
12.25
9,200.37
14,320.41
90.55
233.72
6,800.26
6,729.93
-10.87
-10,652.18
5,980,564.938
608,280.863
13.36
9,230.49
14,350.31
94.46
233.39
6,798.96
6,728.63
-28.61
-10,676.20
5,980,546.819
608,257.125
13.12
9,260.17
14,380.63
92.18
231.10
6,797.20
6,726.87
-47.14
-10,700.13
5,980,527.912
608,233.496
10.65
9,290.15
14,410.41
93.16
226.57
6,795.81
6,725.48
-66.72
-10,722.52
5,980,507.985
608,211.423
15.55
9,319.33
14,439.99
98.29
229.42
6,792.86
6,722.53
-86.41
-10,744.38
5,980,487.953
608,189.881
19.81
9,348.11
14,470.27
97.02
234.26
6,788.83
6,718.50
-104.94
-10,767.97
5,980,469.047
608,166.590
16.39
9,377.80
14,499.91
94.24
238.89
6,785.92
6,715.59
-121.18
-10,792.58
5,980,452.420
608,142.242
18.15
9,407.24
14,530.58
91.75
242.44
6,784.31
6,713.98
-136.18
-10,819.27
5,980,436.999
608,115.791
14.12
9,437.86
14,560.29
89.08
245.30
6,784.10
6,713.77
-149.26
-10,845.94
5,980,423.497
608,089.337
13.17
9,467.49
14,590.45
89.11
249.37
6,784.57
6,714.24
-160.88
-10,873.76
5,980,411.440
608,061.706
13.49
9,497.39
14,626.85
90.83
253.84
6,784.59
6,714.26
-172.37
-10,908.29
5,980,399.411
608,027.365
13.16
9,533.04
14,657.07
93.01
256.00
6,783.58
6,713.25
-180.22
-10,937.45
5,980,391.092
607,998.337
10.15
9,562.22
14,686.73
94.58
260.76
6,781.62
6,711.29
-186.18
-10,966.43
5,980,384.673
607,969.459
16.87
9,590.30
10/1712016 11:32:24AM
Page 10
COMPASS 5000.1 Build 818
BP
lw,�00p Final Survey Report
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
S-113
Wellbore:
S-113BL1
Design:
S-113BL1
Survey
(usft)
rias
BAKER
HUGHES
Local Co-ordinate Reference:
Well S-113
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K - Alaska PROD - ANCP1
MD Inc
Azi (azimuth)
TVD
TVDSS
NIS
ENV
Northing
Easting
DLeg
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°1100usft)
14,711.04
94.36
262.14
6,779.72
6,709.39
-189.79
-10,990.40
5,980,380.690
607,945.555
5.73
14,740.51
94.55
257.96
6,777.43
6,707.10
-194.86
-11,019.33
5,980,375.157
607,916.709
14.16
14,770.11
96.21
253.71
6,774.66
6,704.33
-202.07
-11,047.89
5,980,367.496
607,888.263
15.36
14,800.35
98.19
250.67
6,770.87
6,700.54
-211.24
-11,076.45
5,980,357.872
607,859.855
11.93
14,830.46
97.95
246.62
6,766.64
6,696.31
-222.10
-11,104.21
5,980,346.580
607,832.274
13.34
14,859.93
98.46
242.75
6,762.43
6,692.10
-234.57
-11,130.58
5,980,333.695
607,806.116
13.11
14,890.30
97.82
238.12
6,758.13
6,687.80
-249.40
-11,156.72
5,980,318.452
607,780.215
15.24
14,923.19
97.70
233.96
6,753.68
6,683.35
-267.60
-11,183.74
5,980,299.827
607,753.486
12.54
14,950.43
97.67
229.80
6,750.04
6,679.71
-284.26
-11,204.97
5,980,282.832
607,732.522
15.13
14,981.29
97.99
225.53
6,745.83
6,675.50
-304.84
-11,227.57
5,980,261.894
607,710.259
13.75
15,012.07
97.70
221.62
6,741.63
6,671.30
-326.93
-11,248.58
5,980,239.479
607,689.600
12.62
15,040.33
97.79
217.21
6,737.82
6,667.49
-348.56
-11,266.36
5,980,217.573
607,672.172
15.47
15,070.21
97.63
216.01
6,733.81
6,663.48
-372.32
-11,284.01
5,980,193.530
607,654.895
4.02
15,099.87
97.41
214.00
6,729.93
6,659.60
-396.41
-11,300.88
5,980,169.183
607,638.414
6.76
15,130.45
96.36
209.91
6,726.26
6,655.93
-422.16
-11,316.94
5,980,143.179
607,622.763
13.71
15,165.45
97.00
207.94
6,722.19
6,651.86
-452.59
-11,333.76
5,980,112.495
607,606.437
5.88
15,188.05
97.25
206.57
6,719.39
6,649.06
-472.52
-11,344.03
5,980,092.401
607,596.486
6.12
15,220.05
95.14
204.57
6,715.93
6,645.60
-501.22
-11,357.76
5,980,063.494
607,583.216
9.06
15,250.37
92.73
202.48
6,713.85
6,643.52
-528.95
-11,369.83
5,980,035.577
607,571.587
10.51
15,281.31
92.18
201.05
6,712.53
6,642.20
-557.65
-11,381.29
5,980,006.694
607,560.584
4.95
15,314.83
92.24
198.87
6,711.23
6,640.90
-589.14
-11,392.72
5,979,975.038
607,549.653
6.50
15,325.85
92.03
200.83
6,710.82
6,640.49
-599.49
-11,396.46
5,979,964.623
607,546.079
17.88
15,368.00
92.03
200.83
6,709.33.
6,639.00
-638.86
-11,411.44
5,979,925.024
607,531.728
0.00
Projection to TD - 2-318"
V. Sec
(usft)
9,612.86
9,640.45
9,668.79
9,698.11
9,727.58
9,756.64
9,786.70
9,819.20
9,845.92
9,875.78
9,905.02
9,931.23
9,958.41
9,985.05
10, 011.84
10, 041.61
10, 060.48
10, 086.71
10,111.03
10,135.31
10,160.95
10,169.37
10, 202.03
1011712016 11:32:24AM Page 11 COMPASS 5000.1 Build 81B
`RN'fZ
by
BP
•■
T
Final Survey Report,fA
BAKER
ES
Company:
North America
- ALASKA - BP
Local Coordinate Reference:
Well S-113
Project:
Prudhoe Bay
TVD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Site:
PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well:
5-113
North Reference:
True
Wellbore:
S-11361-1
Survey Calculation Method:
Minimum Curvature
Design:
S-113BL1
Database:
EDM RSK- Alaska PROD -ANCP1
Casing Points
Measured
Vertical
Casing Hole
Depth
Depth
Diameter Diameter
(usft)
(usft)
Name
(in) (in)
13,036.00
6,764.16
7" Planned TOWS
7.000 8.500
15,368.00
6,709.33
2-3/8"
2.375 4.250
Design Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N1-S
+Fr-yy
(usft)
(usft)
(usft)
(usft)
Comment
12,989.77
6,722.83
813.39
-9,799.17
TIP
13,039.00
6,766.84
804.40
-9,819.33
KOP Whipstock
13,054.68
6,780.65
801.29
-9,826.06
Interpolated Azimuth
13,087.06
6,807.18
793.21
-9,842.69
Interpolated Azimuth
13,115.57
6,827.27
784.10
-9,860.69
Interpolated Azimuth
13,145.05
6,843.96
772.91
-9,882.20
Interpolated Azimuth
13,175.48
6,856.18
759.85
-9,906.77
Interpolated Azimuth
15,368.00
6,709.33
-638.86
-11,411.44
Projection to TD
Prepared By: Yosha Ragbirsingh Survey Manager Baker Hughes
10/17/2016 11.32:24AM Page 12 COMPASS 5000.1 Build 818
Obp
Project: Prudhoe8ay
Site: PBS Pad
Well: 5.113
Wellbore: 5.11381.1
Design: S-11381-1(S-11315-113BL1)
_,.wT__
hle...Nome:19.1e
MegaecFW
S.eegJ:5MfiI0m
DVAaak:alax
U.:10'1201
-- --- Nuasmoct
WELLBORE DETAILS: S-11381_1
RITB EWEPFORVATION
S-113BL1
Ce-arduafe(( Reference: WeDS-113, True Nenh
Vertmi(TVD)Refereme'. Kelb BusNnVIRotayTabk®70.33ush(DOYONI4)
Parent Wellbore: S-1138
Beetbn (VS) Refererce'. Sbt-(D.DON, DAME)
Tie on MD: 12989.77
Measured Depth Refererce'. Kee/Busting l RotsiyTable B 70.33us0(DOYON 14)
Czkubbon"ad: UnmumCwatre
Dost Drilling
FNA .9
BAKER
HUGHES
Easting (400 usft/in)
A0000 OFFSET REPORT
by
North America - ALASKA - BP
Prudhoe Bay
PB S Pad
S-113
S-113BL1
S-113BL1
AOGCC Post Drilling Offset Report
17 October, 2016
we PF-_
'Ail
BAKER
HUGHES
/BOO GCC OFFS
ET REPORT
b BP r/.as
ZiT p Anticollision Report BAKER
HUGHES
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Reference Site: PB S Pad
Site Error: 0.00usft
Reference Well: S-113
Well Error: 0.00usft
Reference Wellbore S-113BL1
Reference Design: S-113BL1
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 5-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Reference
S-11381-1
Filter type:
NO GLOBAL FILTER: Using user defined selection & filtering criteria
Interpolation Method:
MD Interval 25.00usft Error Model: ISCWSA
Depth Range:
Unlimited Scan Method: Tray. Cylinder North
Results Limited by:
Maximum center -center distance of 500.00usft Error Surface: Elliptical Conic
Survey Program Date 10/17/2016
From To
(usft) (usft) Survey (Wellbore)
132.00 861.10 S-113 Gyro (S-113)
940.96 9,659.25 S-113 IIFR (S-113)
9,700.00 12,989.77 S -113B IIFR (S-1136)
13,039.00 15,325.85 BHI CTK MWD 3" (S-11361-1)
Tool Name Description
CB -GYRO -SS Camera based gyro single shots
MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal
MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal
MWD MWD - Standard
10/17/2016 11:42:50AM Page 2 of 5 COMPASS 5000.1 Build 81B
AOC`C�C OFFSET G-.EPD 0G3T
BP
r
by Anticollision Report
Company:
North America - ALASKA- BP
Local Co-ordinate Reference:
Project:
Prudhoe Bay
ND Reference:
Reference Site:
PB S Pad
MD Reference:
Site Error:
0.00usft
North Reference:
Reference Well:
S-113
Survey Calculation Method:
Well Error:
0.00usft
Output errors are at
Reference Wellbore
S-113BL1
Database:
Reference Design:
5-113BL1
Offset ND Reference:
rias
BAKER
HUGHES
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Summary
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
PB S Pad
Plan S-136 - Plan 5-136 - Plan #7 S-136
2,307.48
2,450.00
186.40
54.87
147.07
Pass - Major Risk
S-100 - S-100 - S-100
1,286.45
1,300.00
68.65
25.62
46.77
Pass - Major Risk
5-101 - S-101 - S-101
105.65
100.00
120.59
4.39
116.20
Pass - Major Risk
S-101 - S-101 PB1 - S-101 PB1
105.65
100.00
120.59
4.39
116.20
Pass - Major Risk
S-102 - S-102 - 5-102
654.31
650.00
81.37
12.07
69.34
Pass - Major Risk
S-102 - S-1021_1 - S-1021_1
654.31
650.00
81.37
12.46
68.95
Pass - Major Risk
S-102 - S-1021_1 PB1 - S-1021-1 PB1
654.31
650.00
81.37
12.46
68.95
Pass - Major Risk
S-102 - S-102PBI - 5-102PB1
654.31
650.00
81.37
12.07
69.34
Pass - Major Risk
S-103 - S-103 - S-103
505.54
500.00
26.88
8.92
18.00
Pass - Major Risk
S-104 - 5-104 - S-104
407.70
400.00
103.07
8.42
94.66
Pass - Major Risk
S-105 - S-105 - S-105
529.89
525.00
89.64
9.46
80.21
Pass - Major Risk
S-106 - S-106 - 5-106
351.36
350.00
61.14
8.28
52.86
Pass - Major Risk
S-106 - S-106PB1 - S-106PB1
351.36
350.00
61.14
8.28
52.86
Pass - Major Risk
S-107 - S-107 - S-107
500.81
500.00
13.38
10.76
2.64
Pass - Major Risk
5-108 - S-108 - 5-108
100.01
100.00
29.56
4.10
25.46
Pass - Major Risk
S-108 - S -108A' - S -108A
34.03
34.03
29.65
2.60
27.05
Pass - Major Risk
S-109 - 5-109 - S-109
254.89
250.00
75.68
4.91
70.78
Pass - Major Risk
S-109 - S-109PB1 - S-109PB1
254.89
250.00
75.68
4.91
70.78
Pass - Major Risk
S-110 - 5-110 - S-110
100.65
100.00
60.33
4.20
56.14
Pass - Major Risk
S-110 - S-11 OA - S -110A
100.00
100.00
60.33
4.18
56.15
Pass - Major Risk
S-110 - S -110B - S -110B
87.08
100.00
60.24
3.87
56.37
Pass - Major Risk
S-111 - S-111 - S-111
505.46
500.00
13.61
10.34
3.30
Pass - Major Risk
S-111 - S-111 PB1 - S-111 PBI
505.46
500.00
13.61
9.79
3.85
Pass - Major Risk
S-111 - S-111 PB2 - S-111 PB2
505.46
500.00
13.61
10.34
3.30
Pass - Major Risk
S-112 - S-112 - S-112
694.82
700.00
217.59
14.54
203.08
Pass - Major Risk
S-112 - S -112L1 - S -112L1
694.82
700.00
217.59
14.49
203.13
Pass - Major Risk
5-112 - S-1121_1 PBI - S -112L1 PBI
694.82
700.00
217.59
14.54
203.08
Pass - Major Risk
S-112 - 5-11211 PB2 - S-1I2L1 PB2
694.82
700.00
217.59
14.54
203.08
Pass - Major Risk
S-113 - 5-113 - 5-113
9,972.51
9,975.00
27.04
11.75
19.38
Pass - Major Risk
S-113 - S-11 3A - S -113A
9,972.51
9,975.00
27.04
11.75
19.38
Pass - Major Risk
S-113 - S -113B - S -113B
Out of range
5-114 - S-114 - S-114
2,454.90
2,425.00
84.48
66.34
18.71
Pass - Major Risk
S-114 - S -114A - S -114A
2,454.90
2,425.00
84.48
66.34
18.71
Pass - Major Risk
S-115 - S-115 - S-115
105.93
100.00
135.38
4.02
131.36
Pass - Major Risk
S-116 - S-116 - S-116
871.25
875.00
275.80
16.40
259.40
Pass - Major Risk
5-116 - S -116A - S -116A
871.25
875.00
275.80
16.40
259.40
Pass - Major Risk
5-116 - S-116APB1 - S-116APB1
871.25
875.00
275.80
16.40
259.40
Pass - Major Risk
5-116 - S-116APB2 - S-116APB2
871.25
875.00
275.80
16.40
259.40
Pass - Major Risk
S-117 - S-117 - 5-117
730.10
725.00
172.45
13.86
158.60
Pass - Major Risk
S-118 - 5-118 - S-118
277.46
275.00
256.42
5.39
251.03
Pass - Major Risk
S-119 - S-119 - S-119
784.86
775.00
35.88
15.04
21.45
Pass - Major Risk
5-120 - S-120 - S-120
2,516.26
2,550.00
209.71
66.46
146.81
Pass - Major Risk
5-121 - 5-121 - 5-121
579.94
575.00
289.39
11.10
278.29
Pass - Major Risk
S-121 - S-121 PB1 - 5-121 PB1
579.94
575.00
289.39
11.10
278.29
Pass - Major Risk
S-122 - S-122 - S-122
229.43
225.00
150.50
4.77
145.74
Pass - Major Risk
S-122 - S-122PB1 - S-122PB1
229.43
225.00
150.50
4.77
145.74
Pass - Major Risk
S-122 - S-122PB2 - S-122PB2
229.43
225.00
150.50
4.77
145.74
Pass - Major Risk
S-122 - S-122PB3 - S-122PB3
229.43
225.00
150.50
4.77
145.74
Pass - Major Risk
S-125 - S-125 - S-125
854.71
850.00
292.41
18.04
274.37
Pass - Major Risk
S-125 - S-125PB1 - 5-125PB1
854.71
850.00
292.41
18.04
274.37
Pass - Major Risk
S-200 - Plan S -200A v4.0 (S -503A) - S -200A wp0
852.38
875.00
238.69
14.57
224.24
Pass - Major Risk
5-200 - 5-200 - S-200
866.30
875.00
238.98
14.89
224.21
Pass - Major Risk
S-200 - 5-200PB1 - S-200PB1
866.30
875.00
238.98
14.89
224.21
Pass - Major Risk
10/1712016 11:42.50AM Page 3 of 5 COMPASS 5000.1 Build 81B
Ak5l C OoI G�CT �EpORT
ft"Vbp BP
Anticollision Report
Company:
North America - ALASKA - BP
Local Co-ordinate Reference:
Project:
Prudhoe Bay
ND Reference:
Reference Site:
PB S Pad
MD Reference:
Site Error:
0.00usft
North Reference:
Reference Well:
S-113
Survey Calculation Method:
Well Error:
0.0ousft
Output errors are at
Reference Wellbore
S-113BL1
Database:
Reference Design:
S-113BL1
Offset TVD Reference:
ri.I
BAKER
HUGHES
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Summary
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
PB S Pad
S-201 - S-201 - S-201
331.80
325.00
44.74
6.55
38.19
Pass - Major Risk
S-201 - S-201 PB1 - S-201 PB1
331.80
325.00
44.74
6.60
38.14
Pass - Major Risk
S-213 - S-213 - S-213
728.47
725.00
202.50
11.92
190.68
Pass - Major Risk
S-213 - S -213A - S -213A
732.36
725.00
202.57
11.98
190.69
Pass - Major Risk
S-213 - S-213ALl - S-213AL1
732.36
725.00
202.57
11.98
190.69
Pass - Major Risk
S-213 - S-213AL1-01 - S-213ALl-01
732.36
725.00
202.57
11.98
190.69
Pass - Major Risk
S-213 - S-213AL2 - S-213AL2
732.36
725.00
202.57
11.98
190.69
Pass - Major Risk
S-213 - S-213AL3 - S-213AL3
732.36
725.00
202.57
11.98
190.69
Pass - Major Risk
S-216 - S-216 - S-216
277.16
275.00
226.31
6.44
219.87
Pass - Major Risk
S-400 - S-400 - S-400
322.51
325.00
420.52
6.34
414.18
Pass - Major Risk
S-400 - S -400A - S -400A
322.70
325.00
420.52
6.34
414.18
Pass - Major Risk
S-401 - S-401 - S-401
2,675.40
2,750.00
179.07
76.75
124.85
Pass - Major Risk
S-401 - S-401 PBI - S-401 PB1
2,675.40
2,750.00
179.07
76.73
124.86
Pass - Major Risk
S-41 - S-41 - S-41
853.55
875.00
388.61
15.91
372.72
Pass - Major Risk
S-41 - S -41A - S-41 A
858.19
875.00
388.72
16.04
372.71
Pass - Major Risk
S-41 - S-41 AL1 - S-41 AL1
858.19
875.00
388.72
16.04
372.71
Pass - Major Risk
S-41 - S-41 L1 - S-41 L1
853.55
875.00
388.61
15.91
372.72
Pass - Major Risk
S-41 - S-41 PB1 - S-41 PBI
853.55
875.00
388.61
15.91
372.72
Pass - Major Risk
S-42 - S-42 - S-42
842.74
850.00
362.83
15.42
347.42
Pass - Major Risk
S-42 - S -42A - S -42A
833.08
850.00
362.67
15.26
347.42
Pass - Major Risk
S-42 - S-42PB1 - S-42PB1
842.74
850.00
362.83
15.42
347.42
Pass - Major Risk
S-43 - S-43 - S-43
818.82
825.00
326.46
14.78
311.70
Pass - Major Risk
S-43 - S-431_1 - S-431_1
818.82
825.00
326.46
14.78
311.70
Pass - Major Risk
S-44 - S-44 - S-44
797.85
800.00
301.07
13.80
287.28
Pass - Major Risk
S-44 - S -44A - S -44A
807.25
825.00
301.27
13.94
287.34
Pass - Major Risk
S-44 - S-441_1 - S -44L1
797.85
800.00
301.07
13.75
287.33
Pass - Major Risk
S-44 - S-441_1 PB1 - S-441_1 PB1
797.85
800.00
301.07
13.75
287.33
Pass - Major Risk
S-504 - S-504 - S-504
95.49
100.00
449.78
4.26
445.52
Pass - Major Risk
10/17/2016 11:42:50AM Page 4 of 5 COMPASS 5000.1 Build 81B
Ak5\�C oOf���C� GSL 'ORT
BP rel Fag
Zr,` z by Anticollision Report BAKERS
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Reference Site:
PB S Pad
Site Error:
0.00usft
Reference Well:
S-113
Well Error:
0.00usft
Reference Wellbore
S-113BL1
Reference Design:
S-113BL1
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well S-113
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K- Alaska PROD - ANCP1
Offset Datum
teference Depths are relative to Kelly Bushing / Rotary Table @ Coordinates are relative to: S-113
)ffset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04
ventral Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.91°
Ladder Plot
Ian S-136, Plan
$ _S -_113,S -113,S -113V14
--J
.--..---
-100,S -100,S 1$
I I
S-113 S-113A,S-113AV3
-0-I S-213 S-213AL1
S 213AL1 V9
-101,S-101,S-1
- S 113,S-113B,S 113BV6
$I S-213,S-213AUl-01,S-213AL1-01
V
-101, S -101
I
I I I
I
:03) 450---
$ S-114AS114
,-
� � 0 10000
- -L - --- 1
I
-102,S-1021-1,S-1021-1V5
-102,S-102L1PB1,S-102L1PB1 V11
$ S-115,15� lre115V[%pth (2500 us�n)
Sfi�led
$ S -116,S -116,S -116V6
I
I
OLO
I I
-
--
c-----
---
o
i I I
I
I
1,
o -
(D 300
U
(V
Q)
J_ J _I_ _ -
_ _
_ _
_ J - _ _ _ _
_ -
--_ - -
_ = - - _ _ - - - - _ _ - _ _
a
- I
I
_l- -LEGEND
X150
r
C)
,
Ian S-136, Plan
$ _S -_113,S -113,S -113V14
$I S-213 S -$13A,
$-213'IA V22
-100,S -100,S 1$
I I
S-113 S-113A,S-113AV3
-0-I S-213 S-213AL1
S 213AL1 V9
-101,S-101,S-1
- S 113,S-113B,S 113BV6
$I S-213,S-213AUl-01,S-213AL1-01
V
-101, S -101
-102,S -102,S- 2V11 2500
$ S-114AS114
,-
� � 0 10000
$ - L,-
S213 3S213AL3 � Y�000
-102,S-1021-1,S-1021-1V5
-102,S-102L1PB1,S-102L1PB1 V11
$ S-115,15� lre115V[%pth (2500 us�n)
Sfi�led
$ S -116,S -116,S -116V6
$ S-216, S-216, S-216 V2
$ S -400,S -400,S -400V4
-103,S-103,S-103V6
-104,S-104,S-104V3
-105,S-105,S-105V6
-106,S-106,S-106V2
-106,S-106PB1,S-106PB1 V12
-107, S-107, S-107 V36
-108, S-108, S-108 V6
-108, S-1 08A*, S-1 08A VO
-109, S-109, S-109 V9
$ S-116,S-116APB1,S-116APB1 VO
$ S-116,S-116APB2,S-116APB2VO
-X- S-117, S-117, S-117 V4
-X- S-118, S-118, S-118 V5
•4-- S-119, S-119, S-119 V7
$ S-120,S-120,S-12OV4
$ S -121,S -121,S-121 V8
• S-121,S-121PB1,S-121PB1 V4
$ S-122, S-122, S-122 V9
$ S-401, S-401, S-401 V4
S-401, S-401 PB1, S-401 PB1 V7
$ S -41,S -41,S-41 V1
-e- S-41,S-41A,S-41AVO
$ S-41,S-41AL1,S-41AL1 VO
$ S-41,S-41L1,S-41L1 VO
�E-
S-41, S-41 PB1, S-41 PB1 VO
-4- S-42, S-42, S-42 V2
$ S-42, S -42A, S -42A VO
10/17/2016 11:42:50AM Page 5 of 5 COMPASS 5000.1 Build 81B
AOCc�C�C OFFSET l�EVnD 0RT
THE STATE
ol ALASKA
1-1
GOVERNOR BILL WALKER
John McMullen
Engineering Team Lead
BP Exploration (Alaska), Inc.
P.O. Box 196612
Anchorage, AK 99519-6612
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-113BL1
BP Exploration (Alaska), Inc.
Permit to Drill Number: 215-218
Surface Location: 4542' FSL, 4496' FEL, SEC. 35, T12N, R12E, UM
Bottomhole Location: 1798' FNL, 207' FEL, SEC. 32, TI 2N, R12E, UM
Dear Mr. McMullen:
Enclosed is the approved application for permit to re -drill the above referenced development
well.
The permit is for a new wellbore segment of existing well Permit No. 202-143, API No. 50-029-
23094-02-00. Production should continue to be reported as a function of the original API
number stated above.
This permit to drill does not exempt you from obtaining additional permits or an approval
required by law from other governmental agencies and does not authorize conducting drilling
operations until all other required permits and approvals have been issued. In addition, the
AOGCC reserves the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to
comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit.
Sincerely,
Cathy . Foerster
Chair
DATED this � day of January, 2016.
STATE OF ALASKA
'_ASKA OIL AND GAS CONSERVATION COMMIS
PERMIT TO DRILL
20 AAC 25.005
4 l %r V es a 1S am r
0FC 14 2015
1 a. Type of Work:
1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑
tc. Specify if well is proposed for:
Drill ❑ Lateral 0 .
Stratigraphic Test ❑ Development - Oil PI • Service - Winj ❑ Single Zone 21-
Colabed Gas ❑ Gas Hydrates ❑
Redrill ❑ Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond Blanket 23 'Single Well ❑
11. Well Name and Number:
BP Exploration (Alaska), Inc
Bond No. 6194193 ,
PBU S-113BL1
3 Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 196612 Anchorage, AK 99519-6612
MD: 15900' ' TVD: 6755'ss •
PRUDHOE BAY, AURORA
OIL (Undefined)
4a. Location of Well Governmental Section):
( )
7. Property Designation (Lease Number):
• ADL 028257, 028258 & 028259
g Land Use Permit:
13. Approximate spud date:
Surface: 4542' FSL, 4496' FEL, Sec. 35, T12N, ,R12E, UM
70' FSL, 3745' FEL, Sec. 28, T12N, R12E, UM
83-47
3/15/2016
Top of Productive Horizon:
9. Acres in Property: 2560 & 2459
14. Distance to Nearest Property:
Total Depth: 1798' FNL, 207' FEL, Sec. 32. T1 2N, R1 2E, UM
2600
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL: 70.33 , feet
15. Distance to Nearest Well Open
to Same Pool:
Surface: x- 618937 y- 5980745 Zone ASP 4
GL Elevation above MSL: 36.56 feet
2550
16. Deviated wells: Kickoff Depth: 13033 feet
17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 114 degrees
Downhole: 3056 ' Surface: 2380
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casin Weight Grade Couolina Len th
MD TVD MD TVD(including stage data
3-1/4" 2-3/8" 4.6# 13Cr85 TH511 2867'
13033' 6691'ss 15900' 6755'ss Uncemented Solid / Slotted Liner
19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft):
Plugs (measured):
1
Effect. Depth MD (ft):
Effect. Depth TVD (ft):
Junk (measured):
1
13515 7191
None
13404
7092
None
Casing Length Size Cement Volume MD TVD
Conductor/Structural 80 20" 260 sx Arctic Set (Approx.) 33-113 33-113
Surface 5553 10-3/4" 784 Arctic Set III Lite 3, 750 sx Class 'G' 33-5586 33-3370
Intermediate
Production 13460 7" 504 sx Class 'G' 31 -13491 31 -7170
Liner
Perforation Depth MD (ft): 13014'- 13098' Perforation Depth TVD (ft): 6745- 6819'
20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program Z Time v. Depth Plot ❑ Shallow Hazard Analysis ❑
Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program RI 20 AAC 25.050 requirements
21. Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Boltz, Travis
from without prior written approval. Email Travis.Boltz@bp.com
Printed Name J011rv- C Ile Title Engineering Team Lead
SignaturePhone +1 907 564 4711 Date
Commission Use Only
Permit to Drillj
API Number: 50- 029-23094-60-00
Permit Approval
Date:
See cover letter for other
Number: 15—.- Z/E
requirements:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed meth ne, gas hydrates, or gas contained in shales: Eg"
1 Mud log req'd: Yes ❑ No
Other: QpP trsf fv 3 5pUP5�JSamples req'd: Yes ❑ L1
'
�/
fJ�, r7[J�GtT�' I'e- VG fCr fly 2 ,SUDt44- easures Yes & No ❑/ Directional svy req'd: Yes 87 No El
Spacing exception req'd: Yes El No Liz Inclination -only svy req'd: Yes ❑ No EI`
Post initial injection MIT req'd: Yes ❑ No ❑
APPROVED BY /
Approved by: L^_ COMMISSIONER THE COMMISSION Dater _
C
ORIGINAL r/ I-
`l_.�,``'�,
Form 10-401 Revised 11/2015 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g))
Submit Form and
Attachments in Duplicate
To: Alaska Oil & Gas Conservation Commission
From: Travis Boltz by
CTD Engineer
Date: December 9, 2015
Re: S-113BL1 Permit to Drill Request
Approval is requested for a permit to drill a CTD sidetrack from well S-113BL1 using Nordic 1 to
a target in Kuparuk. This is a lateral extension of the S-113BL1 for the following reasons: when
the rig drills the pilot hole to set the whipstock it will be re -opening the perforations, one of the
objectives of the lateral to maintain parent production, and the completion is uncemented so the
well will not be abandoned by drilling and completing this lateral.
Rig Work (scheduled to begin 15 March, 2016)
1.
MIRU and test BOPE 250 psi low and 3,500 psi high. (609 psi MASP).
2.
Mill 3.5" Pilot hole to 13,033' MD
3.
Drift and Caliper for Whipstock
4.
Set 3.5" Monobore Whipstock at 13,033'MD
5.
Mill 2.80" window and 10' of rathole.
6.
Drill Build section: 3.25" OH, —241'(301 deg/100 planned)
7.
Drill Lateral section: 3.25" OH, —2606'(120 deg/100 planned)
8.
Run 2-3/8" solid L-80 Solid x 2-3/8" slotted L-80 liner to leaving TOL 12,920 MD.
9.
Freeze protect well to 2500' MD
10.
Set TWC, RDMO
Post -Rig Work:
1. Re -install wellhouse, flowline and pull TWC.
2. Set GLV's
Mud Program:
• Milling/drilling: 9.8 ppg PowerVis for milling window and drilling (386 psi over -balance).
Disposal: `--
• All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI
at DS 4 or Pad 3 at DS 6.
• Fluids >1 % hydrocarbons or flammables must go to Pad 3.
• Fluids >15% solids by volume must go to GNI.
• Fluids with solids that will not pass through 1/4" screen must go to GNI.
• Fluids with PH >11 must go to GNI.
Hole Size:
• 3.25" From 13,033' MD to 15,900' MD
Liner Program:
• 2-3/8", 4.6 Ib/ft, 13Cr-85, TH511, solid 13,033' MD -14,000' MD
• 2-3/8", 4.6 Ib/ft, 13Cr-85, TH511, slotted 14,000' MD —15,900' MD
• The primary barrier for this operation: a minimum EMW of 9.8 ppg.
• A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Well Control:
• BOP diagram is attached.
• Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
• The annular preventer will be tested to 250 psi and 3,500 psi.
Directional:
• See attached directional plan. Maximum planned hole angle is 1141, inclination at kick off
point is 28.5°
• Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
• Distance to nearest property —2,600'.
• Distance to nearest well within pool — 2,550'.
Logging:
• MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section.
Anti -Collision Failures:
• S-1138 Parent Wellbore at KOP: No Errors
Hazards:
• S pad is considered a H2S pad.
• Most recent H2S level on S -Pad is 32 ppm recorded on 3/10/2015.
• The lost circulation risk in S-113BL1 is considered to be medium, with 2 fault crossings.
Reservoir Pressure:
• The reservoir pressure on S-113BL1 expected to be 3056 psi at 6756' TVDSS. (8.7 ppg
equivalent).
• Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2380.4 psi.
• An EMW of 9.8 ppg for this well will provide 386 psi over -balance to the reservoir.
Travis Boltz CC: Well File
CTD Engineer Joe Lastufka
564-5750
TREE = 4-12" 5M CNV
WELLHEAD =
135/8" 5M FMC
ACTUATOR =
REF LOG: MWD GR ON 07/11/02
OKB_ ELEV =
70.33'
BF. ELEV =
39.13'
KOP =
700'
Max Angle_-,..
71° @347TI
Datum MD =
13043''
Datum TVD =
6700' SS
10-314" CSG, 45.5#, L-80, D = 9.950" j- j 6587'
Minimum ID = 2.813" a@ 2367'
3-112" HES X NIPPLE
3-112" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" 1-] 12942'
PBTD 13404'
7" CSG, 26#, L-80, D = 6.276" 13491'
S-1 13 B @
SAFL _ _ NOTES: 3-1/2" CHROME NIPPLES. WELL
ANGLE> 70° 3381'.
2367' �-j3-1/2" HES X NP, D= 2.813"
r`,A.r, I FT MANDRELS
ST
PERFORATION SUMMARY
TVD
REF LOG: MWD GR ON 07/11/02
TYPE VLV
ANGLE AT TOP PERF: 26° @ 13014'
Note: Refer to Production DB for historical perf data
SQE
SPF
INTERVAL
Opn/Sqz
SHOT
SQZ
2-1/2"
4
13014 - 13038
O
07/28/02
5598
2-12"
6
13018 - 13038
O
11/08/02
2
2-112"
6
13038 - 13098
O
06!29114
0
PBTD 13404'
7" CSG, 26#, L-80, D = 6.276" 13491'
S-1 13 B @
SAFL _ _ NOTES: 3-1/2" CHROME NIPPLES. WELL
ANGLE> 70° 3381'.
2367' �-j3-1/2" HES X NP, D= 2.813"
r`,A.r, I FT MANDRELS
ST
MD
TVD
DEVI
TYPE VLV
LATCH
PORT
DATE
4
6713
3800
69
MMG DOME
RK
16
09118/15
3
11147
5598
62
MMG DOME
RK
16
09/18/15
2
12712
6480
33
MMG DMI'
RK
0
07/12/02
1
12802
6557
30
MMG SO
RK
22
09/18/15
12862 J -j3-1/2" x CATCHER (08/10/15)
12862 3-1/2" HES X NP, D = 2.813"
12884 T X 4-1/2" BAKER -S3 PKR D= 3.875"
12910 {-] 3-112" HES X NP, D = 2.813"
12930 E-A 3-112" HES X NP, D = 2.813"
12942 -13 1/2" VVL.EG, D = 2.992"
12932 ELMD TT (LOGG®07128!02)
DATE
REV BY COMMENTS
DATE REV BY COMMENTS
07/13/02
DACIKK ORIGINAL COM PLETION
08/29/11 SET/SV TT ELM CORRECTION
07/28/02
TMWKK PERF & GLV C/O (7/30/02)
07/02/14 GTW/JMD ADPERFS (06/29/14)
08/02/02
RL./tlh GLV UPDATE
08/28/15 SJW/JMD SET X CATCHER (08110/15)
11/08/02
KSB/KK ADPEW
08/28/15 SJW/JMD GLV CIO (08/12/15)
11
04/09/03
DRS/TP I TVDYMDCORRECTIONS
10/02/15 MGSiJMD GLV C/O (09/18/15)
0620/03
JCMNTLH I GLV C/O
AURORA UNIT
WELL: S -113B
PERMf No: '2021430
API No: 50-029-2309402
SEC 35, T12K R12E, 738' FNL & 783' FVVL
BP Exploration (Alaska)
TRS= 4-1/2"5MCMN
WELLHEAD =
13-518" 5M FMC
ACTUATOR=
REF LOG: MWD GR ON 07/11/02
OKB_ E -EV =
70.33'
BF. ELEV =
39.13'
KOP =
700'
Max Angle =
71" @ 3477'
Datum MD =
13043'
Datum TVD =
6709 SS
10-314" CSG, 45.5#, L-80, D = 9.950" H 5587'
Minimum ID = 2.813" @ 2367'
3-1/2" HES X NIPPLE
IS -1 13 B L 1 SAFETY NOTES: 3-1/2" CHROME
NIPPLES. W ELL ANGLE> 70" @
CTD Sidetrack Proposal 3381'.
1 3-1/2" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" 1-1 12942'
3-1/2" monobore whipstock @ 13,033' —
28°inc @ winds;
m�
a�
PBTD 13404'
7" CSG, 26#, L-80, D = 6.276" 13491'
2367' I-13-1/2" HES X NP, D = 2.813"
GAS LIFT MANDRELS
ST
PERFORATION SUMMARY
rVD
REF LOG: MWD GR ON 07/11/02
TYPE
ANGLE AT TOP PERF: 26' @ 13014'
Note: Refer to Production DB for historical pert data
SIZE
SPF
INTERVAL
Opn/Sgz
SHOT
SQZ
2-1/2"
4
13014 - 13038
O
07/28/02
3
2-1/2"
6
13018- 13038
O
11/08/02
RK
2-112"
6
13038 - 13098
O
06/29/14
33
1 3-1/2" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" 1-1 12942'
3-1/2" monobore whipstock @ 13,033' —
28°inc @ winds;
m�
a�
PBTD 13404'
7" CSG, 26#, L-80, D = 6.276" 13491'
2367' I-13-1/2" HES X NP, D = 2.813"
GAS LIFT MANDRELS
ST
MD
rVD
DEV
TYPE
VLV
LATCH
PORT
DATE
4
6713
3800
69
MMG
DOME
RK
16
08/02/02
3
11147
5598
62
MMG
DOME
RK
16
08/02/02
2
12712
6480
33
MMG
DMY
RK
0
07112/02
1
12802
6557
30
MMG
SO
RK
26
06/19/03
1286—j 3 1/2" HfsS X NP, D = 2.813"
128 7" X 4-1/2- BAKER S-3 PKR, D = 3.875-
--J__1291 J—i 3-1/2" HES X NP, D = 2.813"
2.70" deployment sleeve
Landed across nipple
12930 Fl/2— HES X NP, D = 2.813"
—J 12942 I --i3-1/2" WLEG, D= 2.992"
12932 H.MD TT (LOGGED 07/28/02)
35°/100' BUR
RA Tags TD @ 15,900' MD
14,000'MD XO 2-3/8" solid x 2 3/8" slotted L-80 liner
DATE
REV BY COMMENTS DATE REV BY COMFITS
07/13/02
DAC/KK ORIGINAL COMPLETION 08/29/11 SET/SV TT O_MD cORRECTlON
07/28/02
IMNYKK !ERF & GLV GO (7/30102) 07/02/14 GTW/JMD ADPERFS (06/29114)
08/02/02
RLAlh GLV UPDATE
11/08/02
KSB/KK ADPERF
04/09/03
DRS/TP TVDVMD CORRECTIONS
06/20/03 1
JCMYTLH I GLV CJO
AURORA UNIT
WELL: S -113B
PENT No: "2021430
AR No: 50-029-23094-02
SEC 35, T12K R12E, 738' FNL & 783' FWL
BP Exploration (Alaska)
North America - ALASKA - BP
Prudhoe Bay
PB S Pad
S-113
S-113BL1
Plan: S-113BL1 WP12
BP Coil Tubing Report
10 December, 2015
& pp -_-
BAKER
HUGHES
r.
j br)
1.0#44
Company:
North America -ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
S-113
Wellbore:
S-113BL1
Design:
S-11361_1 WP12
BP
PB S Pad, TR -12-12
reA.®
BP Coil Tubing Report
From:
BAKER
Position Uncertainty:
0.00 usft
HUGHES
Local Co-ordinate Reference:
Well 5-113
+NI -S 0.00 usft
TVD Reference:
Mean Sea Level
Position Uncertainty
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Model Name Sample Date
Survey Calculation Method:
Minimum Curvature
Design
Database:
EDM R5K - Alaska PROD - ANCP1
Project Prudhoe Bay, GPB, PRUDHOE BAY
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site
PB S Pad, TR -12-12
Site Position:
70° 21'23.002 N
From:
Map
Position Uncertainty:
0.00 usft
Well
S-113
Well Position
+NI -S 0.00 usft
Northing:
+E/ -W 0.00 usft
Position Uncertainty
0.00 usft
Wellbore
S-113BL1
Magnetics
Model Name Sample Date
Wellhead Elevation:
BGGM2015 5/1/2016
Design
S-113BL1 WP12
Audit Notes:
Version:
Phase:
Vertical Section:
Depth From (TVD)
(usft)
-37.48
Northing:
5,980,854.540 usft
Latitude:
70° 21'23.002 N
Easting:
617,919.920 usft
Longitude:
149° 2'32.343 W
Slot Radius:
0.000 in
Grid Convergence:
0.90 °
Northing:
5,980,744.910 usft •
Latitude:
70° 21'21.767 N
Easting:
618,930.630 usft
Longitude:
149° 2'2.849 W
Wellhead Elevation:
37.48 usft
Ground Level:
• 36.56 usft
Declination Dip Angle Field Strength
(nT)
18.85 81.05 57,515
PLAN Tie On Depth: 12,893.81
+N/ -S +E/ -W Direction
(usft) (usft) (°)
0.00 0.00 240.00
12/10/2015 8; 55: 53AM Page 2 COMPASS 5000.1 Build 61
BP
bp
�Nt BP Coil Tubing Report FeA&8
BAKER
HUGHES
Company: North America -ALASKA - BP
Project: Prudhoe Bay
Site: PS S Pad
Well: S-113
Wellbore: S-113BL1
Design: S-113BL1 WP12
Survey Tool Program Date 12/8/2015
From To
(usft) (usft) Survey (Wellbore)
132.00 861.10 5-113 Gyro (5-113)
940.96 9,659.25 S-113 IIFR (S-113)
9,700.00 12,893.81 S -113B IIFR (5-113B)
12,893.81 15,900.00 S-113BL1 WP12 (S-113BL1)
Planned Survey
MD Inc Azi
(usft) (°) (°I
12,893.81 27.93 247.10
5-1138 Actual Survey
12,900.00 27.84 247.05
12,989.77 26.54 246.27
S -113B Actual Survey
13,000.00 26.58 246.15
13,033.00 26.72 245.75
S -113B Actual Survey TIP
13,053.00 28.52 245.75
KOP
13,100.00 44.97 245.75
13,103.00 46.02 245.75
5
13,153.00 63.52 245.75
6
13,200.00 79.97 245.75
13,203.00 81.02 245.75
7
13,230.00 90.47 245.75
8
Tool Name
CB -GYRO -SS
MWD+IFR+M S -WO CA
MWD+IFR+M S-WOCA
MWD
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Description
Camera based gyro single shots
MWD + IFR + Multi Station W/O Crustal
MWD + IFR + Multi Station W/O Crustal
MWD - Standard
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
EDM R5K-Alaska PROD -ANCP1
TVDSS
N/S
ENV
Northing
Easting
DLeg
V. Sec
TFace
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
(°)
6,567.18
830.76
-9,758.84
5,981,420.577
609,160.655
2.40
8,036.02
162.51
6,572.65
829.64
-9,761.50
5,981,419.408
609,158.007
1.50
8,038.89
-165.08
6,652.50
813.39
-9,799.17
5,981,402.567
609,120.609
1.50
8,079.63
-165.04
6,661.65
811.55
-9,803.35
5,981,400.656
609,116.454
0.68
8,084.18
-52.55
6,691.15
805.51
-9,816.87
5,981,394.410
609,103.035
0.68
8,098.90
-52.44
6,708.87
801.70
-9,825.32
5,981,390.468
609,094.644
9.00
8,108.13
0.00
6,746.40
790.19
-9,850.87
5,981,378.556
609,069.283
35.00
8,136.01
0.00
6,748.50
789.32
-9,852.82
5,981,377.647
609,067.347
35.00
8,138.14
0.00
6,777.23
772.61
-9,889.92
5,981,360.352
609,030.526
35.00
8,178.61
0.00
6,791.91
754.34
-9,930.47
5,981,341.442
608,990.268
35.00
8,222.87
0.00
6,792.40
753.12
-9,933.17
5,981,340.184
608,987.590
35.00
8,225.82
0.00
6,794.40
742.08
-9,957.69
5,981,328.751
608,963.249
35.00
8,252.58
0.00
12110/2015 8:55:53AM Page 3
COMPASS 5000.1 Build 61
!�
BP
rel he
Ntr
BP Coil Tubing Report
BAKER
HUGHES
Company: North America - ALASKA - BP
Local Coordinate
Reference:
Well 5-113
Project: Prudhoe Bay
Site: PB S Pad
TVD Reference:
Mean Sea Level
Well: 5-113
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Wellbore: S-113BL1
Survey Calculation Method:
Minimum Curvature
Design: S-113BLIWP12
Database:
EDM RSK- Alaska PROD
-ANCP1
Planned Survey
-
MD Inc
(usft) (°)
Azi
TVDSS
N/S
ENV
Northing
Easting
DLeg
V. Sec
TFace
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(usft)
(°)
13,270.00
104.47
245.75
6,789.21
725.83
-9,993.76
5,981,311.933
608,927.443
35.00
8,291.94
0.00
9
13,282.00
108.41
244.24
6,785.82
720.96
-10,004.19
5,981,306.906
608,917.094
35.00
8,303.40
-20.00
10
13,294.00
111.35
241.05
6,781.74
715.78
-10,014.21
5,981,301.566
608,907.157
35.00
8,314.67
-45.00
End 35deg/100ft
13,300.00
111.66
240.35
6,779.54
713.05
-10,019.08
5,981,298.758
608,902.333
12.00
8,320.25
-65.00
13,354.00
114.24
233.89
6,758.47
686.10
-10,060.82
5,981,271.149
608,861.027
12.00
8,369.88
-65.26
12
13,400.00
114.12
227.84
6,739.61
659.63
-10,093.35
5,981,244.171
608,828.924
12.00
8,411.28
-90.00
13,414.00
114.04
226.01
6,733.89
650.90
-10,102.69
5,981,235.295
608,819.729
12.00
8,423.73
-92.48
13
13,500.00
103.72
226.01
6,706.11
594.46
-10,161.15
5,981,177.934
608,762.175
12.00
8,502.59
180.00
13,564.00
96.04
226.01
6,695.13
550.70
-10,206.48
5,981,133.462
608,717.554
12.00
8,563.72
-180.00
14
13,600.00
95.72
230.34
6,691.44
526.82
-10,233.15
5,981,109.167
608,691.261
12.00
8,598.76
94.00
13,700.00
94.67
242.34
6,682.35
471.73
-10,315.89
5,981,052.775
608,609.413
12.00
8,697.96
94.44
13,714.00
94.51
244.02
6,681.23
465.43
-10,328.35
5,981,046.282
608,597.062
12.00
8,711.89
95.54
15
13,800.00
84.19
244.02
6,682.21
427.81
-10,405.55
5,981,007.442
608,520.477
12.00
8,797.56
180.00
13,832.00
80.35
244.02
6,686.51
413.92
-10,434.05
5,980,993.104
608,492.205
12.00
8,829.19
-180.00
16
13,900.00
81.16
235.79
6,697.46
380.29
-10,492.06
5,980,958.560
608,434.738
12.00
8,896.24
-85.00
13,970.00
82.17
227.36
6,707.63
337.29
-10,546.26
5,980,914.702
608,381.227
12.00
8,964.69
-83.66
17
14,000.00
83.12
223.86
6,711.47
316.48
-10,567.52
5,980,893.559
608,360.304
12.00
8,993.50
-75.00
14,100.00
86.43
212.28
6,720.61
238.21
-10,628.79
5,980,814.333
608,300.290
12.00
9,085.70
-74.55
14,120.00
87.12
209.97
6,721.73
221.11
-10,639.11
5,980,797.080
608,290.243
12.00
9,103.18
-73.49
18
12/10/2015 8:55:53AM
Page 4
COMPASS 5000.1 Build 61
12/10/2015 8.55.53AM Page 5 COMPASS 5000.1 Build 61
BP
OEM
`sffi
BP Coil Tubing Report
BAKER
HUGHES
Company: North America
- ALASKA - BP
Local Coordinate
Reference:
Well 5-113
Project: Prudhoe Bay
TVD Reference:
Mean Sea Level
Site: PB S Pad
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Well: 5-113
North Reference:
True
Wellbore: S-113BL1
Survey Calculation Method:
Minimum Curvature
Design: S-113BL1 WP12
-
-
Database:
EDM R5K-Alaska PROD
-ANCP1
Planned Survey
-
- -
- - -
- -
- - -
- - -
-
MD Inc
Azi
TVDSS
NIS
ENV
Northing
Easting
DLeg
V. Sec
TFace
(usft) (°)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(°I100usft)
(usft)
(°)
14,200.00
88.09
219.53
6,725.09
155.52
-10,684.62
5,980,730.778
608,245.782
12.00
9,175.39
84.40
14,300.00
89.38
231.47
6,727.31
85.58
-10,755.80
5,980,659.719
608,175.729
12.00
9,272.01
84.00
14,400.00
90.69
243.39
6,727.25
31.84
-10,839.92
5,980,604.661
608,092.480
12.00
9,371.73
83.73
14,470.00
91.59
251.75
6,725.85
5.16
-10,904.55
5,980,576.961
608,028.283
12.00
9,441.04
83.74
19
14,500.00
90.97
255.29
6,725.18
-3.34
-10,933.31
5,980,568.000
607,999.668
12.00
9,470.20
100.00
14,580.00
89.28
264.74
6,725.01
-17.19
-11,012.01
5,980,552.904
607,921.208
12.00
9,545.27
100.08
20
14,600.00
90.66
262.78
6,725.02
-19.37
-11,031.89
5,980,550.416
607,901.366
12.00
9,563.58
-55.00
14,700.00
97.50
252.89
6,717.89
-40.31
-11,129.22
5,980,527.927
607,804.385
12.00
9,658.35
-55.00
14,725.00
99.18
250.38
6,714.27
-48.11
-11,152.69
5,980,519.763
607,781.041
12.00
9,682.57
-55.71
21
14,800.00
97.21
241.50
6,703.56
-78.35
-11,220.40
5,980,488.451
607,713.830
12.00
9,756.33
-102.00
14,805.00
97.07
240.92
6,702.94
-80.74
-11,224.75
5,980,485.993
607,709.520
12.00
9,761.29
-103.27
22
14,855.00
91.07
240.92
6,699.39
-104.97
-11,268.31
5,980,461.075
607,666.349
12.00
9,811.13
-180.00
23
14,900.00
90.50
235.55
6,698.77
-128.65
-11,306.55
5,980,436.791
607,628.493
12.00
9,856.09
-96.00
15,000.00
89.23
223.61
6,699.01
-193.37
-11,382.54
5,980,370.878
607,553.545
12.00
9,954.26
-96.07
15,005.00
89.17
223.02
6,699.08
-197.01
-11,385.97
5,980,367.187
607,550.174
12.00
9,959.05
-96.05
24
15,085.00
88.35
213.45
6,700.82
-259.76
-11,435.41
5,980,303.664
607,501.740
12.00
10,033.24
-95.00
25
15,100.00
88.25
211.65
6,701.26
-272.40
-11,443.48
5,980,290.900
607,493.876
12.00
10,046.55
-93.00
15,200.00
87.68
199.66
6,704.83
-362.32
-11,486.67
5,980,200.314
607,452.124
12.00
10,128.91
-92.95
15,265.00
87.36
191.86
6,707.65
-424.77
-11,504.29
5,980,137.597
607,435.499
12.00
10,175.39
-92.52
26
15,300.00
86.64
187.71
6,709.48
-459.21
-11,510.23
5,980,103.074
607,430.108
12.00
10,197.75
-100.00
12/10/2015 8.55.53AM Page 5 COMPASS 5000.1 Build 61
12/10/2015 8.55:53AM Page 6 COMPASS 5000.1 Build 61
BP
��•�
�)P
BP Coil Tubing Report
BAKER
HUGHES
Company: North America
- ALASKA - BP
Project: Prudhoe Bay
Local Coordinate
Reference:
Well 5-113
Site: PB S Pad
TVD Reference:
Mean Sea Level
Well: S-113
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
Wellbore: S-113BL1
North Reference:
True
Design: S-113BL1 WP12
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K - Alaska PROD
- ANCP1
Planned Survey
-
-
-
- -
MD Inc
(usft) (°)
Azi
TVDSS
N/S
EIW
Northing
Easting
DLeg
V. Sec
TFace
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(°I100usft)
(usft)
l°)
15,400.00
84.68
175.84
6,717.08
-558.69
-11,513.33
5,980,003.566
607,428.591
12.00
10,250.18
-99.78
15,415.00
84.41
174.05
6,718.50
-573.56
-11,512.01
5,979,988.717
607,430.142
12.00
10,256.47
-98.88
27
15,500.00
84.50
184.30
6,726.74
-658.04
-11,510.79
5,979,904.276
607,432.699
12.00
10,297.66
90.00
15,515.00
84.53
186.11
6,728.18
-672.91
-11,512.15
5,979,889.388
607,431.581
12.00
10,306.27
89.01
28
15,600.00
82.85
196.23
6,737.54
-755.68
-11,528.48
5,979,806.372
607,416.569
12.00
10,361.80
100.00
15,615.00
82.58
198.02
6,739.44
-769.90
-11,532.86
5,979,792.087
607,412.414
12.00
10,372.70
98,88
29
15,700.00
84.45
187.93
6,749.06
-852.09
-11,551.79
5,979,709.614
607,394.796
12.00
10,430.19
-80.00
15,765.00
86.01
180.26
6,754.48
-916.65
-11,556.41
5,979,644.995
607,391.203
12.00
10,466.46
-78.86
30
15,800.00
88.71
177.04
6,756.09
-951.59
-11,555.58
5,979,610.071
607,392.581
12.00
10,483.22
-50.00
15,837.00
91.57
173.65
6,756.00
-988.46
-11,552.58
5,979,573.257
607,396.166
12.00
10,499.06
-49.85
31
15,900.00
90.51
181.14
6,754.85 •
-1,051.34
-11,549.72
5,979,510.437
607,400.025
12.00
10,528.02
TD at 15900.00
98.00
12/10/2015 8.55:53AM Page 6 COMPASS 5000.1 Build 61
r., BP r�.r
BP Coil Tubing Report BAKER
HUGHES
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Mean Sea Level
Site: PB S Pad
MD Reference:
Well: S-113
70.33usft (DOYON 14)
Wellbore: S-11381-1
True
Design: 5-113BL1 WP12
Survey Calculation Method:
Targets
Target Name
EDM R5K - Alaska PROD - ANCP1
hit/miss target Dip Angle Dip Dir. TVD +NIS
+E/ -W
Shape (°) (°) (usft) (usft)
(usft)
5-113BL1 Fault 1 0.00 0.00 0.00 283.43
-10,789.40
plan misses target center by 6670.05usft at 12893.81 usft MD (6567.18 TVD, 830.76 N, -9758.84 E)
608,139.000 70° 21'24.478 N
Polygon
5,980,857.00
Point 1 0.00 0.00
0.00
Point 2 0.00 -277.11
-122.42
Point 3 0.00 -472.65
-91.52
Point 4 0.00 -277.11
-122.42
S-113BL1 T3 0.00 0.00 6,700.00 -101.58
-11,234.60
plan misses target center by 13.46usft at 14823.91 usft MD (6700.98 TVD, -89.88 N, -11241.19 E)
5,980,465.000
Point
149° T31.264 W
5-113BL1 T1 0.00 0.00 6,710.00 328.08
-10,577.64
plan misses target center by 15.40usft at 13998.93usft MD (6711.34 TVD, 317.24 N, -10566.79 E)
5,979,665.000
Point
149° T41.538 W
S-113BL1 T4 0.00 0.00 6,755.00 -896.15
-11,587.29
plan misses target center by 31.45usft at 15746.85usft MD (6753.14 TVD, -898.55 N, -11555.99 E)
5,978,650.00
Point
S-113BL1 Fault 0.00 0.00 0.00 -1,914.55
-11,386.41
plan misses target center by 6811.74usft at 15900.00usft MD (6754.85 TVD, -1051.34 N, -11549.72 E)
5,978,667.00
Polygon
Point 1 0.00 0.00
0.00
Point 2 0.00 11.16
-198.86
Point 3 0.00 23.35
-399.71
Point 4 0.00 11.16
-198.86
S-113BL1 T2 0.00 0.00 6,725.00 34.28
-10,972.39
plan misses target center by 45.41 usft at 14532.00usft MD (6724.83 TVD, -10.44 N, -10964.51 E)
149° 6'56.366 W
Point
5-113BL1 T5 0.00 0.00 6,755.00 -1,141.77
-11,551.18
plan misses target center by 90.44usft at 15900.00usft MD (6754.85 TVD, -1051.34 N, -11549.72 E)
Point
5-113BL1 Polygon 0.00 0.00 0.00 1,124.20
-10,039.14
plan misses target center by 6579.71 usft at 12893.81 usft MD (6567.18 TVD, 830.76 N, -9758.84 E)
Polygon
Point 1 0.00 0.00
0.00
Local Co-ordinate Reference: Well 5-113
TVD Reference:
Mean Sea Level
MD Reference:
Kelly Bushing / Rotary Table @
70.33usft (DOYON 14)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K - Alaska PROD - ANCP1
Northing
Easting
(usft)
(usft) Latitude
Longitude
5,980,857.000
608,139.000 70° 21'24.478 N
149° 7' 18.266 W
5,980,857.00
608,139.00
5,980,578.00
608,021.00
5,980,383.00
608,055.00
5,980,578.00
608,021.00
5,980,465.000
607,700.000 70° 21'20.685 N
149° T31.264 W
5,980,905.000
608,350.000 70° 21'24.920 N
149° 7' 12.077 W
5,979,665.000
607,360.000 700 21' 12.865 N
149° T41.538 W
5,978,650.000
607,577.000 700 21' 2.853 N
149° T35.621 W
5,978,650.00
607,577.00
5,978,658.00
607,378.00
5,978,667.00
607,177.00
5,978,658.00
607,378.00
5,980,605.000
607,960.000 70° 21'22.025 N
1490 T23.605 W
5,979,420.000
607,400.000 70° 21' 10.450 N
149° T40.471 W
5,981,709.500
608,875.750 70° 21' 32.757 N
149° 6'56.366 W
5,981,709.50 608,875.75
12110/2015 8:55:53AM Page 7 COMPASS 5000.1 Build 61
Company:
NorthAmerica- ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
5-113
Wellbore:
S-113BL1
Design:
S-113BL1 WP12
Point 2
-1,314.31
Point 3
Point 4
Point 5
Point 6
Casing Points
Measured Vertical
Depth Depth
(usft) (usft)
115.00 44.67 CONDUCTOR 1
5,587.19 3,300.62 SURFACE CASING
15,900.00 6,754.85 2-3/8"
BP
BP Coil Tubing Report
0.00
-440.37
363.96
0.00
-1,721.45
-1,222.64
0.00
-2,522.23
-1,341.57
0.00
-2,509.19
-1,753.26
0.00
-1,314.31
-1,730.17
Name
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
5,981,275.00
5,979,969.00
5,979,166.50
5,979,173.00
5,980,368.00
Casing
Hole
Diameter
Diameter
(in)
(in)
20.000
42.000
10.750
13.500
2.375
4.250
►i.®
BAKER
HUGHES
Well 5-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
True
Minimum Curvature
EDM R5K - Alaska PROD - ANCPi
609,246.62
607,680.69
607,574.50
607,162.69
607,166.81
12/10/2015 8:55.53AM
Page 8
COMPASS 5000.1 Build 61
BP
by BP Coil Tubing Report FG&r
BAKER
HUGHES
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Site:
PB S Pad
Well:
5-113
Wellbore:
5-113BL1
Design:
S-113BL1 WP12
Plan Annotations
Measured
Depth
(usft)
12,893.81
12,989.77
13, 033.00
13,053.00
13,103.00
13,153.00
13,203.00
13,230.00
13,270.00
13,282.00
13,294.00
13,354.00
13,414.00
13,564.00
13,714.00
13,832.00
13,970.00
14,120.00
14,470.00
14,580.00
14,725.00
14,805.00
14,855.00
15,005.00
15,085.00
15, 265.00
15,415.00
15, 515.00
15,615.00
15, 765.00
15, 837.00
Local Co-ordinate Reference:
Well 5-113
ND Reference:
Mean Sea Level
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K-Alaska PROD -ANCP1
Vertical
Local Coordinates
Depth
+N/ -S
+E/ -W
(usft)
(usft)
(usft)
Comment
6,567.18
830.76
-9,758.84
5-113B Actual Survey
6,652.50
813.39
-9,799.17
S-1138 Actual Survey
6,691.15
805.51
-9,816.87
S-11 3B Actual Survey TIP
6,708.87
801.70
-9,825.32
KOP
6,748.50
789.32
-9,852.82
5
6,777.23
772.61
-9,889.92
6
6,792.40
753.12
-9,933.17
7
6,794.40
742.08
-9,957.69
8
6,789.21
725.83
-9,993.76
9
6,785.82
720.96
-10,004.19
10
6,781.74
715.78
-10,014.21
End 35deg/100ft
6,758.47
686.10
-10,060.82
12
6,733.89
650.90
-10,102.69
13
6,695.13
550.70
-10,206.48
14
6,681.23
465.43
-10,328.35
15
6,686.51
413.92
-10,434.05
16
6,707.63
337.29
-10,546.26
17
6,721.73
221.11
-10,639.11
18
6,725.85
5.16
-10,904.55
19
6,725.01
-17.19
-11,012.01
20
6,714.27
-48.11
-11,152.69
21
6,702.94
-80.74
-11,224.75
22
6,699.39
-104.97
-11,268.31
23
6,699.08
-197.01
-11,385.97
24
6,700.82
-259.76
-11,435.41
25
6,707.65
-424.77
-11,504.29
26
6,718.50
-573.56
-11,512.01
27
6,728.18
-672.91
-11,512.15
28
6,739.44
-769.90
-11,532.86
29
6,754.48
-916.65
-11,556.41
30
6,756.00
-988.46
-11,552.58
31
12/10/2015 8:55.53AM Page 9
COMPASS 5000.1 Build 61
12/10/2015 8:55:53AM Page 10
COMPASS 5000.1 Build 61
Fel
�..�
BP Coil Tubing Report
BAKER
HUGHES
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Local Co-ordinate Reference:
Well S-113
Site:
PB S Pad
ND Reference:
Mean Sea Level
Well:
5-113
MD Reference:
Kelly Bushing / Rotary Table @ 70.33usft (DOYON 14)
Wellbore:
S -1136L1
North Reference:
True
Design:
S-113BL1 WP12
Survey Calculation Method:
Minimum Curvature
Database:
EDM R5K - Alaska PROD - ANCP1
15,900.00 6,754.85 -1,051.34
-11,549.72 TD at 15900.00
Checked By:
Approved By:
Date:
12/10/2015 8:55:53AM Page 10
COMPASS 5000.1 Build 61
Project: Prudhoe Bay
Site: PBS Pad
Well: S-113
Wellbore: S-113BL1
Plan: S-113131-1 WP12(S4131S-113BL1
1500
MIGN
omm
HUGHES
quo
S-113BL1 Fault I
600 -
300-
s•n3Is-1138
i
J 0
S-I13BL1 TI
-300
5-113131-1 T2
-600 - - - S-113BLIT3' -
7
-900 _. --Si IH/S�il-13BL1 - - - -. -
1 - S-113BLIT4
-120 - +
-1500_ _ _ S-113BLIT5
-1800 S-113BLIFault2
-�,II� --_ - --_- _--
Y -
0E
-21013200-12 - .. _ - -
900-12600-12300-12000.11700-11400-11100.10800-105(10-10200 -9900 -9600 -9300 -9000 -8700 -8400 -8100 -7800 -750(
West(-Wr t + 300 ft/'
as ( ) (
nnrwnmRue Nem
Maanetk NOM laefi
Megrc FFl
WELLBORE DETAILS: S-113BL1
REFE10CENFORMATION
S-11381-1
Con
erdnate (NE) Reference WMI S-113, True North
Ground Level: 36.56
aaerwh,575 53en1
+N/ -S
vertical [M) Rebrence: Mean Sea Level
Easting Labttude Longitude
M
Mpyie:eln5
13-sl1ZHE
Parent Wallbore: S-1138
Section (VS) Relarenra. Sbt- jO.00N, 0.009
MWel'eGGM2D15
Tie on MD: 12893.81
MeasuredDepth Reference: Ke Bushin IRo Table 70.33us8 DOYON I4
Ce Watian Metlwd: MininumCwebrary ( 1
1500
MIGN
omm
HUGHES
quo
S-113BL1 Fault I
600 -
300-
s•n3Is-1138
i
J 0
S-I13BL1 TI
-300
5-113131-1 T2
-600 - - - S-113BLIT3' -
7
-900 _. --Si IH/S�il-13BL1 - - - -. -
1 - S-113BLIT4
-120 - +
-1500_ _ _ S-113BLIT5
-1800 S-113BLIFault2
-�,II� --_ - --_- _--
Y -
0E
-21013200-12 - .. _ - -
900-12600-12300-12000.11700-11400-11100.10800-105(10-10200 -9900 -9600 -9300 -9000 -8700 -8400 -8100 -7800 -750(
West(-Wr t + 300 ft/'
as ( ) (
WELL DETAILS: S-113
US m)
Ground Level: 36.56
6320
+N/ -S
�E/-W Northing
Easting Labttude Longitude
Slot
0.00
OAO 5980744.910 618930.630 70°21'21.767N 149°2'2.849W
SECTION DETAILS
ANNOTATIONS
Sac
MD Inc Azi ssTVD
+NFS +EFW Dleg TFace VSect Target
_I
TVD MD Annotation 1
1
12893.81 27.93 247.10 6567.18
830.76 -9758.84 0.00 0.00 8036.02
6567.18 12893.81 S-113BActualSurvey
2
12989.77 26.54 24627 565250
813.39 -9799.17 1.50 -165.08 8079.63
6652.50 12989.77 S-113BActualSurvey
3
13033.00 26.72 245.75 6691.15
805.51 -9816.87 0.68 -5255 8098.90
6691.15 13033.00 S-113BActual Survey TIP
4
13053.00 28.52 245.75 6708.87
801.70 -9825.32 9.00 0.00 8108.13
6708.87 13053.00 KOP
5
13103.00 46.02 245.75 674850
789.32 -985292 35.00 0.00 8138.14
6748.50 13103.00 5
6
13153.00 53.52 245.75 677723
772.61 -9889.92 35.00 0.00 8178.61
6777.23 13153.00 6
7
13203.00 81.02 245.75 6792.40
753.12 -9933.17 35.00 0.00 822592
6792.40 13203.00 7
8
13230.00 90.47 245.75 6794AD
742.08 -995799 35.00 0.00 825258
6794.40 13230.00 8
9
13270.00 104.47 245.75 678921
725.83 -9993.76 35.00 0.00 8291.94
6789.21 13270.00 9
10
13282.00 108.41 244.24 678592
720.96 -10004.19 35.00 -20.00 8303AO
6785.82 13282.00 10
11
13294.00 111.35 241.05 6781.74
715.78 -10014.21 35.00 45.00 831497
6781.74 13294.00 End 35deg/1008
12
13354.00 114.24 233.89 6758.47
686.10 -10060.82 12.00 -65.00 8369.88
6758.47 13354.00 12
13
13414.00 114.04 226.01 673399
650.90 -10102.69 12.00 -90.00 8423.73
6733.89 13414.00 13
14
13564.00 96.04 226.01 6695.13
550.70-10206AB 12.00 180.00 8563.72
6695.13 13564.00 14
15
13714.00 94.51 244.02 668123
465.43 -10328.35 12.00 94.00 8711.89
6681.23 13714.00 15
16
13832.00 80.35 244.02 6686,51
413.92 -10434.05 12.00 180.00 8829.19
6686.51 13832.00 16
17
13970.00 82.17 227.36 6707.63
33729 -1054626 12.00 -85.00 896499
6707.63 13970.00 17
18
14120.00 87.12 209.97 6721.73
221.11 -10639.11 12.00 -75DO 9103.18
6721.73 14120.00 18
19
14470.00 91.59 251.75 672595
5.16-1090455 12.00 84.40 9441 D4
6725.85 14470.00 19
20
14580.00 89.28 264.74 6725.01
-17.19 -11012.01 12.00 100.00 954527
6725.01 14580.00 20
21
14725.00 99.18 250.38 671427
48.11 -11152.69 12.00 -55.00 9682,57
6714.27 14725.00 21
22
14805.00 97.07 240.92 6702.94
-80.74 -11224.75 12.00 -102.00 976129
6702.94 14805.00 22
23
14855.00 91.07 240.92 669939
-10497.11268.31 12.00 180.00 9811.13
6699.39 14855.00 23
24
15005.00 89.17 223.02 669908
-197.01 -11385.97 12.00 -96.00 9959.05
6699.08 15005.00 24
25
15085.00 88.35 213.45 670092
-259.76 -11435.41 12.00 -95.001003324
6700.82 15085.00 25
26
15265.00 87.36 191.86 6707.65
.424.77 -1150429 12.00 -93.001017539
6707.65 15265.00 26
27
15415.00 84.41 174.05 671850
-573M -11512.01 12.00 -100.0010256.47
6718.50 15415.00 27
28
15515.00 84.53 186.11 6728.18
-672.91 -11512.15 12.00 90.0010306.27
6728.18 15515.00 28
29
15615.00 62.58 198.02 6739.44
-76990 -11532.86 12.00 100.0010372.70
6739.44 15615.00 29
30
15765.00 86.01 18026 6754.48
-91695-11556.41 12.00-BODO10466.46
6754.48 15765.00 30
31
15837.00 91.57 173.65 6756.00
-988A6 -11552,58 12.00 -50.0010499.06
6756.00 15837.00 31
32
15900.00 90.51 181.14 6754.85
-105134.11549.72 12.00 98.0010528.02
6754.85 15900.00 TDatj5900.00
1500
MIGN
omm
HUGHES
quo
S-113BL1 Fault I
600 -
300-
s•n3Is-1138
i
J 0
S-I13BL1 TI
-300
5-113131-1 T2
-600 - - - S-113BLIT3' -
7
-900 _. --Si IH/S�il-13BL1 - - - -. -
1 - S-113BLIT4
-120 - +
-1500_ _ _ S-113BLIT5
-1800 S-113BLIFault2
-�,II� --_ - --_- _--
Y -
0E
-21013200-12 - .. _ - -
900-12600-12300-12000.11700-11400-11100.10800-105(10-10200 -9900 -9600 -9300 -9000 -8700 -8400 -8100 -7800 -750(
West(-Wr t + 300 ft/'
as ( ) (
US m)
6320
6400
^
C;
6480
i - __ _
_. - -- L.1.1-.
'..
I
m
6560
-
5-11313 Actual Survey TIP
tl tl-R. 1
TD at 1590000 1
p
KOP
W
6640
-
__ i - -•--_ : --
- - - -
•
End 35cle IOUft
_ S-113BL I T3
_. -. S i - _.
- -113131-1- 1 - -
- - 13131-1 T2 - _-
�
- - :
�� 51.11381-.1 T4
,>p
G.
6720
-
�
_r. .-
15 __ a
� / S-I13BL I T5
Q
/ 13 14
16 -_ __-- _
17 18 19 20 21 22 23 ., 24 25
26 27 26 >_.* -
6800
.
- __.�
__� 12
6
_. - -
29 �_
U
7 8 910
- __- - 30 311 = _
t:
6880
S-I13>51138L1-
y
6960
7040
Mean ft@
evel
- _ S-113,$..1138
8000
8080 8160 8240 R320 8400 8480 9560 8640
8720 8800 8660 8960 9040 9120 9200 9280 9360 9440 9520 9600 9680 9760 9840 9920 10000 10080
10160 10240-�3-20 -� �0' � r�0 ID �l(�u11120 I "
10320 10400 10480 10560 10640 10720 10800 IOSRO 960 11040 11120 1121
Vertical Section at 240.00° (80 usft/in)
amw„m nv, e,m WELLBORE DETAILS: 5-113BL1 RHFERENCEIPFOROTION �.�
Project: Prudhoe Bay M,e,�,oto ,m, tees a�
Site: PBSPad M.erer�Fu 5-113BL1 C—rdmte(Nil9Reference: WeRS-113,T-Nutlh
Well: 5-113 so-erynsrsa VSeGbo (VS)Referew Mean Sea Leval BAKER �
f"► Wellbore: 2(S41L1 oipana�, et.os Secfion (VS)Rehretm: Slot-(O.00N, O.00E)
lv_ o,t„ytrmt Parent Wellbore: 5-1138
Plan: S-113BL7WP12(S-1131S-113BL7) vna,r&,cttmt Tie on MD: 12893.81 Measured Depth Busrg MISSES
Cehdafion Method: Miniurvehra
1350=
;
b O
to
1200
_ . __ _. ^ :bbd
9UPl-.-
I o
'. C
750:
b00
4`b
_
a -
O _
600_
_. _..
oZ, _
450
T
S_
1 3 g1 1 2
L
300:
_ ..
150
of
+
hb
p •150:
0
O
vl .450_
h0
+G -600
-750j
C
i-. -900.
_
_. + _.
-low
0
5-113BL1
�
-12001
+
-1350,
-1500
-1650
-
-18001._
-1950]{',
-2100 .
-2250
- -
-2400
-2550 -
Mean Sea Level
-
-
-2700
_
14100-13950-13800-13650-13.x_..._) 05 12 �- -9450 -9300 3 00-1215 0-12 0110-1 185 0 •117!10 -11550-IIS--_---
- 500-13350-132!81 -13050.12900-12750.12600-12450- 400-11250-11100-10950-10800 -10650-IOSUO-10350-10200-10050 -99W 9750 -961M1 9450 9300 900 9000 885!1 -87!10 8550
West( -)/East(+) (150 usft/in)
Project: Prudhoe Bay
Site: PBS Pad
t,1 Well: S-113
ok
d o Wellbore: S-113BL1
Plan: S-11381-1 WP12(S-113/S-11
-------- M
HA 1-11
BAKER
HUGHES
From Colour To MD
ANTI -COLLISION SETTINGS
COMPANY DETAILS: North America - ALASKA - BP
Interpolation Method: MD, interval: 25.00
Calculation Method: Minimum Curvature
13033.0026.72
Depth Range From: 12893.81 To 15900.00
Error System: ISCWSA
1
Results Limited By: Centre Distance: 1786.71
Scan Method: Tray. Cylinder North
Reference: Plan: S-113BL1 WP12 (S-113/S-113BL1)
Error Surface: Elliptical Conic
3B
28.52 245.75 6708.87
Warning Method: Rules Based
HA 1-11
BAKER
HUGHES
From Colour To MD
3
13033.0026.72
245.75 6691.15
WELL DETAILS: 5-113
1
_
160
Ground Level:
4
13053.00
28.52 245.75 6708.87
801.70 5825.32 9.00 0.00 8108.13
36.56
+NIS
+EI -W
Northing
E.V,g Latittudo
Longitude Slot
0 0.00
0.00
5980744.910
618930.630 70'21'21.767N 149° 2'2.849 W
6
SECTION DETAILS
63.52 245.75 6777.23
----�
Sec
MD
Inc Ali
TVD +N/ -S +E/ -W
Dleg TFace VSect
7
1
2
12893.81
12989 77
27.93 247.10
2654 24627
6567.18 830.76 -9758.84
665250 81339 579917
0.00 0.00 8036.02
150 16508 807963
120
140 _-
180
200 _
Azimuth from North [°] vs Centre to Centre Separation [20 usft/in]
3
13033.0026.72
245.75 6691.15
805.51 -9816.87 0.68 52.55 8098.90
_
160
4
13053.00
28.52 245.75 6708.87
801.70 5825.32 9.00 0.00 8108.13
5
1 31 03. 00
46.02 245.75 6748.50
789.32 5852.82 35.00 0.00 8138.14
6
13153.00
63.52 245.75 6777.23
772.61 -9889.92 35.00 0.00 8178.61
7
13203.00
81.02 245.75 6792.40
753.12 -9933.17 35.00 0.00 6225.82
140
8
13230.00
90.47 245.75 6794.40
742.08 -9957.69 35.00 0.00 8252.58
9
13270.00
104.47 245.75 6789.21
725.83 -9993.76 35.00 0.00 8291.94
3
10
13282.00
108.41 244.24 6785.82
720.96 -10004.19 35.00 -20.00 8303.40
120
60
11
13294.00
111.35 241.05 6781.74
715.78 -10014.21 35.00 45.00 8314.67
12
13354.00
114.24 233.69 6758.47
686.10-10060.82 12.00 85.00 8369.88
13
13414.00
114.04 226.01 6733.89
650.90 -10102.69 12.00 50.00 8423.73
"
14
13564.00
96.04 226.01 6695.13
550.70 -10206.48 12.00 180.00 8563.72
100
15
13714.00
94.51 244.02 6681.23
465.43 -10328.35 12.00 94.00 8711.89
rypp�
S- 38" 132
S-1138
16
13832.00
80.35 244.02 6686.51
413.92 -10434.05 12.00 180.00 8829.19
17
13970.00
82.17 227.36 6707.63
337.29 -10546.26 12.00 85.00 8964.69
"
80
18
14120.00
87.12 209.97 6721.73
221.11 -10639.11 12.00 -75.00 9103.18
132
19
20
14470.00
14580.00
91.59 251.75 6725.85
89.28 264.74 6725.01
5.16 -10904.55 12.00 84.40 9441.04
-17.19 -11012.01 12.00 100.00 9545.27
-113
Ll 2
21
14725.00
99.18 250.38 6714.27
-08.11 -11152.69 12.00 55.00 9682.57
60
22
14805.00
97.07 240.92 6702.94
80.74 -11224.75 12.00 -102.00 9761.29
21
23
14855.00
91.07 240.92 6699.39
-104.97 -11268.31 12.00 180.00 9811.13
24
15005.00
89.17 223.02 6699.08
-197.01 -11385.97 12.00 56.00 9959.05
25
15085.00
88.35 213.45 6700.82
-259.76 -11435.41 12.00 55.00 10033.24
4D 1
26
15265.00
87.36 191.66 6707.65
-024.77 -11504.29 12.00 53.00 10175.39
27
15415.00
84.41 174.05 6718.50
573.56 -11512.01 12.00 -100.00 10256.47
131 %
I
28
15515.00
84.53 186.11 6728.18
872.91 -11512.15 12.00 90.00 10306.27
29
15615.00
82.58 198.02 6739.44
-769.90 -11532.86 12.00 100.00 10372.70
13
30
15765.00
86.01 180.26 6754.48
-916.65 -11556.41 12.00 80.00 10466.46
f30
8
31
15837.00
91,57 173.65 6756.00
588.46 -11552.58 12.00 50.00 10499.06
�
9L_32
15900.00
90.51 181.14 6754.85
-1051.34 -11549.72 12.00 98.00 10528.02
1 893
2
`
SURVEYPROGRAM
40
Date: 2015-12-08T00:00:00 Valldated.Yes
Version:
"
Depth From
Depth To Sumey/Plan
Tool
132.00
861.10 S-113 Gyro(S-113)
CB-GYRO-SS60
940.96
9659.25 S-113 IIFR (S-113)
MWD+IFR+MSVUCA
'
9700.00
12893.81 57138 IIFR(S113B)
MWD+IFR+MS-WOCA
12893.81
15900.00 S-11381-1 WP12(S-113BL1) MVVD
80
100
-
120
120
140 _-
180
200 _
Azimuth from North [°] vs Centre to Centre Separation [20 usft/in]
North America - ALASKA - BP
Prudhoe Bay
PB S Pad
S-113
500292309400
S-113BL1
S-113BL1 WP12
Travelling Cylinder Report
08 December, 2015
Ff P F -_-
AA Fag
BAKER
HUGHES
BP rZAaI
++;4 Travelling Cylinder Report BAKER
HUGHES
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Reference Site: PB S Pad
Site Error:
0.00 usft
Reference Well:
S-113
Well Error:
0.00 usft
Reference Wellbore
S-113BL1
Reference Design:
S-113BL1 WP12
Local Co-ordinate Reference
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Reference S-113BL1 WP12
Filter type: GLOBAL FILTER APPLIED: All wellpaths within 2004 100/1000 of reference
Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA
Depth Range: 12,893.81 to 15,900.00usft Scan Method: Tray. Cylinder North
Results Limited by: Maximum center -center distance of 1,786.72 usft Error Surface: Elliptical Conic
Survey Tool Program
Date 12/8/2015
From
To
Offset Site Error: 0.00 usft
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
132.00
861.10 S-113 Gyro (S-113)
CB -GYRO -SS
Camera based gyro single shots
940.96
9,659.25 S-113 IIFR (S-113)
MWD+IFR+MS-WOCA
MWD + IFR + Multi Station W/O Crustal
9,700.00
12,893.81 S-1138 IIFR (S -113B)
MWD+IFR+MS-WOCA
MWD + IFR + Multi Station W/O Crustal
12,893.81
15,900.00 S-113BL1 WP12(S-113BL1)
MWD
MWD - Standard
Casing Points
(usft)
(usft)
(usft)
Measured Vertical
(usft)
Casing Hole
PB S Pad
Depth Depth
Casing -
Diameter Diameter
No Go
(usft) (usft)
Name
(in) (in)
14,691.12
115.00 44.67 CONDUCTOR 1
1,064.50
20.000 42.000
705.71
5,587.19 3,300.62 SURFACE CASING
S-106 - S-106 - S-106
10.750 13.500
Centre
15,900.00 6,754.85 2-3/8"
Deviation
2.375 4.250
Summary
PB S Pad - Plan S-137 - Plan S-137 - Plan #7 S-137
Offset Site Error: 0.00 usft
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
Vertical
(usft)
Offset
PB S Pad
Offset Wellbore Centre
Casing -
Centre to
No Go
Allowable Warning
Depth
Plan S-137 - Plan S-137 - Plan #7 S-137
14,691.12
13,700.00
1,064.50
421.69
705.71
Pass - Major Risk
S-106 - S-106 - S-106
Hole Size
Centre
Distance
Deviation
(usft)
Out of range
S-108 - S -108A+ - S -108A
(usft)
(usft)
(usft)
(1
(usft)
Out of range
S-113 - S-113 - S-113
(usft)
(usft)
(usft)
13,675.00
6,684.45
Out of range
S-113 - S-1138 - S -113B
13,025.00
13,025.00
0.00
0.63
-0.56
FAIL- NOERRORS
S-114 - S-114 - S-114
324.02
1,205.15 Pass - Major Risk
13,675.00
6,684.45
12,050.00
Out of range
S-114 - S -114A - S -114A
58.39
-143.73
89.80
-9,938.04
5-625
Out of range
Offset Design
PB S Pad - Plan S-137 - Plan S-137 - Plan #7 S-137
Offset Site Error: 0.00 usft
Survey Program: 47-GYD-GC-SS, 1000
-MWD..
1000-MWD+IFR+MS-W0CA,
4900
-MWD, 4900-MWD+IFR+MS-W0CA
Rule Assigned: Major Risk
Offset Well Error: 0.00 usft
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toolface+
Offset Wellbore Centre
Casing -
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+N/,S
+E/ -W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(1
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
13,675.00
6,684.45
12,025.00
5,457.75
60.95
58.24
-144.33
78.96
-9,917.60
5.625
1,345.56
324.02
1,205.15 Pass - Major Risk
13,675.00
6,684.45
12,050.00
5,467.21
60.95
58.39
-143.73
89.80
-9,938.04
5-625
1,328.07
324.29
1,189.76 Pass - Major Risk
13,675.00
6,684.45
12,075.00
5,476.67
60.95
58.54
-143.12
100.65
-9,958.49
5.625
1,310.83
324.57
1,174.64 Pass - Major Risk
13,685.08
6,683.59
12,100.00
5486.12
61.02
58.69
-141.18
111.50
-9,978.93
5.625
1,293.75
329.33
1,157.82 Pass - Major Risk
13,690.38
6,683.15
12,125.00
5,495.58
61.05
58.83
-139.86
122.35
-9,999.37
5.625
1,276.90
331.93
1,142.24 Pass - Major Risk
13,700.00
6,682.35
12,150.00
5,505.04
61.11
58.98
-137.96
133.20
-10,019.81
5.625
1,260.29
336.33
1,126.26 Pass - Major Risk
13,700.00
6,682.35
12,175.00
5,514.50
61.11
59.13
-137.31
144.04
-10,040.25
5,625
1,243.88
336.63
1,112.15 Pass - Major Risk
CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/8/2015 10:04:55PM Page 2 COMPASS 5000.1 Build 61
Foam
BAKER
HUGHES
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Offset Design
PBS Pad Plan S-137- Plan S-137 Plan
BP
Travelling Cylinder Report
Company:
North America - ALASKA - BP
Local Co-ordinate Reference:
Project:
Prudhoe Bay
TVD Reference:
Reference Site:
PB S Pad
MD Reference:
Site Error:
0.00 usft
North Reference:
Reference Well:
S-113
Survey Calculation Method:
Well Error:
0.00 usft
Output errors are at
Reference Wellbore
S-113BL1
Database:
Reference Design:
S-113BL1 WP12
Offset TVD Reference:
Foam
BAKER
HUGHES
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Offset Design
PBS Pad Plan S-137- Plan S-137 Plan
-
-
#7 S-137
Offset Site Error- 0.00 usft
Survey Program: 47-GYD-GC-SS,
1000•MWO,
1000-MWD+IFR+MS-WOCA,
4900 -MWD, 4900-MWD+IFR+MS-WOCA
Rule Assigned: Major Risk
Offset Well Error. 0.00 usft
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
offset
Toofface +
Offset Wellbore Centre
Casing -
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+NIS
+EI -W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(I
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
13,707.59
6,681.74
12,200.00
5,523.95
61.17
59.28
-135.65
154.89
-10,060.70
5.625
1,227.72
340.10
1,097.12 Pass - Major Risk
13,714.00
6,681.23
12,225.00
5,533.41
61.21
59.43
-134.14
165.74
-10,081.14
5.625
1,211.79
343.04
1,082.60 Pass - Major Risk
13,714.00
6,681.23
12,250.00
5,542.87
61.21
59.58
-133.45
176.59
-10,101.58
5.625
1,196.13
343.35
1,069.32 Pass - Major Risk
13,725.00
6,680.50
12,275.00
5,552.33
61.28
59.72
-132.73
187.44
-10,122.02
5.625
1,180.74
343.53
1,052.77 Pass - Major Risk
13,725.00
6,680.50
12,300.00
5,561.78
61.28
59.87
-132.00
198.28
-10,142.46
5.625
1,165.61
343.84
1,040.10 Pass - Major Risk
13,725.00
6,680.50
12,325.00
5,571.24
61.28
60.02
-131.24
209.13
-10,162.91
5.625
1,150.84
344.15
1,027.76 Pass - Major Risk
13,725.00
6,680.50
12,350.00
5,580.70
61.28
60.17
-130.47
219.98
-10,183.35
5.625
1,136.42
344.45
1,015.75 Pass - Major Risk
13,737.34
6,679.97
12,375.00
5,590.16
61.37
60.32
-129.67
230.83
-10,203.79
5.625
1,122.15
345.14
1,000.15 Pass - Major Risk
13,750.00
6,679.76
12,400.00
5,599.61
61.46
60.47
-128.85
241.68
-10,224.23
5.625
1,108.42
345.84
985.04 Pass - Major Risk
13,750.00
6,679.76
12,425.00
5,609.07
61.46
60.62
-128.01
252.52
-10,244.67
5.625
1,094.85
346.15
973.98 Pass - Major Risk
13,750.00
6,679.76
12,450.00
5,618.53
61.46
60.77
-127.14
263.37
-10,265.12
5.625
1,081.69
346.46
963.25 Pass - Major Risk
13,750.00
6,679.76
12,475.00
5,627.99
61.46
60.92
-126.26
274.22
-10,285.56
5.625
1,068.95
346.76
952.84 Pass- Major Risk
13,750.00
6,679.76
12,500.00
5,637.44
61.46
61.07
-125.35
285.07
-10,306.00
5.625
1,056.65
347.07
942.74 Pass - Major Risk
13,762.64
6,679.88
12,525.00
5,646.90
61.55
61.22
-124.42
295.91
-10,326.44
5.625
1,044.56
347.77
929.59 Pass- Major Risk
13,775.00
6,680.33
12,550.00
5,656.36
61.63
61.37
-123.47
306.76
-10,346.88
5.625
1,033.08
348.47
917.18 Pass - Major Risk
13,775.00
6,680.33
12,575.00
5,665.82
61.63
61.52
-122.49
317.61
-10,367.33
5.625
1,021.84
348.77
908.06 Pass- Major Risk
13,775.00
6,680.33
12,600.00
5,675.27
61.63
61.67
-121.49
328.46
-10,387.77
5.625
1,011.10
349.08
899.20 Pass - Major Risk
13,775.00
6,680.33
12,625.00
5,684.73
61.63
61.82
-120.48
339.31
-10,408.21
5.625
1,000.86
349.39
890.58 Pass - Major Risk
13,785.18
6,680.94
12,650.00
5,694.19
61.71
61.97
-119.44
350.15
-10,428.65
5.625
991.00
350.02
880.30 Pass - Major Risk
13,789.84
6,681.29
12,675.00
5,703.65
61.74
62.12
-118.37
361.00
-10,449.09
5.625
981.65
350.47
871.46 Pass - Major Risk
13,800.00
6,682.21
12,700.00
5,713.10
61.81
62.27
-117.29
371.85
-10,469.54
5.625
972.83
351.10
862.21 Pass - Major Risk
13,800.00
6,682.21
12,725.00
5,722.56
61.81
62.43
-116.19
382.70
-10,489.98
5.625
964.41
351.41
854.67 Pass - Major Risk
13,800.00
6,682.21
12,750.00
5,732.02
61.81
62.58
-115.08
393.55
-10,510.42
5.625
956.57
351.72
847.28 Pass - Major Risk
13,809.05
6,683.21
12,775.00
5,741.48
61.88
62.73
-113.94
404.39
-10,530.86
5.625
949.20
352.31
839.32 Pass - Major Risk
13,813.99
6,683.83
12,800.00
5,750.93
61.91
62.88
-112.79
415.24
-10,551.30
5.625
942.39
352.78
832.08 Pass - Major Risk
13,825.00
6,685.39
12,825.00
5,760.39
61.99
63.03
-111.61
426.09
-10,571.75
5.625
936.17
353.43
825.05 Pass - Major Risk
13,825.00
6,685.39
12,850.00
5,769.85
61.99
63.18
-110.43
436.94
-10,592.19
5.625
930.39
353.74
818.57 Pass - Major Risk
13,829.11
6,686.04
12,875.00
5,779.31
62.02
63.34
-109.24
447.79
-10,612.63
5.625
925.22
354.18
812.30 Pass - Major Risk
13,837.97
6,687.51
12,900.00
5,788.77
62.08
63.49
-108.63
458.63
-10,633.07
5.625
920.61
352.21
806.25 Pass - Major Risk
13,850.00
6,689.50
12,925.00
5,798.22
62.17
63.64
-108.60
469.48
-10,653.52
5.625
916.47
347.57
800.11 Pass- Major Risk
13,862.97
6,691.62
12,950.00
5,807.68
62.25
63.79
-108.64
480.33
-10,673.96
5.625
912.79
342.33
794.03 Pass - Major Risk
13,875.00
6,693.55
12,975.00
5,817.14
62.34
63.94
-108.55
491.18
-10,694.40
5.625
909.61
337.27
788.10 Pass - Major Risk
13,884.64
6,695.07
13,000.00
5,826.60
62.40
64.10
-108.20
502.02
-10,714.84
5.625
906.95
333.13
782.35 Pass - Major Risk
13,894.40
6,696.60
13,025.00
5,836.05
62.47
64.25
-107.83
512.87
-10,735.28
5.625
904.83
328.81
776.90 Pass - Major Risk
13,903.53
6,698.00
13,050.00
5,845.51
62.53
64.40
-107.39
523.72
-10,755.73
5.625
903.27
324.66
771.82 Pass - Major Risk
13,912.07
6,699.30
13,075.00
5,854.97
62.58
64.55
-106.86
534.57
-10,776.17
5.625
902.28
320.70
767.16 Pass - Major Risk
13,920.09
6,700.50
13,100.00
5,864.43
62.63
64.71
-106.27
545.42
-10,796.61
5.625
901.88
316.98
762.97 Pass - Major Risk, CC
13,925.00
6,701.23
13,125.00
5,873.88
62.66
64.86
-105.35
556.26
-10,817.05
5.625
902.08
314.75
759.12 Pass - Major Risk
13,934.70
6,702.65
13,150.00
5,883.34
62.72
65.01
-104.91
567.11
-10,837.49
5.625
902.87
310.01
756.23 Pass - Major Risk
13,941.36
6,703.62
13,175.00
5,892.80
62.76
65.17
-104.16
577.96
-10,857.94
5.625
904.27
306.75
753.75 Pass - Major Risk
13,950.00
5,704.85
13,200.00
5,902.26
62.82
65.32
-103.61
588.81
-10,878.38
5.625
906.30
302.38
752.20 Pass - Major Risk
13,950.00
6,704.85
13,225.00
5,911.71
62.82
65.47
-102.17
599.66
-10,898.82
5.625
908.95
302.60
750.26 Pass - Major Risk
13,959.20
6,706.14
13,250.00
5,921.17
62.87
65.63
-101.68
610.50
-10,919.26
5.625
912.19
297.80
750.23 Pass - Major Risk
13,964.52
6,706.88
13,275.00
5,930.63
62.90
65.78
-100.80
621.35
-10,939.70
5.625
916.06
295.07
750.42 Pass - Major Risk
13,970.00
6,707.63
13,300.00
5,940.09
62.94
65.93
-99.94
632.20
-10,960.15
5.625
920.54
292.20
751.40 Pass - Major Risk
13,975.00
6,708.30
13,325.00
5,949.54
62.97
66.09
-99.03
643.05
-10,980.59
5.625
925.62
289.58
752.78 Pass - Major Risk
13,980.10
6,708.98
13,350.00
5,959.00
62.99
66.24
-98.14
653.90
-11,001.03
5.625
931.30
286.87
754.92 Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
121812015 10:04:55PM Page 3 COMPASS 5000.1 Build 61
I&V
BAKER
HUGHES
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Offset Design
PBS Pad - Plan S-137- Plan S-137- Plan #7 S-137
BP
Travelling Cylinder Report
Company:
North America - ALASKA - BP
Local Co-ordinate Reference
Project:
Prudhoe Bay
TVD Reference:
Reference Site:
PB S Pad
MD Reference:
Site Error:
0.00 usft
North Reference:
Reference Well:
S-113
Survey Calculation Method:
Well Error:
0.00 usft
Output errors are at
Reference Wellbore
S-113BL1
Database:
Reference Design:
S-113BL1 WP12
Offset TVD Reference:
I&V
BAKER
HUGHES
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Offset Design
PBS Pad - Plan S-137- Plan S-137- Plan #7 S-137
Offset Site Error. 0.00 usft
Survey Program:
47-GYD-GC-SS,
1000 -MWD,
1000-MWD+IFR+MS-WOCA,
4900 -MWD, 4900-MWD+IFR+MS-WOCA
Rule Assigned: Major Risk
Offset Well Error: 0.00 usft
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toofface+
Offset Wellbore
Centre
Casing-
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+NIS
+E/ -W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(I
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
13,984.96
6,709.60
13,375.00
5,968.46
63.02
66.40
-97.24
664.74
-11,021.47
5.625
937.57
284.26
757.80 Pass - Major Risk
13,989.54
6,710.19
13,400.00
5,977.92
63.05
66.55
-96.32
675.59
-11,041.91
5.625
944.41
281.78
761.40 Pass - Major Risk
13,993.88
6,710.73
13,425.00
5,987.37
63.07
66.70
-95.40
686.44
-11,062.36
5.625
951.83
279.42
765.72 Pass - Major Risk
14,000.00
6,711.47
13,450.00
5,996.83
63.10
66.86
-94.69
697.29
-11,082.80
5.625
959.81
275.99
771.17 Pass - Major Risk
14,000.00
6,711.47
13,475.00
6,006.29
63.10
67.01
-93.36
708.14
-11,103.24
5.625
968.34
276.16
776.04 Pass - Major Risk
14,000.00
6,711.47
13,500.00
6,015.75
63.10
67.17
-92.06
718.98
-11,123.68
5.625
977.42
276.33
781.56 Pass - Major Risk
14,009.12
6,712.54
13,525.00
6,025.20
63.15
67.32
-91.71
729.83
-11,144.12
5.625
986.98
271.17
789.94 Pass - Major Risk
14,012.47
6,712.92
13,550.00
6,034.66
63.17
67.48
-90.80
740.68
-11,164.57
5.625
997.07
269.36
797.67 Pass - Major Risk
14,015.67
6,713.28
13,575.00
6,044.12
63.19
67.63
-89.89
751.53
-11,185.01
5.625
1,007.67
267.62
806.04 Pass - Major Risk
14,025.00
6,714.29
13,600.00
6,053.58
63.24
67.79
-89.65
762.37
-11,205.45
5.625
1,018.79
262.20
816.95 Pass- Major Risk
14,025.00
6,714.29
13,625.00
6,063.03
63.24
67.94
-88.46
773.22
-11,225.89
5.625
1,030.30
262.35
825.69 Pass - Major Risk
14,025.00
6,714.29
13,650.00
6,072.49
63.24
68.10
-87.30
784.07
-11,246.33
5.625
1,042.29
262.50
835.01 Pass - Major Risk
14,025.00
6,714.29
13,675.00
6,081.95
63.24
68.25
-86.16
794.92
-11,266.78
5.625
1,054.73
262.65
844.89 Pass- Major Risk
14,691.12
6,719.01
13,700.00
6,091.41
68.13
68.41
-52.66
805.77
-11,287.22
5.625
1,064.50
421.69
705.71 Pass - Major Risk, ES, SF
14,700.00
6,717.89
13,725.00
6,100.86
68.21
68.56
-52.65
816.61
-11,307.66
5.625
1,070.93
420.10
709.14 Pass - Major Risk
14,708.02
6,716.81
13,750.00
6,110.32
68.29
68.72
-52.55
827.46
-11,328.10
5.625
1,077.78
418.89
713.13 Pass - Major Risk
14,715.88
6,715.67
13,775.00
6,119.85
68.36
68.87
-52.44
838.30
-11,348.52
5.625
1,085.01
417.76
717.69 Pass - Major Risk
14,725.00
6,714.27
13,800.00
6,129.74
68.45
69.01
-52.48
849.06
-11,368.80
5.625
1,092.37
416.30
722.71 Pass - Major Risk
14,725.00
6,714.27
13,825.00
6,140.04
68.45
69.14
-51.45
859.74
-11,388.92
5.625
1,099.88
416.61
727.10 Pass - Major Risk
14,725.00
6,714.27
13,850.00
6,150.73
68.45
69.27
-50.42
870.33
-11,408.88
5.625
1,107.59
416.91
731.80 Pass - Major Risk
14,736.41
6,712.47
13,875.00
6,161.81
68.56
69.41
-50.96
880.84
-11,428.68
5.625
1,115.30
413.71
740.01 Pass - Major Risk
14,740.30
6,711.88
13,900.00
6,173.28
68.59
69.54
-50.47
891.25
-11,448.30
5.625
1,123.25
412.76
746.38 Pass - Major Risk
14,750.00
6,710.41
13,925.00
6,185.14
68.69
69.66
-50.76
901.57
-11,467.74
5.625
1,131.39
409.83
755.02 Pass - Major Risk
14,750.00
6,710.41
13,950.00
6,197.38
68.69
69.79
-49.74
911.79
-11,486.99
5.625
1,139.58
410.11
760.68 Pass - Major Risk
14,750.00
6,710.41
13,975.00
6,210.00
68.69
69.91
-48.71
921.91
-11,506.05
5.625
1,147.96
410.39
766.63 Pass - Major Risk
14,750.00
6,710.41
14,000.00
6,222.99
68.69
70.04
-47.69
931.93
-11,524.92
5.625
1,156.50
410.67
772.86 Pass - Major Risk
14,750.00
6,710.41
14,025.00
6,236.35
68.69
70.16
-46.67
941.84
-11,543.58
5.625
1,165.21
410.94
779.37 Pass - Major Risk
14,761.10
6,708.79
14,050.00
6,250.08
68.79
70.28
-47.16
951.64
-11,562.03
5.625
1,173.91
407.31
789.88 Pass - Major Risk
14,764.18
6,708.35
14,075.00
6,264.18
68.82
70.40
-46.56
961.32
-11,580.26
5.625
1,182.82
406.45
797.96 Pass - Major Risk
14,775.00
6,706.84
14,100.00
6,278.63
68.91
70.52
47.01
970.89
-11,598.28
5.625
1,191.95
402.66
809.31 Pass - Major Risk
14,775.00
6,706.84
14,125.00
6,293.44
68.91
70.63
-46.01
980.34
-11,616.07
5.625
1,201.05
402.90
816.72 Pass - Major Risk
14,775.00
6,706.84
14,150.00
6,308.59
68.91
70.74
-45.00
989.66
-11,633.63
5.625
1,210.30
403.14
824.37 Pass - Major Risk
14,775.00
6,706.84
14,175.00
6,324.09
68.91
70.85
-44.01
998.87
-11,650.95
5.625
1,219.69
403.38
832.27 Pass - Major Risk
14,775.00
6,706.84
14,200.00
6,339.93
68.91
70.96
-43.01
1,007.94
-11,668.04
5.625
1,229.21
403.61
840.41 Pass - Major Risk
14,775.00
6,706.84
14,225.00
6,356.10
68.91
71.06
-42.02
1,016.88
-11,684.87
5.625
1,238.85
403.83
848.80 Pass - Major Risk
14,775.00
6,706.84
14,250.00
6,372.61
68.91
71.17
41.04
1,025.69
-11,701.45
5.625
1,248.61
404.05
857.41 Pass - Major Risk
14,785.25
6,705.46
14,275.00
6,389.44
69.01
71.27
-41.43
1,034.37
-11,717.78
5.625
1,258.33
400.23
870.19 Pass - Major Risk
14,787.48
6,705.17
14,300.00
6,406.59
69.03
71.37
40.76
1,042.90
-11,733.84
5.625
1,268.24
399.55
880.08 Pass - Major Risk
14,789.62
6,704.89
14,325.00
6,424.05
69.05
71.46
-40.08
1,051.30
-11,749.63
5.625
1,278.25
398.87
890.16 Pass - Major Risk
14,800.00
6,703.56
14,350.00
6,441.83
69.14
71.56
-40.49
1,059.55
-11,765.16
5.625
1,288.44
394.73
904.03 Pass - Major Risk
14,800.00
6,703.56
14,375.00
6,459.90
69.14
71.65
-39.53
1,067.65
-11,780.41
5.625
1,298.57
394.92
913.55 Pass - Major Risk
14,800.00
6,703.56
14,400.00
6,478.28
69.14
71.74
-38.58
1,075.61
-11,795.37
5.625
1,308.80
395.11
923.26 Pass - Major Risk
14,800.00
6,703.56
14,425.00
6,496.95
69.14
71.83
-37.63
1,083.41
-11,810.05
5.625
1,319.12
395.29
933.17 Pass - Major Risk
14,800.00
6,703.56
14,450.00
6,515.91
69.14
71.91
-36.69
1,091.06
-11,824.44
5.625
1,329.51
395.46
943.25 Pass - Major Risk
14,800.00
6,703.56
14,475.00
6,535.06
69.14
72.00
-35.76
1,098.61
-11,838.64
5.625
1,340.09
395.65
953.59 Pass - Major Risk
14,802.50
6,703.25
14,500.00
6,554.21
69.16
72.10
-35.17
1,106.15
-11,852.82
5.625
1,351.03
394.77
965.46 Pass - Major Risk
14,805.00
6,702.94
14,525.00
6,573.36
69.18
72.20
-34.60
1,113.70
-11,867.01
5.625
1,362.34
393.90
977.77 Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/6/2015 10:04:55PM Page 4 COMPASS 5000.1 Build 61
BP F /.rI
by 0 Travelling Cylinder Report BAKER
HUGHES
Company: North America - ALASKA - BP
Project: Prudhoe Bay
Reference Site: PB S Pad
Site Error:
0.00 usft
Reference Well:
S-113
Well Error:
0.00 usft
Reference Wellbore
S-113BL1
Reference Design:
S-113BL1 WP12
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K-Alaska PROD -ANCP1
Offset Datum
Offset Design
PBS Pad
- Plan
S-137- Plan S-137-
Plan
#7
S-137
Offset Site Error, 0.00 use
Survey Program: 47-GYD-GC-SS, 1000
-MWD,
1000-MWD+IFR+MS-WOCA, 4900.MWD, 4900-MWD+IFR+MSWOCA
Rule Assigned: Major Risk
Offset Well Error, 0.00 use
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toofface +
Offset Wellbore Contra
Casing -
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+NIS
+EI -W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(`)
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
14,807.50
6,702.63
14,550.00
6,592.51
69.20
72.31
-33.71
1,121.24
-11,881.20
5.625
1,374.00
394.00
989.42 Pass - Major Risk
14,812.89
6,702.03
14,575.00
6,611.66
69.25
72.41
-32.84
1,128.79
-11,895.39
5.625
1,385.99
393.97
1,001.45 Pass - Major Risk
14,818.67
6,701.45
14,600.00
6,630.81
69.30
72.52
-31.99
1,136.33
-11,909.58
5.625
1,398.30
393.91
1,013.78 Pass - Major Risk
14,825.00
6,700.89
14,625.00
6,649.96
69.36
72.62
-31.16
1,143.88
-11,923.77
5.625
1,410.91
393.83
1,026.40 Pass - Major Risk
14,831.59
6,700.40
14,650.00
6,669.11
69.42
72.73
-30.35
1,151.42
-11,937.96
5.625
1,423.82
393.95
1,039.28 Pass - Major Risk
14,838.83
6,699.96
14,675.00
6,688.26
69.48
72.83
-29.55
1,158.96
-11,952.14
5.625
1,437.02
394.44
1,052.39 Pass - Major Risk
14,846.67
6,699.62
14,700.00
6,707.42
69.55
72.94
-28.78
1,166.51
-11,966.33
5.625
1,450.48
394.95
1,065.72 Pass - Major Risk
14,855.00
6,699.39
14,725.00
6,726.57
69.63
73.04
-28.02
1,174.05
-11,980.52
5.625
1,464.20
395.48
1,079.23 Pass - Major Risk
14,855.00
6,699.39
14,750.00
6,745.72
69.63
73.15
-27.28
1,181.60
-11,994.71
5.625
1,478.19
395.70
1,093.36 Pass - Major Risk
14,855.00
6,699.39
14,775.00
6,764.87
69.63
73.26
-26.56
1,189.14
-12,008.90
5.625
1,492.48
395.92
1,107.83 Pass - Major Risk
14,855.00
6,699.39
14,800.00
6,784.02
69.63
73.36
-25.85
1,196.69
-12,023.09
5.625
1,507.04
396.14
1,122.62 Pass - Major Risk
14,863.14
6,699.24
14,825.00
6,803.17
69.70
73.47
-26.14
1,204.23
-12,037.26
5.625
1,521.78
392.63
1,141.34 Pass- Major Risk
14,865.10
6,699.21
14,850.00
6,822.32
69.72
73.57
-25.69
1,211.77
-12,051.46
5.625
1,536.83
391.93
1,157.61 Pass - Major Risk
14,867.04
6,699.18
14,875.00
6,841.47
69.73
73.68
-25.26
1,219.32
-12,065.65
5.625
1,552.12
391.24
1,174.15 Pass - Major Risk
14,875.00
6,699.06
14,900.00
6,860.62
69.81
73.79
-25.57
1,226.86
-12,079.84
5.625
1,567.70
387.65
1,193.86 Pass - Major Risk
14,875.00
6,699.06
14,925.00
6,879.78
69.81
73.89
-24.93
1,234.41
-12,094.03
5.625
1,583.44
387.87
1,210.00 Pass- Major Risk
14,875.00
6,699.06
14,950.00
6,898.93
69.81
74.00
-24.30
1,241.95
-12,108.22
5.625
1,599.42
388.08
1,226.41 Pass - Major Risk
14,875.00
6,699.06
14,957.93
6,905.00
69.81
74.03
-24.10
1,244.34
-12,112.72
5.625
1,604.53
388.14
1,231.67 Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/8/2015 10:04:55PM Page 5 COMPASS 5000.1 Build 61
0 by
PB S Pad - S-113 - S -113B - S-1138
BP
Travelling Cylinder Report
Company:
North America - ALASKA - BP
Local Co-ordinate Reference:
Project:
Prudhoe Bay
TVD Reference:
Reference Site:
PB S Pad
MD Reference:
Site Error:
0.00 usft
North Reference:
Reference Well:
S-113
Survey Calculation Method:
Well Error:
0.00 usft
Output errors are at
Reference Wellbore
S-11381-1
Database:
Reference Design:
S-113BL1 WP12
Offset TVD Reference:
'Ab
BAKER
HUGHES
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Offset Design
PB S Pad - S-113 - S -113B - S-1138
Offset Site Error 0.00 usft
Survey Program: 132-C&GYRO-SS, 941-MWD+IFR+MS-WOCA,
9700-MWD+IFR+MS-WOCA
Rule Assigned: NOERRORS
Offset Well Error: 0.00 usft
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toofface+
Onset Wellbore Centre
Casing-
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+NIS
+E/ -W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(I
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
12,900.00
6,572.65
12,900.00
6,572.65
0.01
0.01
-112.95
829.64
-9,761.50
5.625
0.00
0.53
-0.47 FAIL-NOERRORS
12,925.00
6,594.80
12,925.00
6,594.80
0.09
0.04
-113.16
825.09
-9,772.18
5.625
0.00
0.55
-0.47 FAIL-NOERRORS
12,950.00
6,617.01
12,950.00
6,617.01
0.16
0.07
-113.38
820.56
-9,782.71
5.625
0.00
0.57
-0.47 FAIL-NOERRORS
12,975.00
6,639.30
12,975.00
6,639.30
0.23
0.10
-113.60
816.05
-9,793.10
5.625
0.00
0.59
-0.47 FAIL - NOERRORS, CC
13,000.00
6,661.65
13,000.00
6,661.65
0.30
0.13
86.25
811.55
-9,803.35
5.625
0.00
0.61
-0.56 FAIL-NOERRORS
13,025.00
6,684.00
13;025.00
6,684.00
0.38
0.16
86.39
806.99
-9,813.59
5.625
0.00
0.63
-0.56 FAIL- NOERRORS, ES, SF
13,050.00
6,706.22
13,050.00
6,706.33
0.45
0.19
69.62
802.36
-9,823.84
5.625
0.22
0.65
-0.30 FAIL-NOERRORS
13,074.73
6,727.22
13,075.00
6,728.64
0.53
0.22
67.78
797.66
-9,834.10
5.625
2.41
0.68
1.91 Pass-NOERRORS
13,098.32
6,745.20
13,100.00
6,750.92
0.63
0.24
67.18
792.90
-9,844.38
5.625
8.18
0.72
7.71 Pass-NOERRORS
13,120.00
6,759.65
13,125.00
6,773.19
0.74
0.27
66.85
788.11
-9,854.69
5.625
17.21
0.77
16.75 Pass-NOERRORS
13,140.00
6,770.98
13,150.00
6,795.43
0.85
0.29
66.64
783.32
-9,865.04
5.625
29.05
0.84
28.59 Pass-NOERRORS
13,156.19
6,778.63
13,175.00
6,817.66
0.95
0.32
66.52
778.50
-9,875.43
5.625
43.19
0.90
42.73 Pass-NOERRORS
13,170.00
6,784.01
13,200.00
6,839.87
1.03
0.35
66.43
773.67
-9,885.84
5.625
59.25
0.97
58.78 Pass - NOERRORS
13,183.36
6,788.18
13,225.00
6,862.10
1.12
0.37
66.38
768.85
-9,896.21
5.625
76.84
1.03
76.37 Pass-NOERRORS
13,194.14
6,790.78
13,250.00
6,884.34
1.19
0.40
66.34
764.02
-9,906.56
5.625
95.68
1.10
95.21 Pass-NOERRORS
13,203.00
6,792.40
13,275.00
6,906.60
1.25
0.43
66.32
759.21
-9,916.87
5.625
115.51
1.16
115.04 Pass-NOERRORS
13,210.00
6,793.35
13,300.00
6,928.87
1.30
0.46
66.30
754.39
-9,927.15
5.625
136.15
1.21
135.68 Pass-NOERRORS
13,220.00
6,794.18
13,325.00
6,951.16
1.37
0.49
66.30
749.57
-9,937.39
5.625
157.42
1.29
156.95 Pass-NOERRORS
13,224.38
6,794.35
13,350.00
6,973.47
1.40
0.52
66.30
744.74
-9,947.59
5.625
179.19
1.34
178.72 Pass - NOERRORS
13,230.00
6,794.40
13,375.00
6,995.80
1.44
0.55
66.30
739.92
-9,957.75
5.625
201.41
1.40
200.94 Pass-NOERRORS
13,234.35
6,794.31
13,400.00
7,018.15
1.47
0.59
66.30
735.13
-9,967.88
5.625
223.98
1.45
223.51 Pass-NOERRORS
13,240.00
6,794.01
13,425.00
7,040.52
1.51
0.62
66.28
730.41
-9,978.00
5.625
246.87
1.51
246.40 Pass - NOERRORS
13,240.00
6,794.01
13,450.00
7,062.91
1.51
0.64
66.26
725.76
-9,988.09
5.625
270.01
1.23
269.35 Pass-NOERRORS
13,245.48
6,793.54
13,475.00
7,085.31
1.55
0.66
66.23
721.12
-9,996.18
5.625
293.32
4.98
288.40 Pass-NOERRORS
13,250.00
6,793.02
13,500.00
7,107.71
1.58
0.68
66.21
716.49
-10,008.27
5.625
316.83
9.26
307.57 Pass-NOERRORS
13,250.00
6,793.02
13,515.00
7,121.15
1.58
0.69
66.2D
713.71
-10,014.33
5.625
330.99
11.83
319.15 Pass - NOERRORS
CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/6/2015 10.04:55PM Page 6 COMPASS 5000.1 Build 61
bp Travelling Cylinder Report BAKER
HUGHES
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Reference Site:
PB S Pad
Site Error:
0.00 usft
Reference Well:
S-113
Well Error:
0.00 usft
Reference Wellbore
S-113BL1
Reference Design:
S-113BL1 WP12
Local Co-ordinate Reference
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset ND Reference:
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Reference Depths are relative to Kelly Bushing / Rotary Table @ 70.33 Coordinates are relative to: S-113
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04
Central Meridian is 150° 0'0.000 W Grid Convergence at Surface is: 0.91 °
CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation
12/8/2015 10:04:55PM Page 7 COMPASS 5000.1 Build 61
Ladder Plot
I I I
I
1600
I
I
I I
I
I
I II
l
1200
0
m
a
W
U)
m
G2
800
U
0
c
a�
U
400
0
0 2500
5000 7500 10000 12500
15000
Measured Depth
LEGEND
- S-113, S-1136, S -113B V6
Plan S-137, Plan S-137, Plan #7 S-137 V0
CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation
12/8/2015 10:04:55PM Page 7 COMPASS 5000.1 Build 61
I I I
I
I I
I
I
I I
I
I
I II
l
CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation
12/8/2015 10:04:55PM Page 7 COMPASS 5000.1 Build 61
°° F31 RG
°'w Travelling Cylinder Report BAKER
HUGHES
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Reference Site:
PB S Pad
Site Error:
0.00 usft
Reference Well:
S-113
Well Error:
0.00 usft
Reference Wellbore
S-113BL1
Reference Design:
S-113BL1 WP12
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method
Output errors are at
Database:
Offset ND Reference:
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K-Alaska PROD -ANCP1
Offset Datum
Reference Depths are relative to Kelly Bushing / Rotary Table @ 70.33 Coordinates are relative to: 5-113
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04
Central Meridian is 1501 0' 0.000 W Grid Convergence at Surface is: 0.91 °
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/8/2015 10:04:55PM Page 8 COMPASS 5000.1 Build 61
BP
b ri.2
-0"Or Travelling Cylinder Report BAKER
HUGHES
Company:
North America - ALASKA - BP
Project:
Prudhoe Bay
Reference Site:
PB S Pad
Site Error:
0.00 usft
Reference Well:
S-113
Well Error:
0.00 usft
Reference Wellbore
S-113BL1
Reference Design:
S-113BL1 WP12
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well S-113
Mean Sea Level
Kelly Bushing / Rotary Table @ 70.33usft
(DOYON 14)
True
Minimum Curvature
1.00 sigma
EDM R5K - Alaska PROD - ANCP1
Offset Datum
Reference Depths are relative to Kelly Bushing / Rotary Table @ 70.33 Coordinates are relative to: S-113
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04
Central Meridian is 150° 0'0.000 W Grid Convergence at Surface is: 0.91 °
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/8/2015 10.04 55PM Page 9
COMPASS 5000.1 Build 61
CoFlex Hose
NORDIC-CALISTA RIG 1 CHOKE / REEL/CIRCULATION
MANIFOLD DIAGRAM
e 7/232013
Udo Cassee
V12
V14
V20
40
V15
V11
Transducers
7-1116" 5000 psi GOP'. ID = 7.06"
POOR BOY
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V17 BOP 2
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BOP 1
BOP 3
BOP 4
V4 5
V7
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BOP 5
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OTiger
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PS 2
Reverse Circulating line / CT
CoFlex Hose
TRANSMITTAL LETTER CHECKLIST
WELL NAME:
PTD: 2 ZI
/Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional
FIELD: �G�G POOL:G
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing ell Permit
r'
LATERAL
No. '- API No. 50 �-
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69)
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50---
50--
) from records, data and logs acquired for well
-___)
(name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within Q(1,4-- after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150
Well Name: PRUDHOE BAY UN AURO S-113BL1 Program DEV Well bore seg
PTD#: 2152180 Company
BP EXPLORATION (ALASKA) INC Initial Class/Type
DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal
Administration
17
Nonconven, gas conforms to A$31.05.030Q.1_.A),(j.2.A-D) - - _ .
NA_ -
- - - - - - - - - - - - - --- - - -
&_,,�
1
Permit fee attached - - -
NA- - .
- - - - - - - - - - - - - - - -- - -- - - - . - - . - - - -
2
Lease number appropriate- - - - - - - -
_ Yes - -
- - _ _ _ Surface Location lies within_ADL0028257, Top Productive Interval lies- in ADL00282-58;_ -
3
Unique well name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - -
Yes -
- - - _ _ TD Lies in ADL0028259----------------------- - - . - - - . - - - - - -
4
Well located in_ a_defined_pool . - - - - - - - - - - - - -
- Yes
- - _ PRUDHOE BAY, AURORA_OIL - 64.0120, governed b CO 457 -B ---Corrected_
--- g- y -
5
Well located proper distance_ from drilling unit- boundary ----------- - - - - - -
Yes -
- - - _ - Rule 1: "Spacing units within the -pool shall -be a_minimum of 40 acres._ 20_AAC 25.055(a)(1)- -
6
Well -located proper distance_ from other wells- - - - - -
Yes
- and -(2) -shall- not apply to property lines _within the external boundaries of the Aurora -
7
Sufficient acreage -available in-d_ril_ling unit_ - - _
- Yes --
_ - _ _ Participating_ Area." _ _ - - - - - - - - _ - . - . . - - - -
8
If -deviated, is -wellbore plat_included - - - - - - - - - - - - - - - - -
- Yes - -
- - - - _ Received requested digital direct_ional_survey data. _SFD_1/4/20.16 . .
9
Operator onlyaff_ectedparty- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
10
Operator has -appropriate- bond in force - - - - - - - - - - - _ .
Yes -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . .
Appr Date
11
Permit can be issued without conservation order_ - - - - - - - - .
Yes -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - -
12
Permit -can be issued_without ad ministrativ_e_approval - - - - - - - - - - - - - - - - - - - - - - -
Yes _
---- - - - - - - - -
SFD 1/4/2016
13
Canpermitbeapprovedbefore 15-daywait- - _ _ - _ _ - _ - - - - - - - -
- Yes - -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - . - - - - -
14
Well located within area and -strata authorized by_ Injection Order # (put_ 1O# in -comments)_ (For_: _NA_
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - _ - - -
15
All wells -within -1/4 -mile area_of review identified (For service well only) - - - - ..
NA_ -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - .
16
Pre -produced injector: duration -of pre production less than_ 3 months- (For -service well only) _
- NA- - _
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
18
Conductor string_ provided - - - --------- ----- ----- --- --
- NA-_____-_Con_ductorset_in
PBU S-113_______-___________
Engineering
19
Surface casing_ protects all -known USDWs - - - - - - - - - - - - - -
NA_
- - - - - Surface casing set in PBU S-113 _ _ - - - _ _ - -- - - - - - - - - - - - - - - - - - -
20
CMT-v_ol adequate to circulate -on conductor & surf_csg - - - - - _ - - -
NA_
- - - Surf -ace casing set and fully_ cemented - - - - - - - - - - - - - - - - - - - - - - - - - - - --
-21
21
CMT_v_ol adequate to tie-in long string to -surf csg_ _ _ - - - - - - - - - - - - - - _
_ _N_A- --
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
22
CMT_will coverall known_productive horizons - - _ _ - - - - - -
N_o- - -
- - - - - Productive interval will -be completed with uncemented slotted liner_ - - - - - - - - -
23
Casing designs adequate for CJ, B &_ permafrost ------------ - - - - -- - - - - - -
- Yes _ -
- - - - - - - _ - _ _ - - - - - - - - - - - - - - - - - - - - . - - - --
24
Adequate -tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - _ _ Rig has steel tanks, all_waste_to approved disposal wells_ - _ - - - - - - - - - - _ - . - . - - - . - - - - - -
25
If_a_ re- drill_, has_ a 107403 for abandonment been approved - - - - - - - - - - - - - - - - - - - - -
NA_ - -
- - _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - _ - - - - -
26
Adequate wellbore separation _proposed _ _ - _
Yes -
- - - _ Anti -collision analysis complete; no major risk failures - - - - - - - - - - - - - - - - - - -
27
If-diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - -
NA_
- - - _ _ _ _ _ _ _ - _ _ - - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Appr Date
28
Drilling fluid_ program schematic_& equip -list adequate- - - - - - - - - - - - - - - - - - - - - - - -
Yes - -
- - - - - Max formation_ pres_ is 3056_psig(8.7_ppg EMW);_will drill w/ 9.8 ppg EMW--------------
VTL 12/30/2015
29
BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - -
- Yes ...
- . - - - - - - - - - - - - - - - - _ - _ - - - - - - - . - - - - - - - - - - - - - - - - - . - - - - - - - _ - - -
30
_B-OPE_press rating appropriate; test to_(put psig in comments)- - - - - - - - - - - - - - - - - - -
- Yes - _
_ - - - - MPSP is 2380 psig; will test BOPs_to 3500_psig-----------------------
31
Choke_manifold complies w/API_ RP -53 (May 84)_ _ _ - - - - _ _ - - - - - - - - - - - - - -
- Yes
-- - - - - - - - - - - - - - - - - - - - - - - - - - -
32
Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - -
Yes - -
- - - _ _ - - _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - -
33
Js presence of 1-12S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - -
Yes - - -
- - - - H2S measures required - - - - - _ _ _ - - - - - - _ - - - - - - - - -
34
-Mechanical-conclition of wells within AOR verified (For sLervice well only) - - - - - - - - -
_ NA_ - .
- - - - - - -- - - ---- -- - - - - - - - - - - - - - - - - - - - - .. _ - - - - - - - - - - - -- - - -
35
Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - -
- No_ _ _ -
_ - _ _ PBU S -Pad wells are H2S--bearing. Per 20 AAC 25.065(b), H2S _measures -are required._ - - - - - - - - - - - -
Geology
36
Data_presented on potential overpressure zones _ - _ _ _ _ _ _ _ - - - - - - -
Yes _ _ -
_ _ - - Planned drilling mud_program (9.8_ppg)-appears_ adequatetocontrol_operator's forecast _ _ _ _ _ _ _
Appr Date
37
Seismic_analysis of shallow gas_zones-----------------------------------
N_A--------
pore pressure_gradient (about 8.7 ppg)._Should higher pore pressures be encountered,_ _ _ _ _ _
SFD 12/15/2015
38
Seabed condition survey -(if off_ -shore) - - - - - - - - - - - - - - - -
_ NA_ - - -
- _ - _ BP has- access to fluid -mixing facilities within_ the PBU ._ - _ - - _ -
39
Contact name/phone for weekly_ progress reports_ [exploratory only] - - - - - - - - - - - - - - - -
- NA_ - _ -
- _ _ _ - _ - - - - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - _ - - . - - - _ - - - _ - _ - - _ _ -
Geologic
Engineering
Public
Commissioner:
Date:
Commissione .
Date Commissioner Date
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