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212-092
7. 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-37A Reservoir Cement Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-092 50-029-22291-01-00 11583 Surface Intermediate Liner Liner Liner 8656 2890 9076 247 1485 1280 7861 10-3/4" 7-5/8" 5-1/2" 3-1/2" x 3-1/4" 2-3/8" 7592 33 - 2923 32 - 9108 8894 - 9141 8869 - 10354 10303 - 11583 33 - 2915 32 - 8643 8460 - 8672 8439 - 8677 8680 - 8656 None 2480 4790 6280 10530 11780 7861, 8734 5210 6890 7740 10160 11200 6812 - 6861 4-1/2" 12.6# 13Cr80 30 - 6751, 8670 - 8902 6711 - 6753 Conductor 75 20" 34 - 109 34 - 109 1490 470 4-1/2" HES TNT Packer 8837, 8412 6669, 8837 6587, 8412 Torin Roschinger Operations Manager Leslie Manning lreavis@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 30 - 6658, 8270 - 8467 7861' - 8283'MD Pump 15-bbls 15.8-ppg Class G Cement. Final pressure = 1400-psi Well Not Online Well Not Online 1700 1750 240 220 323-657 13b. Pools active after work:Aurora Oil 4-1/2" Baker S3 Packer 6669, 6587 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 No SSSV Installed By Grace Christianson at 11:18 am, May 15, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.05.15 07:58:58 -08'00' Torin Roschinger (4662) RBDMS JSB 051524 DSR-5/15/24WCB 8-29-2024 ACTIVITY DATE SUMMARY 3/19/2024 *** WELL SHUT IN ON ARRIVLE ****** BAILED FROM 6,630' SLM DOWN TO 6,658' SLM *** CONTINUE WSR ONTO 3/20/24 *** 3/20/2024 *** CONTINUED WSR FROM 3/19/24 *** BAILED DOWN TO 6,657' SLM PUMP 158 BBL OF HOT CRUDE BAILED DOWN TO 6,674' SLM (RECOVERED CEMENT SLURRY) *** CONTINUE WSR ONTO 3/21/24 *** 3/20/2024 T/I/O=1644/1655/4 (PLUG AND ABANDONMENT-RESERVOIR) Pumped 158 bbls 190* crude down the TBG to assist SL bailing. SL in control of well and pad op notified upon LRS departure. 3/21/2024 T/I/O=1100/1901/4 (PLUG AND ABANDONMENT-RESERVOIR) Pumped 57 bbls 190* Crude down TBG. SL in control of well and pad op notified upon LRS departure. 3/21/2024 *** CONTINUED WSR FROM 3/20/24 *** LRS PUMPED 57 BBL'S OF HOT CRUDE OIL. TOOLS PULLED FREE FROM 6,667' SLM. DISCUSSED PLAN FORWARD W/OE, RDMO HES SLICKLINE. ***WELL SHUT IN ON DEPARTURE*** 4/20/2024 LRS CTU #2: 2" 0.156 WT Objective: FCO, Pull rock screen, Reservoir P&A. MIRU LRS CTU #2 and support equipment. M/U & RIH w/Slim BHA - 2" JSN. Dry tagged 6,694' ctm. PUH and establish 1:1 returns. .......Job continued on 4/21/24 WSR 4/21/2024 LRS CTU #2: 2" 0.156 WT Objective: FCO, Pull rock screen, Reservoir P&A. Establish 1:1 returns. Wash down to rock screen 6,694' ctm. Consistent tags at 6,708' ctm. Reciprocate pipe 6,650' - 6,708' while jetting 2-3 bpm w/gel sweeps. Pooh w/BHA. FP coil w/60 bbls of diesel while Pooh. FP surface lines. Put 20 bbl Meoh cap on well, IA tracking tubing through the night. M/U & RIH w/YJ fishing BHA - 4" G- spear. Retrieved slotted rock screen from 6698' with no issue. Screen was clean for the most part. Had a couple small rocks in the lower slots. MU Slim 2" FCO BHA and RIH - 2" JSN. Tagged ~8266' ctm and begin fill cleanout taking 30' bites and chasing up hole w/gel sweeps. Cleanout down to 8,420' ctm. Pumped bottoms up and reciprocate pipe at 4-1/2" tubing tail while catching up with fluids due to limited Worley trucking support. LRS FP IA w/66 bbls of diesel. Continue FCO down to 8,450' ctm, pulled 15k - 20k over PUW from 8,450' up to 8,260' and weight broke over. ***Job Continued on 4/22/24 WSR*** 4/21/2024 T/I/O=1260/1495/0 Assist CTU #2. Freeze protect IA with 66 bbls of diesel capped with 3 bbls of 60/40. Final WHPS 1260/2425/0 4/22/2024 Travel from location to TFS shop. Daily Report of Well Operations PBU S-37A Daily Report of Well Operations PBU S-37A 4/22/2024 LRS CTU #2: 2" 0.156 WT Objective: FCO, Pull rock screen, Reservoir P&A. Continue FCO down to 8,450' ctm. Hang up 20 - 30k over PUW every bite. Work pipe and dragging up hole 8,379' - 8,312' and weight broke over. Lost fluid returns. PUH to 4-1/2" tubing tail and establish 1:1 returns. Dry tag fill 8,283' ctm. PUW clean 25k. Pooh to inspect BHA. FP coil w/60 bbls diesel. Discuss plan forward w/OE. AOGCC approval to lay cement plug from previous tag 8283'. RIH w/2" BDN BHA. Circulate coil and tubing to KCL before dry tag. Dry tag 8283', get wt back and paint flag 10' uphole. Nozzle became clogged right after tag. Unable to free it, POOH. On surface B/D BHA plugged w/cement, go to well and free up coil. RIH w/Cement BHA - 2" BDN, pumping min rate. Stop at flag 8,273' ctm. Pump cement as per pump schedule: 5 bbl FW spacer, 15 bbls of 15.8 ppg cement, FW spacer, and KCI displacement. With cement at nozzle, lay in cement in 7-5/8" casing 1:1 at 21.8 fpm from 8,273' - 7,947'. Pooh w/BHA pumping PD, maintain 1400 psi on WHP. .......Continued on 4/23/24 WSR. 4/23/2024 LRS CTU #2: 2" 0.156 WT Objective: FCO, Pull rock screen, Reservoir P&A. Pooh w/BHA pumping PD, maintain 1400 psi on WHP. Put meoh cap on well. Pumped 3/4" drift ball through 2" coil. Recovered ball. FP coil w/60 bbls of diesel. RIH and freeze protect tubing from 2500' to surface. Pooh w/BHA pumping diesel PD. RDMO LRS CTU #2. ***Job Completed*** 4/26/2024 T/I/O= 1600/1600/0 Displace IA to crude (P&A-Reservoir) Pumped 3 bbls 60/40 meth followed by 175 bbls crude down IA. Final WHPs 2550/1300/0 5/4/2024 ***WELL S/I ON ARRIVAL*** PERFORMED AOGCC WITNESS TAG TOC (BOB NOBLE), LOC. TT @ 6745' SLM/6751' MD (+6' correction), TAG TOC @ 7855' SLM/7861' MD ***END TICKET, DIFFERENT AFE FOR SBHPS ON SAME WELL*** 5/4/2024 ***WELL S/I ON ARRIVAL*** RAN SBHPS PER PROGRAM (good data, see log) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Cement was to be placed from 8670' up to 8520' (150' total). TOC as tagged at 7861', so there is over 800' cement. -WCB PERFORMED AOGCC WITNESS TAG TOC (BOB NOBLE), LOC. TT @ 6745'() SLM/6751' MD (+6' correction), TAG TOC @ 7855' SLM/7861' MD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:35 Township:12N Range:12E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:11583 ft MD Lease No.:ADL 028257 Operator Rep:Suspend:P&A:x Conductor:20"O.D. Shoe@ 109 Feet Csg Cut@ Feet Surface:10 3/4"O.D. Shoe@ 2923 Feet Csg Cut@ Feet Intermediate:7 5/8"O.D. Shoe@ 9108 Feet Csg Cut@ Feet Production:5 1/2"O.D. Shoe@ 9141 Feet Csg Cut@ Feet Liner:3 1/2" x 3 1/4"O.D. Shoe@ 10354 Feet Csg Cut@ Feet Tubing:2 3/8"O.D. Tail@ 11583 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Other 8734 ft 7861 ft 7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jerimiah Galloway Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Plug was founded on a existing cement plug. Top of Cement was located with a slick line tag. Bailer was full of what looked like thick contaminated cement. I ask the oil company rep why they were not pressure testing plug. He told me because the plug that this one was founded on had been tested. May 4, 2024 Bob Noble Well Bore Plug & Abandonment PBU S-37A Hilcorp North Slope, LLC PTD 2120920; Sundry 323-657 none Test Data: Casing Removal: rev. 3-24-2022 2024-0504_Plug_Verification_PBU_S-37A_bn From:Rixse, Melvin G (OGC) To:Michael Hibbert Cc:Leslie Reavis; AOGCC Records (CED sponsored); DOA AOGCC Prudhoe Bay Subject:20240201 1311 PTD 212-082 Sundry 323-658 PBU S-32A, PTD 212-092 Sundry 323 PBU S-37A - No pressure test required Date:Thursday, February 1, 2024 1:16:58 PM Attachments:Sundry_323-658_013124.pdf Sundry_323-657_013124.pdf Michael, No pressure test required of the lower plug for these two sundries. The approved Sundries should not include an AOGCC witnessed pressure test as the pressure test was previously performed. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Michael Hibbert <Michael.Hibbert@hilcorp.com> Sent: Thursday, February 1, 2024 1:04 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Leslie Reavis <lreavis@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hi Mel, Attached are the approved sundries for the cement plugs in PBU S-32 and PBU S-37. The AOGCC wrote in under the ‘Other Conditions of Approval’ that the cement plugs will need to be pressure tested to 2500 psi. The reservoir plugs were already AOGCC witness tagged and pressure tested on 4/11/23 and 4/8/23 respectively. These sundries will place additional cement above the tubing stubs, but they cannot be pressure tested due to the Kuparuk formation being perforated uphole. As agreed previously (below in this email chain) the cement plugs will be tagged with AOGCC witness, but not pressure tested. Please advise. Thanks, Michael Hibbert CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. PBW OE – Hilcorp AK From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, November 14, 2023 4:36 PM To: Michael Hibbert <Michael.Hibbert@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Michael, It sounds like an appropriate plan forward. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Michael Hibbert <Michael.Hibbert@hilcorp.com> Sent: Tuesday, November 14, 2023 2:28 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: FW: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hello Mel, I wanted to touch bases with you about these 2 jobs that I am taking over from Claire Mayfield. I am planning on placing 150’ of cement above the tubing stubs on S-37 and S-32 as agreed earlier this year after recompleting the wells up-hole as Kuparuk wells. I plan on submitting 10-403’s for this work including AOGCC witness tags post-cement placement. Let me know if that sounds like the appropriate path forward? Thanks, Michael Hibbert PBW Operations Engineer 907-903-5990 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, May 1, 2023 9:15 AM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, I want to limit the time to 12 months to lay in the 150’ of cement. Then I believe it will work. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Friday, April 28, 2023 10:44 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hi Mel, Thanks for sending the recent Sundry approval for S-37A. I wanted to send in the same addendum for S-32A attached since it is a similar plan. We can complete this with the same terms as S-37A if that works for you. Recently completed pre-RWO scope on S-32A: 1. SL tagged cement plug at 9378’ SLMD on 4/11/2023 2. MIT-T to 2500 psi passed on 4/11/20233. Eline tagged TOC at 9389’ MD with junk basket on 4/13/2023.4. Eline cut tubing at 9314’ MD on 4/13/2023 Future Abandonment of Ivishak & Sag Reservoir Plan 1. Coiled Tubing to lay ~150’ of cement inside the 9-5/8” casing directly on top of tubing stub at 9314’ to achieve cement across all annuli in the confining zone above the Sag reservoir. 2. SL tag TOC, state witnessed. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, April 26, 2023 2:09 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, Nice to hear. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Wednesday, April 26, 2023 1:40 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hi Mel, We can lay that proposed ~150’ of cement above the tubing stub after the workovers are completed (tubing will be out of the way) so that cement across all annuli is achieved over the ivishak more near term rather than ~20 years from now at final abandonment. If it can be done sometime in the next six to twelve months, that would give us a lot of flexibility with coil units and cementing crews. We will likely be sending in a separate sundry to frac this well post RWO, so I just want to make sure we are in good shape for that. Give me a call if you’d like to discuss. Thanks, Claire From: Claire Mayfield Sent: Tuesday, April 25, 2023 9:47 AM To: 'Rixse, Melvin G (OGC)' <melvin.rixse@alaska.gov> Cc: 'Davies, Stephen F (OGC)' <steve.davies@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; 'McLellan, Bryan J (OGC)' <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hi Mel, Please see attached for an addendum that can be attached to the sundry request. Alternatively I can send a full word document or PDF with the addendum included. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Let me know if you would like more information to be included. I only specified the abandonment of the Ivishak/Sag zone. Thanks, Claire From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Monday, April 24, 2023 5:26 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Mel, Can do – thanks for the clarification. Apologies for the delayed response, I’ve been in an offsite training today. I’ll send over that information tomorrow morning or by mid-day. Thanks, Claire From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, April 24, 2023 9:55 AM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, Include a final future Ivishak P&A schematic and brief procedure in this sundry request. It should be clear to commissioners, Hilcorp, and AOGCC staff what the future commitment is from Hilcorp to assure permanent isolation of the oil pools. Reading our discussion from February 27, 2023 I am unclear why I would approve a future Ivishak abandonment without a proper cement plug on this sundry. I won’t require this upper plug on these wells today but anticipate a proper Ivishak abandonment to permanently isolate these pools on up coming sundries. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan, Steve Davies, Aras Worthington From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Monday, April 24, 2023 8:35 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hi Bryan, Mel, We aligned in February that a plug on top of the tubing stub would be set upon final abandonment of the well (email discussion attached). Therefore, those steps would be on a future separate sundried program not the workover sundry, correct? We have already tagged and MIT-T’d the current plugs and cut tubing as described in the approved sundries and approved change to leave the LTP in place (email attached). The only program change that is outstanding prompting the 10-403 MOC form, is that Thunderbird Rig 1 rather than Nordic 3 will perform the tubing pull/run steps of the recomplete. Let me know if any other information would be helpful or if you would like to discuss over the phone. Thanks, Claire Mayfield Hilcorp Energy Company Prudhoe Bay West – Operations Engineer Office: (907) 564-4375 Cell: (713) 443-3631 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Saturday, April 22, 2023 8:16 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hi Claire, Could you send the following information so I can attach it to the Sundry for S-37: 1. Detail your procedure for the P&A plug that you plan to place above the tubing stub. 2. TOC tag depth with SL 3. Results of MIT-T post-cementing 4. Depth of tubing cut. 5. Updated Proposed P&A schematic Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, February 27, 2023 3:10 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, I am good with that. Please request through proper AOGCC account that you want to recall last week’s sundries. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Monday, February 27, 2023 2:50 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Thanks Mel – Agreed that upon final abandonment, we can lay in cement just above that production packer in the production casing. If you’re good with leaving the LTP’s in place, not punching holes and documenting via email, then I am good to withdraw the recent change sundries submitted. Thanks, Claire From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, February 27, 2023 2:38 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, I can approve the original sundries if we lay in cement across all annuli at the confining zones above the Ivishak (and above the existing production packer) for the final well abandonment sometime in the future. Do you want to just withdraw the sundries you submitted last week for ‘change to approved program’? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Monday, February 27, 2023 8:37 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Mel, Can you give me a call on this when you get a chance? Thanks, Claire From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, February 24, 2023 5:05 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, AOGCC wants cement across all annuli for a reservoir abandonment. Please assure you put 100’ of cement above your existing production packer within the 9-5/8” on S-32A and 100’ above your production packer within the 7-5/8” on S-37A. No reason to cut your tubing higher. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Rixse, Melvin G (OGC) Sent: Tuesday, February 21, 2023 3:18 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, Sorry to do this to you but AOGCC should get new sundries with ‘change to approved program’ checked. The field inspectors will be confused if we don’t do this step. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Monday, February 20, 2023 4:56 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Hi Mel, Yes I can confirm the two statements below. I am comfortable with setting the TOC’s >=100’MD above the production packers in both cases. Also, for S-32, I had a step for punching holes in the tubing tail just below the production packer. However, with 100’ of cement above the production packer, that step seems redundant. If we get a passing pressure test on that production packer (meaning the cement from the window up to the tubing tail is competent), I’d like to avoid punching holes, and go ahead with the fullbore cement P&A with the TOC >=100’MD above the production packer. Let me know if all sounds good to you. Thanks, Claire From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, February 17, 2023 3:50 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Subject: [EXTERNAL] RE: S-32A and S-37A Liner Top Packers Claire, Please confirm the following: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 1. PTD212-082, S-32A the production tubing packer at 9832’ MD is within and greater than 100’ below the top of the PB oil pool confining zones. Yes/No? Yes 2. PTD212-092, S-37 the production tubing packer at 8837’ MD is within and greater than 100’ below the top of the PB oil pool confining zones. Yes/No? Yes If you are able to answer ‘Yes’ to the two questions above, I will approve not pulling the LTPs in these wells, but AOGCC would like to see a minimum of 100’ MD of cement above the packers. That would be the following: 1. For S-32A, TOC would be at shallower than 9732’ MD. 2. For S-37A, TOC would be at shallower than 8737’ MD. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Wednesday, February 15, 2023 8:36 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: S-32A and S-37A Liner Top Packers Hi Mel, On two of our upcoming recomplete wells, S-32 and S-37, we were unable to pull the LTPs after many hours of jarring as planned pre-abandonment of the ivishak completion. We will plan to leave the LTP’s in place, pump the fullbore cement P&A into the liner and above the liner top with ~25’ of cement on top of the LTP (same target TOC’s as in original sundries approved). Please let me know if you have any questions/concerns with leaving the LTP’s in place. Thanks, Claire Mayfield Hilcorp Energy Company Prudhoe Bay West – Operations Engineer Office: (907) 564-4375 Cell: (713) 443-3631 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 thes 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-37A Reservoir Cement Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-092 50-029-22291-01-00 457B ADL 0028257 11583 Surface Intermediate Liner Liner Liner 8656 2890 9076 247 1485 1280 8734 10-3/4" 7-5/8" 5-1/2" 3-1/2" x 3-1/4" 2-3/8" 8324 33 - 2923 32 - 9108 8894 - 9141 8869 - 10354 10303 - 11583 3409 33 - 2915 32 - 8643 8460 - 8672 8439 - 8677 8680 - 8656 None 2480 4790 6280 10530 11780 8734 5210 6890 7740 10160 11200 6812 - 6861 4-1/2" 12.6# 13Cr80 30 - 6751, 8670 - 89026711 - 6753 Conductor 75 20" 34 - 109 34 - 109 1490 470 4-1/2" HES TNT Packer 4-1/2" Baker S3 Packer 6669, 6587 8837, 8412 Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com (907) 903-5990 PRUDHOE BAY 1/15/24 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 No SSSV Installed By Grace Christianson at 9:07 am, Dec 11, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.12.08 17:03:37 -09'00' Torin Roschinger (4662) 323-657 SFD 12/20/2023MGR30JAN24 AOGCC to witness tag (TOC ~8520' MD) and pressure test to 2500 psi. 10-404 DSR-12/14/23*&:JLC 1/31/2024 1/31/24Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.31 15:23:52 -09'00' RBDMS JSB 020124 Ivishak Cement Plug Well: S-37A Well Name:S-37A API Number:50-029-22291-01 Current Status:Kuparuk Producer - SI Estimated Start Date:1/15/2024 Rig:Coiled Tubing Sundry #TBD Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:212-092 First Call Engineer:Michael Hibbert (907) 903-5990 (M) Second Call Engineer:Kirsty Glasheen (907) 350-4310 (C) Est Bottom Hole Pressure:4079 psi @ 6700 TVD 11.8 PPG | (Est based on 2018 data) Max. Anticipated Surface Pressure:3409 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2025 psi (Taken on 6/25/2023) Min ID:3.813” at2,100’ X-nipple Max Angle:34 Deg @ 7,177’ MD Cement Tag:EL tagged TOC at 8,734’ on 4/9/23 with 3.63” gauge ring Last Intervention:Slickline set rock screen at 6,698’ on 7/24/23 Brief Well Summary: S-37A was originally completed as a Sag/Ivishak well, but had been shut in for several years, so that reservoir was abandoned and recompleted to be a Kuparuk well. The Ivishak/Sag was isolated with a cement plug pumped on 4/4/23. An AOGCC witnessed tag of the cement top was completed on 4/8/23, 8,719’ MD. An AOGCC witnessed MIT-T was completed on 4/8/23 to 2500 psi. A RWO was executed in May 2023 which pulled the existing 4-1/2” tubing and install new 4-1/2” tubing and a 4-1/2” x 7-5/8” packer at 6,669’. Kuparuk perforations were added from 6,812’-6,861’. WC was high and the planned frac was never completed. A CT FCO was completed on 7/21/23 and hard fill and rocks (1.5”-2” in diameter) were found in the tubing. SL set a rock-screen in the X-nipple at 6,698’. As part of the Kuparuk recomplete, Hilcorp made an agreement with the AOGCC to place a 150’ cement plug in the 7-5/8” casing above the cut tubing stub by the end of Q1 2024. Job includes pumping excess cement to allow for any contamination/slumping of cement top. Objective: x Place cement plug in the 7-5/8” casing from ~8,670’ - ~8,520’. AOGCC witnessed tag of cement top. Slickline 1. Drift to cement top at 8,734’. Tie into tubing tail for depth correction. 2. Collect sample from TD. Consider bailing fill and determine if it is loose debris or rocks. DHD 1. Get tubing and IA fluid levels and pressures Coiled Tubing 1. MIRU 1.75” CT w/ cementers 2. If SL found tag depths high then be prepared to perform a FCO if necessary. 3. MU and RIH w/ cementing BHA a. Note there are open perforations above the cement placement depths from 6,812’-6,861’. 4. Layin 14 bbls of Class G cement from 8,670’-8,370’ a. Let ~2 bbls exit nozzle and then layin 1 for 1. 7-5/8” casing has a capacity of 21.8 ft/bbls. Pump at 1 bpm and pull at 21.8 fpm. b. TOC should be at ~8,370’. 5. POOH. 6. RDMO. Ivishak Cement Plug Well: S-37A Slickline – Wait on Cement 1. Give AOGCC 24 hours notice prior to tag 2. Perform AOGCC witnessed tag of cement. Ivishak Cement Plug Well: S-37A Current WBD: Ivishak Cement Plug Well: S-37A Proposed WBD: Cement Plug in 7-5/8” from 8,670’-8,520’ Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d W o r k O v e r S u n d r y P r o c e d u r e Da t e : D e c e m b e r 8 , 2 0 2 3 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l S - 3 7 A Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o th e AO G C C b y t h e w o r k o v e r ( W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230519 1516 Approval CBL PTD212-092 S-37A (Sundry 323-214) RWO CBL Date:Friday, May 19, 2023 3:17:22 PM From: Rixse, Melvin G (OGC) Sent: Friday, May 19, 2023 3:15 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] RE: S-37A (Sundry 323-214) RWO CBL Claire, Isolation demonstrated in the CBL. Approved to proceed with sundry. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Friday, May 19, 2023 2:53 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] RE: S-37A (Sundry 323-214) RWO CBL Hi Mel, Please see attached RBT log on S-37 with field pick TOC of ~2900’ MD. We are planning to proceed with the Kuparuk completion as described in the sundry #323-214 program (top of Kuparuk at 6812’MD). Please let me know if you have any questions/concerns. Thanks, Claire Mayfield Hilcorp Energy Company Prudhoe Bay West – Operations Engineer CAUTION: This email originated from outside the State of Alaska mail system. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Office: (907) 564-4375 Cell: (713) 443-3631 From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Tuesday, May 16, 2023 4:12 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL] RE: S-37A (Sundry 323-214) RWO CBL Thanks Mel, appreciate it. Claire From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, May 16, 2023 3:56 PM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL] RE: S-37A (Sundry 323-214) RWO CBL Claire, Thank you. Will be watching out for it. Feel free to text me with updates. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Steve Davies From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Tuesday, May 16, 2023 3:16 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: S-37A (Sundry 323-214) RWO CBL Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Mel, The Thunderbird 1 Rig is moving to S-37A today, and the program includes running a CBL to confirm top of cement is above the Kuparuk. I just wanted to send a heads up that we will likely be running the CBL tool on Friday or Saturday. We are planning to run Halliburton’s Radial Bond logging tool (RBT) on memory as the Cast-M tool/crew is not available. Let me know if you have any questions. Thanks, Claire Mayfield Hilcorp Energy Company Prudhoe Bay West – Operations Engineer Office: (907) 564-4375 Cell: (713) 443-3631 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230512 0929 APPROVAL No additional pressure test of plug - Completed 10-403 for PBU S-37A (PTD_ 212-092) Date:Friday, May 12, 2023 9:32:35 AM Attachments:image001.png From: Rixse, Melvin G (OGC) Sent: Friday, May 12, 2023 9:21 AM To: Claire Mayfield <Claire.Mayfield@hilcorp.com> Cc: Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: [EXTERNAL] Completed 10-403 for PBU S-37A (PTD: 212-092) Claire, Agreed. You will not need an MIT-T as the lower plug has a state witnessed pressure test. A pressure test would be redundant. AOGCC will require the state to witness the tag of the 150’ of cement. (No pressure test.) Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Aras, Oliver, Abbie From: Claire Mayfield <Claire.Mayfield@hilcorp.com> Sent: Friday, May 12, 2023 8:34 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: FW: [EXTERNAL] Completed 10-403 for PBU S-37A (PTD: 212-092) Hi Mel, Thanks for the call this week. Just sending a note via email to document as discussed: we will not need to MIT-T the 150’ cement plug laid post-rig workover as mentioned in blue comments in the approved sundry. Since the cement plug in the liner has already been MIT-T’d and witnessed on 4/8/2023, and the workover will add perforations above the plug, an additional MIT-T will not be necessary or possible. Screenshot of the addendum below: Thanks, From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, April 27, 2023 9:09 AM To: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: FW: [EXTERNAL] Completed 10-403 for PBU S-37A (PTD: 212-092) All, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. See attached approved 10-403 for S-37A Recomplete to Aurora RWO. There are several conditions of approval, notes throughout the program and an addendum page at the end of the document. Thank you, Abbie From: Junke, Kayla M (OGC) <kayla.junke@alaska.gov> Sent: Thursday, April 27, 2023 8:59 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Completed 10-403 for PBU S-37A (PTD: 212-092) Hello, Attached is the completed 10-403 for PBU S-37A (PTD: 212-092) Kayla Junke Natural Resources Tech II AOGCC (907) 793-1225 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individualor entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:35 Township:12N Range:12E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:11583 ft MD Lease No.:ADL0028257 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 109 Feet Csg Cut@ Feet Surface:10 3/4"O.D. Shoe@ 2923 Feet Csg Cut@ Feet Intermediate:7 5/8"O.D. Shoe@ 9108 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner1:5 1/2"O.D. Shoe@ 9151 Feet Csg Cut@ Feet Liner2:3.5" x 3.25"O.D. Shoe@ 10354 Feet Csg Cut@ Feet Liner3:2-3/8"O.D. Shoe@ 11583 Feet Csg Cut@ Feet Tubing:4 1/2"O.D. Tail@ 8902 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Bottom 11583 ft 8719 ft 14 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 450 2755 2648 2621 IA 1100 1238 1239 1236 OA 0 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Caleb Piaskowski Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Tag and MITT per sundry. Wireline had 13 feet of 2 1/8" tool string to total approximately 270 lbs. First tag was at 8719 ft MD and the second tag after the MITT was at 8720 ft MD. The sample of the cement showed good cured cement. No issues. April 8, 2023 Guy Cook Well Bore Plug & Abandonment PBU S-37A Hilcorp North Slope LLC PTD 2120920; Sundry 323-030 Photo Test Data: P Casing Removal: rev. 11-28-18 2023-0408_Plug_Verification_PBU_S-37A_gc 7. 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-37A Recomplete to Aurora Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-092 50-029-22291-01-00 11583 Surface Intermediate Liner Liner Liner 8656 2890 9076 247 1485 1280 8734 10-3/4" 7-5/8" 5-1/2" 3-1/2" x 3-1/4" 2-3/8" 8324 33 - 2923 32 - 9108 8894 - 9141 8869 - 10354 10303 - 11583 33 - 2915 32 - 8643 8460 - 8672 8439 - 8677 8680 - 8656 None 2480 4790 6280 10530 11780 8734 5210 6890 7740 10160 11200 6812 - 6861 4-1/2" 12.6# 13Cr80 30 - 6751, 8670 - 8902 6711 - 6753 Conductor 75 20" 34 - 109 34 - 109 1490 470 4-1/2" HES TNT Packer 6669, 6587 6669, 8837 6587, 8412 Torin Roschinger Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY, Prudhoe Oil / 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 30 - 6658, 8270 - 8467 8734 - 11561' MD in Tubing/liner Pump 22.3-bbls of 14-ppg Class G Cement with final pressure of 180-psi. 115 Well Not Online 185 4949 1544 1900 306 0 323-030, 323-214 13b. Pools active after work:Aurora Oil Pool 4-1/2" Baker S3 Packer 8837, 8412 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 By Grace Christianson at 9:22 am, Jun 14, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.13 16:13:25 -08'00' Torin Roschinger (4662) DSR-6/15/23 RBDMS JSB 071423 WCB 3-6-2024 ACTIVITY DATE SUMMARY 1/28/2023 T/I/O=shut in/1500/0+ . PPPOT-IC (PASS), PPPOT-T (PASS). Pre RWO Tbg hgr void had 1400 psi, bled off quickly, shut in 10 min., held @ 0 psi, ICPO had 700 psi., bled off quickly, shut in 10 min., held @ 0 psi., test ICPO 500 psi./5 min., 0 psi. loss, test to 3500 psi., lost 100 psi. first 15 min., lost 0 psi. last 15 min., bled off, functioned ULDS one at a time, all went out to 4-3/4" out,one was twisted, but not bent, functioned fine, marked & labeled it w/ yellow paint/wrote on flange, buffed & Kroiled LDS, ran in, tagged hanger, torqued gland nuts ~ 450 ft/lbs., torqued LDS to 500 ft/lbs., test tbg hgr void 500 psi/5 min., 0 psi loss, test to 5000 psi/30 min., 0 psi. loss, bled off, RDMO 2/11/2023 ***WELL S/I ON ARRIVAL*** (Caliper) DRIFT w/ 3.79" GAUGE RING TO LTP @ 8,863' MD ***CONTINUED ON 2/12/23 WSR*** 2/12/2023 ***CONTINUED FROM 2/11/23 WSR*** (Caliper) DRIFT w/ DMY LTP TO LTP AT 8,863' MD SET WHIDDON CATCHER AT 8,863' MD PULL OGLV & LGLV'S AT ST # 4 (6,713' MD), ST # 5 (5,104' MD) & ST # 6 (3,018'MD). SET BK-DGLV'S AT ST # 6 (3,018' MD), ST# 5 (5104' MD) & ST# 4 (6713' MD) PULLED BK-DGLV IN ST# 1 @ 8438' MD LRS LOADED IA w/ 200 BBLS SEAWATER FOLLOWED BY 66 BBLS DIESEL FP RESET BK-DGLV IN ST# 1 @ 8438' MD PULLED WHIDDON CATCHER @ 8863' MD (empty) LRS LOADED TBG w/ 160 BBLS SEAWATER FOLLOWED BY 38 BBLS DIESEL FP ATTEMPT MIT-IA(IA pressure building, see LRS wsr) JARRED ON LTP AT 8849' MD FOR 1HR. ***CONTINUED ON 2/13/23 WSR*** 2/12/2023 T/I/O = 1660/1600/0 . Temp - SI. Assist SL. Pumped 3 bbls 60/40, 200 bbls SW, 66 bbls diesel down IA. Pumped 2 bbls 60/40, 160 bbls sw, 38 bbls diesel down tubing. Pumped 13.6 bbls DSL into IA to reach max applied pressure of 3500 psi for Pressure test. IA pressure maintinaed. Bled back to 1500 psi, bled back 3 bbls. *** Job continued to 2-13-2023 ***. 2/13/2023 *** Job continued from 2-12-2023 ***. Assist SL. *** Job continued to 2-14-2023 *** 2/13/2023 ***CONTINUED FROM 2/12/23 WSR*** (Caliper) JARRED ON LTP @ 8863' MD FOR 6HR & 40MIN (Parted wire at surface 40min in to last run) WORK ON FISHING WIRE & TOOLSTRING ***CONTINUED ON 2/14/23 WSR*** 2/14/2023 *** Job continued from 2-13-2023 *** Assist SL. Job postponed. SL in control of well upon departure. FWHP's = 35/1664/-13 2/14/2023 ***CONTINUED FROM 2/13/23 WSR*** (Caliper) RECOVERED WIRE & TOOLSTRING FROM LTP @ 8,863' MD. ***JOB SUSPENED TO SPOOL WIRE, NOTIFY DSO OF WELL STATUS*** Daily Report of Well Operations PBU S-37A Daily Report of Well Operations PBU S-37A 2/14/2023 T/I/O= 50/1600/0 Temp= SI Pumped 5 bbls 60/40 followed by 20 bbls Sea water @ 1 bpm @ 85 psi// 20 bbls @ 2 bpm @ 85 psi// 20 bbls @ 3 bpm @ 85 psi// 20 bbls @ 4 bpm @ 100 psi// 20 bbl @ 5 bpm @ 200 psi// 53 bbls @ 5 bpm @ 85 psi. Pumped 5 bbls 60/40 followed by 40 DSL for FP Tags hung FWHP's= 0/1150/0 All CV's= OTG Pad Op notified of well status upon departure 2/14/2023 ***WELL S/I ON ARRIVAL*** (Caliper) RU POLLARD UNIT # 60 ***CONTINUED ON 2/15/23 WSR*** 2/15/2023 ***CONTINUED FROM 2/14/23*** RAN HES 40 ARM CALIPER FROM LTP @ 8,863' MD TO SURFACE ***JOB COMPLETE, WELL S/I ON DEPARTURE, NOTIFY DSO OF WELL STATUS*** 3/22/2023 T/I/O= 62/1138/0. LRS 72 Injectivity Test (INJECTIVITY/STEP RATE TEST). Pumied 2 bbls of 60/40 MeOH, 210 bbls of 130*F 1% KCl and 38 bbls of 100*F diesel into the TBG. IAP increased slowly to 1712 psi then fell off slowly to Final T/I/O= 0/1348/0. 3/29/2023 T/I/O=0/800/0 Disconnected production piping, installed blinds at lateral valves. Set 4" CIW "H" TWC through tree. N/D production tree, N/U dryhole tree. Torqued to specs. PT'd tree through tree cap against TWC 250/5000 psi. pass. Pulled TWC. Installed drilling scaffolding job complete. FWP's 0/800/0. 4/4/2023 Reservoir P&A pre RWO Heat DSL transport to 90* Assist with cement job HES Pump 5bbl FW, 22.3bbl 14ppg class G, 5bbl FW LRS displace cement with 129bbl warm diesel. Est TOC 8797' **Complete** 4/8/2023 ***WELL S/I ON ARRIVAL*** TAGGED CEMENT @ 8,719' SLM W/ 3.25" CENTRALIZER & 2 1/2" SAMPLE BAILER (good sample of cement) PERFORMED AOGCC WITNESSED MIT-T TO 2,500PSI (pass) AOGCC WITNESSED CEMENT TAG @ 8,720' SLM ***WELL LEFT S/I ON DEPARTURE, WALKDOWN LOCATION W/ PAD OP*** 4/9/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP DRIFT TO TOC AT 8734.2' MD WITH JUNK BASKET, 3.63" G.RING. CUT TUBING WITH JET CUTTER AT 8670' MD, CCL TO CUTTER=6', CCL STOP DEPTH=8664' MD. TIED INTO GLM AT 8438' MD ON TUBING TALLY DATED:12/8/91. TUBING/ANNULUS APPEAR TO COMMUNICATE AFTER SHOOTING. PUMP DOWN TUBING AND PRESSURE UP ANNULUS WITH TRIPLEX FOR CONFIRMATION. ***WELL LEFT S/I, READY FOR CIRC OUT*** TAGGED CEMENT @ 8,719' SLM W/ 3.25" CENTRALIZER & 2 1/2" SAMPLE @ BAILER (good sample of cement)(g ) PERFORMED AOGCC WITNESSED MIT-T TO 2,500PSI (pass) AOGCC WITNESSED CEMENT TAG @ 8,720' SLM g LRS displace cement with 129bbl warm diesel Est TOC 8797' Daily Report of Well Operations PBU S-37A 4/16/2023 T/I/O= 1273/864/0. LRS 72 Circ Out (RWO CAPITAL). CMIT-TxIA to 3500 psi PASSED. T/IA lost 50/46 psi during the first 15 minutes and 20/19 psi during the second 15 minutes. T/IA lost 70/65 psi during the 30 minute test. Pumped 5.6 bbls of diesel to achieve test pressure. Bled back 5.2 bbls to T/I/O=815/807/0. Circulate well by pumping into the TBG with IA reutrns to S-12 F/L. Pumped 10 bbls of 60/40 MeOH, 103 bbls of FW with Deep Clean and 560 bbls of 1% KCl. Pumped 104 bbls of 100*F diesel into the TBG. U-Tube TxIA. Bled psi tbg/ia down to zero Freeze protect S-12 Flowline with 10 bbls of 60/40 MeOH. Pressure up FL 1500 psi. Pad Op notified of well status per LRS departure. SV=C HL=C MV=O IA,OA=OTG **Tags hung on MV and IA 5/11/2023 Bleed pressure from void, control and balance lines. Check tree for pressure. Set 4" CTSHBPV w/ dry rod. N/D tree. SBMS stayed in THA. Cut and cap (2) 1/4" CCL's. Pull termination sleeves, remove control lines and plug sleeves and reinstall. Inspect TBG HGR neck and lift threads. Install CTS plug. R/U test equipment and test CTS plug to 4M for 5 min. Passed. Bleed off pressure and evacuate fluid. LDS out = 4 1/4". N/U BOP. 5/11/2023 T/I/O = TWC/0/0. RD DH tree and THA. RU 13" BOP w/ 10" DSA. Torqued to API spec. PT'd to 1000 PSI w/ gas from adjacent well (Pass). Installed 2" intergal flanges on IA and OA. 5/14/2023 T/I/O=BPV/0/0. Reset BOP's as per Thunder Bird Rep. Torque DSA to API specs.. PT with gas from S-12 against TWC to 1000 psi (PASSED). Final WHP's=TWC/0/0. ***JOB COMPLETE***. RDMO 5/17/2023 TBird RWO Job Scope: Recomplete Ivishak to Kuparuk MIRU Thunderbird-1. Spot rig, pits, pump house, koomey, choke house. Raise mast. Load 1% KCI in pits/uprights. Hook up Koomey hoses to BOP stack. Grease choke and kill manifold. Install 3-1/8" integral flanges on IA and OA . Build Scaffold & Hootch around stack. Spot pipe wrangler. M/U 4-1/2" Test Joint. Scaffold crew completed. R/U chart recorder and test hoses. Install 4-1/2" test joint in BOPE stack. Fill stack. Shell test 250 psi low / 3000 psi high. AOGCC waived witness (Guy Cook). Begin BOPE testing as per sundry. ......Job in progress 5/18/2023 TBird RWO Job Scope: Recomplete Ivishak to Kuparuk Completed BOPE testing as per sundry 250 psi low / 3000 psi high. Pulled CTS insert / BPV. Circulate out 103 bbls of diesel FP. M/U landing joint, BOLDS. Hanger pulled free at ~80K. PUW-102K. Pull to floor & L/D. POOH with 4-1/2" NCST tubing. L/D SSSVLN, recovered 4 SS bands & 29 Lasalle clamps. Continue POOH w/4-1/2" 12.6# NSCT tubing. 155 joints pulled. ......Job in progress 5/18/2023 S-37: Pull 4" H CTS plug w/ T bar, make up 4-1/2" TDS landing joint to tubing hanger 9-1/2 right hand turns, check inner annulus psi., none, back out lock down screws, pull hanger to rig floor, cut & cap (2) ¼" control lines, RDMO Daily Report of Well Operations PBU S-37A 5/19/2023 TBird RWO Job Scope: Recomplete Ivishak to Kuparuk Continue POOH w/4-1/2" 12.6# NSCT tubing. Pulled total 218 full joints and 21' cut joint, 6 camco KBMG mandrels. MIRU Slickline w/HES memory. RIH w/HES RBT BHA. Log from 8,000' slm to surface @ 50 fpm. Reference log SLB PProf 02-Feb- 2017. Wait on Log for Cement top. Received approval from AOGCC. RD SL Unit. Rig up GBR casing equipment. Lay out completion jewelry in running order. MU and RIH with 4-1/2" VamTop 12.6# 13CR Completion as per run tally. ......Job in progress 5/19/2023 ***ASSIST T-BIRD RIG*** RAN HES RBT LOG f/ 8000' SLM TO SURFACE ***JOB COMPLETE, DSO NOTIFIED*** 5/20/2023 Drain BOP, Land tubing hanger. Visually very though annulus valve. Torque GN & LDS. Set TWC # 444 RDMO 5/20/2023 T/I/O 0/0/0 Temp TFS unit 4 assist Rig with freeze protect. Pumped 3 bbls of 60/40 followed by 104 bbls of DSL down the IA. Rig youtubed IA and TBG to freeze protect both. Tag hung and mastercard given to DSO. Final WHPS 0/435/0 5/20/2023 TBird RWO Job Scope: Recomplete Ivishak to Kuparuk Continue RIH with 4-1/2" VamTop 12.6# 13CR Completion as per run tally. P/U hanger and land completion, PUW 80, SOW 74. Reverse circulate 90 bbls of 1% KCI w/corrosion inhibitor followed by 87 bbls of KCI. Drop Ball & Rod (1-3/8" FN). Set HES TNT packer, MIT-T to 3500 psi for 30 minutes. Bleed Tbg pressure to 1500 psi. MIT-IA to 3500 psi for 30 minutes. Bleed tubing pressure and shear DCK valve in GLM # 4. Pump 104 bbls of diesel down IA. U-Tube diesel IA x Tbg. Set TWC in hanger. RDMO TB-1. ......RWO Program Completed. 5/21/2023 T/I/O = 0/0/0. Pull 13-5/8" 5M Schaeffer BOPs & 13-5/8" x 11" DSA. Install 11" 5M FMC THA. Install 4-1/16" CIW FLS tree. Wellhead tech tested adapter void. Tree tested to 500 psi low / 5000 psi high. Pull 4" CIW TWC. Install production & AL piping, set well house. 5/21/2023 Clean void & ring groove, press in new SBMS, install new RX-54, inspect/grease THA ID & hanger neck OD seals, M/U THA, S/B for well support to torque, test void 700 psi/5 min., 0 psi loss, test void 5,000 psi/30 min., 0 psi loss, bleed off test psi, RDMO 5/22/2023 T/I/O=360/17/0 (RWO CAPITAL) Assist Slickline MIT-T 3750 psi max applied. Pumped 3.16 bbls diesel down TBG to achieve max pressure applied 3766 Psi. 15 min loss 72 psi, 30 min loss 27 Psi. Bleed back 3 bbls FWHP=360/33/0 Left well in slicklines control. 5/22/2023 ***WELL S/I ON ARRIVAL*** (rwo capital) SET 4-1/2" BAIT SUB, BELL GUIDES & GUTTED 2" JD ON BALL & ROD @ 6673' SLM FOR CATCHER ASSEMBLY PULLED BK-DGLV IN ST# 1 @ 6483' MD REPLACED w/ BK-OGLV PULLED BK-DGLV IN ST# 2 @ 5784' MD, REPLACED w/ BK-LGLV PULLED BK-DGLV IN ST# 3 @ 4965' MD, REPLACED w/ BK-LGLV PULLED BEK-SOV IN ST# 4 @ 3381' MD, REPLACED w/ BK-LGLV PULLED BAITED PULLING TOOL, BALL & ROD, & RHC BODY @ 6697' MD LRS PERFORMED 3500PSI MIT-T (Pass) ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU S-37A 5/31/2023 MIRU RIH AND CORRELATE TO SLB PPROF DATED 02-FEB-2017 SENT TO TOWN FOR APPROVAL BY OE - CLAIRE MAYFIELD APPROVAL GRANTED PERFORATED INTERVAL 6812'-6861' - 49', 6SPF, 60 DEG PHASED GOOD INDICATION OF SHOTS FIRED POOH CLOSE SWAB RIG DOWN OFF WELL - CONFIRMED GUNS FIRED SECURE WELL AND LOCATION CLOSE OUT PERMIT LEAVE LOCATION WITH WELL SI PERFORATED INTERVAL 6812'-6861' - 49', 6SPF, 60 DEG PHASED 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 thes pool? Will planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-37A Recomplete to Aurora Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-092 50-029-22291-01-00 341J / 457B ADL 0028257 11583 Surface Intermediate Liner Liner Liner 8656 2890 9076 247 1485 1280 ~8797 10-3/4" 7-5/8" 5-1/2" 3-1/2" x 3-1/4" 2-3/8" ~8378 33 - 2923 32 - 9108 8894 - 9141 8869 - 10354 10303 - 11583 2336 33 - 2915 32 - 8643 8460 - 8672 8439 - 8677 8680 - 8656 None 2480 4790 6280 10530 11780 ~8797 5210 6890 7740 10160 11200 10305 - 11561 4-1/2" 12.6# 13Cr80 30 - 89028680 - 8657 Conductor 75 20" 34 - 109 34 - 109 1490 470 4-1/2" Baker S3 Packer No SSSV Installed 8837, 8412 Date: Stan Golis Sr. Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY 4/23/23 Current Pools: PRUDHOE OIL Proposed Pools: Aurora Oil 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-214 By Kayla Junke at 10:43 am, Apr 07, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.04.07 06:13:26 -08'00' Stan Golis (880) Aurora Oil DSR-4/13/23 Perforate New Pool SFD 4/10/2023 Prudhoe Oil: CO 341J; Aurora Oil: CO 457B SFD 4/10/2023 Recomplete to Aurorap 10-404 MGR26APR23 2336 *BOPE test to 3000 psi. Annular to 2500 psi. * State to witness slickline tag and pressure test to 2500 psi of reservoir cement plug w/ TOC ~ 8833' MD. * CBL to AOGCC upon completion. * Complete PB Oil Pool abandonment per attached schematic with 150' cement plug above tubing stub to be tagged and pressure tested to 2500 psi completed within 12 months of this sundry approval. JLC 4/26/2023 4/27/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.26 17:17:38 -08'00' RBDMS JSB 042723 Recomplete to Kuparuk Well: S-37A PTD: 212-092 Well Name:S-37A API Number:50-029-22291-01 Current Status:Producer SI Estimated Start Date:4/23/2023 Rig:Thunderbird 1 Sundry #323-030, TBD Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:212-092 First Call Engineer:Claire Mayfield (907) 564-4375 (O)(713) 443-3631 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure:3196 psi @ 8599 TVD 7.2 PPG | (04/23/2012 static) 7.4 PPG with 2500’ freeze protect Max. Anticipated Surface Pressure:2336 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1400 psi (Taken on 11/22/21) Min ID:1.91” SLT LNR at 10303’ MD Max Angle:110 Deg @ 10,098’ MD 70 deg: 9318’ MD High DLS from 9160’-9410’ MD Formation Tops: Kuparuk: 6812’MD, 6711’TVD Kingak: 7934’md, 7820’TVD Sag: 9106 MD, 8642’TVD Shublik: 9149; 8678’TVD Sadlerochit 9287’ MD; 8794’TVD MITs: MIT-T: 2400 psi on 10/17/2012 MIT-IA: 3000 psi on 7/6/2012 Brief Well Summary: The Sag/Ivishak reservoir zones of S-37A no longer remain economically viable. The Kuparuk interval for S-37 motherbore is in between constant pressure boundaries S-112 and S-123 in a relatively low recovery factor area of the Kuparuk. The Sag/Ivishak reservoir will be abandoned, and a RWO is planned to recomplete to Kuparuk to test production rates and water cuts at the Kuparuk interval. S-37 and S-37A History: S-37 was originally drilled in 1992. The 13-1/2” surface hole was drilled to 2932’, 10-3/4” casing was set and cemented with 1756 cu ft of AS III. A top job was also completed with an additional 500cuft of AS I cement. The 10-3/4” casing was tested, the float shoe was drilled out and a leak off test was performed. The 9-7/8” hole was drilled to 9117’, and 7-5/8” casing was installed to 9106’ and cemented with 1305 cu ft of Class G. The 7-5/8” casingwas tested, the shoe was drilledout and the 6-3/4” holewas drilledto 9770’. The 5-1/2” liner and hanger was run in hole, circ’ed out and cemented with 157 cu. ft of Class G cement. They tested the casing and liner, thenranthe4-1/2” tubingin the well. The tubingpackerwas set,andthe tubing was testedbefore rigging down. The well initially produced from Ivishak zones 3 & 4. Water production remained high and oil rates slowly declined. Zone 3 was isolated with sand/cement in 1993 to isolate any water production from this zone and to improve hydraulics, but no major change in production was observed. S-37APB1drillingcommenced on August 11, 2012 to target the Sag Riverformation.The window was milled from 9,141’ to 9,154’ MD, with new formation / rat hole drilled to a depth of 9,162’ MD. Drilling proceeded to 9,900’ o recomplete to Kuparuk to test production rates and water cuts a Recomplete to Kuparuk Well: S-37A PTD: 212-092 MD (-8,641’ TVDss), and a wiper trip was initiated. Hole problems resulted in the coil being stuck for 2 hours and going back to bottom was deemed too risky. An OHST (S-37A) was then undertaken, described below. S-37A: OHST was initiated by setting the billet at 9,255’ MD in the Shublik. The well was steered into the Ivishak and was held horizontal until the Fault 1 zone was passed at 9,600’ MD where total loss of returns occurred. Drilling continued until the protective liner point in the Sag River was reached at 10,354’ MD (-8,607.7’ TVDss). The liner was successfully run to bottom and released. A second cementing attempt consisted of pumping 20 bbls of cement, which was quickly lost to the formation. An FIT was run after milling the shoe, which indicated cement integrity between the formation and the lower liner/shoe. Drilling proceeded to 11,583’ MD (-8,586.8’ TVDss). A slotted liner was then run through the lateral Sag River production interval. Notes Regarding Wellbore Condition x 09/20/2007: GLV C/O x 01/24/2010: GLV C/O x 05/21/2011: Set TTP; Set DSSSV; MIT-T to 2000psi x 01/29/2012: Dummied GLVs x 02/03/2012: MIT-IA passed to 3000psi x 02/04/2012: MIT-OA, LLR 5bpm @ 1250psi, caliper tubing – all jts <20% x 7/26/2012: MIT-IA Passed to 3000 psi x 9/2/2012: CTD sidetrack S-37A x 10/17/2012: MIT T Passed to 2400 psi. x 10/18/2012: Pulled DGLVs from Sta# 5 & 6. Set LGLV Sta# 6, & OGLV Sta# 5. x 10/21/2012: C/O LGLV @ Sta # 6. x 04/01/13 GLV C/O x 8/07/2015: CTU CBL of liner from 8700-10,300’MD; TOC 9640’ x 08/08/2015: CTU mill scale, SCMT, & mud acid x 09/16/2015: Scale Inhibition Treatment pumped x 05/04/2016: GLV C/O x 02/02/2017: EL pprof to test LTP, pprof showed 100% prod coming from Sag slotted liner x 07/13/2021: GLV C/O x 11/22/2021: SL Drift dmy whipstock to 2500 The most recent caliper performed 2/2012 shows an average wall loss around 8%. This tubing should be re- usable, a second caliper can be performed pre-RWO. Objective: x Reservoir abandon Ivishak & Sag, Recomplete to Kuparuk Procedure: Pre-Rig – 1. Obtain updated pressure tests on WH seals Slickline & Fullbore 1. Drift for LTP, broach scale as needed 2. Load tbg & IA with 1% KCl or SW + Freeze protect completed 2/12/2023 a. Total IA volume to St#1: 221 bbls Recomplete to Kuparuk Recomplete to Kuparuk Well: S-37A PTD: 212-092 b. Freeze protect volume to 2500’: 115 bbls 3. Dummy GLVs completed 2/12/2023 4. Obtain 3500 psi MIT-IA (ensure all DGLV’s set)completed 2/12/2023 5. Pull LTP @ 8863 attempted 2/13/23 without success; aligned with AOGCC to cement over LTP 6. Run caliper from liner top to surface completed 2/15/2023 7. Injectivity test with KCL pre-Fullbore P&A completed 2/14/2023 a. Bullhead 210bbls of 1%KCL or SW down the TBG into formation i. Note pressures and rates ii. Max pressure ~2,500psi b. Freeze protect with 38bbls of diesel c. Send rate/pressure information to OE for final cement design d. Note IA pressure during pumping operations Well Support – Prep Tree and WH for P&A work 1. Pull production tree.Install BPV or TWC in tubing hanger profile. 2. Install dry hole tree for P&A work.Pressure test. 3. Drop IA casing valves and install integral valves ----------------------------------------------Sundry Required Before Proceeding-------------------------------------------------- Fullbore P&A of Ivishak completion: 1. Pump Reservoir abandonment plug per schedule below. Planned TOC is 8833’ MD, in the confining zone above the Sag River formation.Completed 4/4/2023. Estimated TOC ~8797. a. 5bbls meth spear b. 10bbls fresh water spacer c.22 bbls 14ppg class G cement d. 5 bbls fresh water spacer e. Foam wiper ball f. 130 bbls diesel displacement – Hot i. (Maximum 130 bbls diesel to get TOC target, minimum 120 bbls to avoid Kuparuk) 2. Note pressure after shutting down pump, do not bleed WHP after cement is in place 3. Max treating pressure during cement job is 3,500psi 4. Before starting the cement job confirm displacement pump metering accuracy to avoid over/under displacing cement. Cement Type/weight:Class G 14 ppg Slurry Temperature:between 80° and 110°F Fluid Loss:20-100cc/30 min Compressive Strength: 1000 psi in 48 hrs. Thickening Time:Minimum 8 hours Estimated TOC ~8797. r abandonment plug Recomplete to Kuparuk Well: S-37A PTD: 212-092 Slickline: 1. WOC. Drift and tag TOC ~8833’ a. Notify AOGCC 24 hours in advance 2. MIT-T to 2,500psi a. Use calibrated crystal gauge for MIT Eline 1. Cut tubing mid joint @ ~8750 (or ~50’ above cement tag)with mechanical or jet cutter a. Avoid X nipple at 8777’ Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. 1. Spot Pump Truck, RU and PT. a. Circulate in at least 420 bbls of 1% KCl through tubing cut b. Annular Volume to cut: 231 bbls c. Tubing Volume to cut: 134 bbls d. Total volume to cut: 365 bbls 2. RDMO pumpers 3. RD well house and flowlines. Clear and level area around well. 4. Set BPV w/insert (TWC) and test. ND Dry Hole Tree and THA. 5. NU BOPE configured top down: Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Thunderbird 1 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/1% KCl as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird 1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 4-1/2”. No plans to run 4” workstring. If 4” workstring run required, repeat Step 3 BOP test with 2-7/8”joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Assess risk of pressure under the valve and utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~8750’ of 4-1/2” 12.6# tubing weighs ~97klbs (buoyed by 8.4 ppg fluid) b. If pulled up to 230 Klbs (80% of 4-1/2” yield strength) with no hanger movement, RU eline and perform 2nd tubing cut in cut window, discuss with OE. 6. POOH and lay down the 4-1/2” tubing. Recomplete to Kuparuk Well: S-37A PTD: 212-092 a. Save tubing for reuse if possible; discard joints with visible defects or damaged threads 7. RU Eline 8. Pull CBL from ~8500’ MD to surface to verify cement quality over Kuparuk interval a. Send copy of log to claire.mayfield@hilcorp.com b. Send copy of log with vendor TOC interpretation to AOGCC (email: Melvin.rixse@alaska.gov) c. If no cement, work with OE for plan forward, very likely will run kill string 9. PU 4-1/2” completion (re-using original 13Cr tubing if possible) and run per S-37A Proposed Completion Running Order. a. Load IA with inhibited KWF brine b. Land tubing with mule shoe/WLEG @ ~6700’ a. Packer must be within 200’ of top perf. (Kuparuk top ~6812’ MD) c. Ensure RHC plug body pre-installed in lowermost X profile 10. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 11. Drop ball and rod and hydraulically set the packer per manufacturer’s setting procedure a. Conduct MIT-T to 3500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed) 12. Shear circ valve in shallow GLM and circ freeze protect. 13. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 14. RDMO Thunderbird 1 Rig and ancillary equipment. Move to next well location. 15. RU crane. ND BOPE. 16. NU the tubing head adapter and production tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 17. Pull BPV with TWC insert. 18. Replace wellhouse and gauge(s) if removed. Post-Rig Procedure: Slickline 1. Spot Slickline unit, RU and PT. 2. RIH and pull RHC plug from X profile at ±6680’ MD 3. MIT-T to 3,500psi a.If issue with MIT, contact OE for possible dump 20-40 sand around tubing stub 4. Install LGLVs per GL engineer 5. RDMO and turn well over to operations. Eline 6. Perforate per geologist a. Charges will be 2-7/8” MaxForce or similar b. 6 SPF c. 60 deg Phasing Operations 7. POP well 8. Obtain AOGCC witnessed SVS test within 5 days of putting well online. MGR 150' reservoir abandonment plug to be tagged and pressure tested to 2500 psi within 12 months of sundry approval. Recomplete to Kuparuk Well: S-37A PTD: 212-092 NOTE: A separate frac sundry and program will be submitted. This program only covers the RWO. Details to be included in future frac program that will require a frac sundry: 1. Slickline dummy GLVs, load hole with 1% KCl and freeze protect, obtain 3500 psi MIT-IA 2. Special Projects frac well 3. Contingent post frac coil FCO 4. Slickline install LGLVs 5. Well testers POP well for frac flowback 6. Handover to OPs Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Nordic 3 BOP Stack Recomplete to Kuparuk Well: S-37A PTD: 212-092 Current WBD: Recomplete to Kuparuk Well: S-37A PTD: 212-092 Proposed WBD: Recomplete to Kuparuk Well: S-37A PTD: 212-092 Thunderbird 1 BOP Schematic Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: April 6, 2023Subject: Changes to Approved Sundry Procedure for Well S-37ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date AddendumtoSͲ37ARWOSundryRequest RecentlycompletedpreͲRWOscope: 1. SLtaggedcementplugat8719’SLMDon4/8/2023 2. MITͲTto2500psipassedon4/8/2023 3. ElinetaggedTOCat8734’MDwithjunkbasketon4/9/2023. 4. Elinecuttubingat8670’MDon4/9/2023 FutureAbandonmentofIvishak&SagReservoirPlan 1. CoiledTubingtolay~150’ofcementinsidethe7Ͳ5/8”casingdirectlyontopoftubingstubat 8870’toachievecementacrossallannuliintheconfiningzoneabovetheSagreservoir. Tagged and pressure tested to 2500 psi. State to witness. 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 thes pool? Will planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-37A Recomplete to Aurora Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-092 50-029-22291-01-00 341J / 457B ADL 0028257 11583 Surface Intermediate Liner Liner Liner 8656 2890 9076 247 1485 1280 11583 10-3/4" 7-5/8" 5-1/2" 3-1/2" x 3-1/4" 2-3/8" 8656 33 - 2923 32 - 9108 8894 - 9141 8869 - 10354 10303 - 11583 2336 33 - 2915 32 - 8643 8460 - 8672 8439 - 8677 8680 - 8656 None 2480 4790 6280 10530 11780 None 5210 6890 7740 10160 11200 10305 - 11561 4-1/2" 12.6# 13Cr80 30 - 89028680 - 8657 Conductor 75 20" 34 - 109 34 - 109 1490 470 4-1/2" Baker S3 Packer No SSSV Installed 8837, 8412 Date: Stan Golis Sr. Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY 3/1/23 Current Pools: PRUDHOE OIL Proposed Pools: Aurora Oil 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov ure approved herein wil January 19, 2023 By Samantha Carlisle at 12:34 pm, Jan 19, 2023 323-030 MGR02FEB23 BOPE test to 3000 psi. Annular to 2500 psi. 10-404 DLB 01/19/2023 State witness of pressure test (MIT-T to 2500 psi) and slick line tag (~TOC 8833' MD) of reservoir abandonment plug DSR-1/20/23 2336 X GCW 02/06/23JLC 2/6/2023 2/6/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.06 13:14:27 -09'00' RBDMS JSB 020723 Recomplete to Kuparuk Well: S-37A PTD: 212-092 Well Name:S-37A API Number:50-029-22291-01 Current Status:Producer SI Estimated Start Date:3/1/2023 Rig:Nordic #3 Sundry #Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:212-092 First Call Engineer:Claire Mayfield (907) 564-4375 (O)(713) 443-3631 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure:3196 psi @ 8599 TVD 7.2 PPG | (04/23/2012 static) 7.4 PPG with 2500’ freeze protect Max. Anticipated Surface Pressure:2336 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1400 psi (Taken on 11/22/21) Min ID:1.91” SLT LNR at 10303’ MD Max Angle:110 Deg @ 10,098’ MD 70 deg: 9318’ MD High DLS from 9160’-9410’ MD Formation Tops: Kuparuk: 6812’MD, 6711’TVD Kingak: 7934’md, 7820’TVD Sag: 9106 MD, 8642’TVD Shublik: 9149; 8678’TVD Sadlerochit 9287’ MD; 8794’TVD MITs: MIT-T: 2400 psi on 10/17/2012 MIT-IA: 3000 psi on 7/6/2012 Brief Well Summary: The Sag/Ivishak reservoir zones of S-37A no longer remain economically viable. The Kuparuk interval for S-37 motherbore is in between constant pressure boundaries S-112 and S-123 in a relatively low recovery factor area of the Kuparuk. The Sag/Ivishak reservoir will be abandoned, and a RWO is planned to recomplete to Kuparuk to test production rates and water cuts at the Kuparuk interval. S-37 and S-37A History: S-37 was originally drilled in 1992. The 13-1/2” surface hole was drilled to 2932’, 10-3/4” casing was set and cemented with 1756 cu ft of AS III. A top job was also completed with an additional 500cuft of AS I cement. The 10-3/4” casing was tested,the float shoe was drilled out and a leak off test was performed. The 9-7/8” hole was drilled to 9117’, and 7-5/8” casing was installed to 9106’ and cemented with 1305 cu ft of Class G. The 7-5/8” casingwas tested, the shoe was drilledout and the 6-3/4” holewas drilledto 9770’. The 5-1/2” liner and hanger was run in hole, circ’ed out and cemented with 157 cu. ft of Class G cement. They tested the casing and liner, thenranthe 4-1/2” tubingin the well. The tubingpackerwas set,andthe tubing wastestedbefore rigging down. The well initially produced from Ivishak zones 3 & 4. Water production remained high and oil rates slowly declined. Zone 3 was isolated with sand/cement in 1993 to isolate any water production from this zone and to improve hydraulics, but no major change in production was observed. S-37APB1drillingcommenced on August 11, 2012 to target the Sag Riverformation.The window was milled from 9,141’ to 9,154’ MD, with new formation / rat hole drilled to a depth of 9,162’ MD. Drilling proceeded to 9,900’ 2336 psi -00 DLB Recomplete to Kuparuk Well: S-37A PTD: 212-092 MD (-8,641’ TVDss), and awiper trip was initiated. Hole problems resulted in the coil being stuck for 2 hours and going back to bottom was deemed too risky. An OHST (S-37A) was then undertaken, described below. S-37A: OHST was initiated by setting the billet at 9,255’ MD in the Shublik. The well was steered into the Ivishak and was held horizontal until the Fault 1 zone was passed at 9,600’ MD where total loss of returns occurred. Drilling continued until the protective liner point in the Sag River was reached at 10,354’ MD (-8,607.7’ TVDss). The liner was successfully run to bottom and released. A second cementing attempt consisted of pumping 20 bbls of cement, which was quickly lost to the formation. An FIT was run after milling the shoe, which indicated cement integrity between the formation and the lower liner/shoe. Drilling proceeded to 11,583’ MD (-8,586.8’ TVDss). A slotted liner was then run through the lateral Sag River production interval. Notes Regarding Wellbore Condition x 09/20/2007: GLV C/O x 01/24/2010: GLV C/O x 05/21/2011: Set TTP; Set DSSSV; MIT-T to 2000psi x 01/29/2012: Dummied GLVs x 02/03/2012: MIT-IA passed to 3000psi x 02/04/2012: MIT-OA, LLR 5bpm @ 1250psi, caliper tubing – all jts <20% x 7/26/2012: MIT-IA Passed to 3000 psi x 9/2/2012: CTD sidetrack S-37A x 10/17/2012: MIT T Passed to 2400 psi. x 10/18/2012: Pulled DGLVs from Sta# 5 & 6. Set LGLV Sta# 6, & OGLV Sta# 5. x 10/21/2012: C/O LGLV @ Sta # 6. x 04/01/13 GLV C/O x 8/07/2015: CTU CBL of liner from 8700-10,300’MD; TOC 9640’ x 08/08/2015: CTU mill scale, SCMT, & mud acid x 09/16/2015: Scale Inhibition Treatment pumped x 05/04/2016: GLV C/O x 02/02/2017: EL pprof to test LTP, pprof showed 100% prod coming from Sag slotted liner x 07/13/2021: GLV C/O x 11/22/2021: SL Drift dmy whipstock to 2500 The most recent caliper performed 2/2012 shows an average wall loss around 8%. This tubing should be re- usable, a second caliper can be performed pre-RWO. Objective: x Reservoir abandon Ivishak & Sag, Recomplete to Kuparuk Procedure: Pre-Rig – 1. Obtain updated pressure tests on WH seals Slickline & Fullbore 1. Drift for LTP, broach scale as needed 2. Load tbg & IA with 1% KCl or SW + Freeze protect a. Total IA volume to St#1: 221 bbls Recomplete to Kuparuk Well: S-37A PTD: 212-092 b. Freeze protect volume to 2500’: 115 bbls 3. Dummy GLVs 4. Obtain 3500 psi MIT-IA (ensure all DGLV’s set) 5. Pull LTP @ 8863 6. Run caliper from liner top to surface 7. Injectivity test with KCL pre-Fullbore P&A a. Bullhead 210bbls of 1%KCL or SW down the TBG into formation i. Note pressures and rates ii. Max pressure ~2,500psi b. Freeze protect with 38bbls of diesel c. Send rate/pressure information to OE for final cement design d. Note IA pressure during pumping operations Well Support – Prep Tree and WH for P&A work 1. Pull production tree 2. Install dry hole tree for P&A work 3. Drop IA casing valves and install integral valves ----------------------------------------------Sundry Required Before Proceeding-------------------------------------------------- Fullbore P&A of Ivishak completion: 1. Pump Reservoir abandonment plug per schedule below. Planned TOC is 8833’ MD, in the confining zone above the Sag River formation. a. 5bbls meth spear b. 10bbls fresh water spacer c. 33.3bbls 14ppg class G cement d. 5 bbls fresh water spacer e. Foam wiper ball f. 130 bbls diesel displacement – Warm 2. Note pressure after shutting down pump, do not bleed WHP after cement is in place 3. Max treating pressure during cement job is 3,500psi 4. Before starting the cement job confirm displacement pump metering accuracy to avoid over/under displacing cement. Cement Type/weight:Class G 14 ppg Slurry Temperature:between 80° and 110°F Fluid Loss:20-100cc/30 min Compressive Strength: 1000 psi in 48 hrs. Thickening Time:Minimum 8 hours Install BPV or TWC in tubing hanger profile. Pressure test. Recomplete to Kuparuk Well: S-37A PTD: 212-092 Slickline: 1. WOC. Drift and tag TOC ~8833’ a. Notify AOGCC 24 hours in advance 2. MIT-T to 2,500psi a. Use calibrated crystal gauge for MIT Eline 1. Cut tubing @ 8810’ with mechanical or jet cutter a. Midway in jt below X nipple Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. 1. Spot Pump Truck, RU and PT. a. Circulate in at least 420 bbls of 1% KCl through tubing cut b. Annular Volume to cut: 231 bbls c. Tubing Volume to cut: 134 bbls d. Total volume to cut: 365 bbls 2. RDMO pumpers 3. RD well house and flowlines. Clear and level area around well. 4. Set BPV w/insert (TWC) and test. ND Dry Hole Tree and THA. 5. NU BOPE configured top down: Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Nordic 3 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/1% KCl as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Nordic #3 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 4-1/2”. No plans to run 4” workstring. If 4” workstring run required, repeat Step 3 BOP test with 4” joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Assess risk of pressure under the valve and utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~8450’ of 4-1/2” 12.6# tubing weighs ~ 94klbs (buoyed by 8.4 ppg fluid) b. If pulled up to 230 Klbs (80% of 4-1/2” yield strength) with no hanger movement, RU eline and perform 2nd tubing cut in cut window, discuss with OE. 6. POOH and lay down the 4-1/2” tubing. a. Save tubing for reuse if possible; discard joints with visible defects or damaged threads Recomplete to Kuparuk Well: S-37A PTD: 212-092 7. RU Eline 8. Pull CBL from sand top @ ~7965’ to surface to verify cement quality over Kuparuk interval a. Send copy of log to claire.mayfield@hilcorp.com b. Send copy of log with vendor TOC interpretation to AOGCC c. If no cement, work with OE for plan forward, very likely will run kill string 9. PU 4-1/2” completion (re-using original 13Cr tubing if possible) and run per S-37A Proposed Completion Running Order. a. Load IA with inhibited KWF brine b. Land tubing with mule shoe/WLEG @ ~6700’ a. Packer must be within 200’ of top perf. (Kuparuk top ~6812’ MD) c. Ensure RHC plug body pre-installed in lowermost X profile 10. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 11. Drop ball and rod and hydraulically set the packer per manufacturer’s setting procedure a. Conduct MIT-T to 3500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed) 12. Shear circ valve in shallow GLM and circ freeze protect. 13. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 14. RDMO Nordic 3 WO Rig and ancillary equipment. Move to next well location. 15. RU crane. ND BOPE. 16. NU the tubing head adapter and production tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 17. Pull BPV with TWC insert. 18. Replace wellhouse and gauge(s) if removed. Post-Rig Procedure: Slickline 1. Spot Slickline unit, RU and PT. 2. RIH and pull RHC plug from X profile at ±6680’ MD 3. Dump 30’ of 20-40 sand on top of tubing stub a. Packer to top of stub: ~27’ 4. After dumping all the sand, tag top of sand to verify fillup, dump more sand as needed. POH a. Top of sand should be right at/above the tubing stub 5. MIT-T to 3,500psi 6. Install LGLVs per GL engineer 7. RDMO and turn well over to operations. Eline 8. Perforate per geologist a. Charges will be 2-7/8” MaxForce or similar b. 6 SPF c. 60 deg Phasing email: melvin.rixse@alaska.gov Recomplete to Kuparuk Well: S-37A PTD: 212-092 Operations 9. POP well 10. Obtain AOGCC witnessed SVS test within 5 days of putting well online. NOTE: A separate frac sundry and program will be submitted. This program only covers the RWO. Details to be included in future frac program that will require a frac sundry: 1. Slickline dummy GLVs, load hole with 1% KCl and freeze protect, obtain 3500 psi MIT-IA 2. Special Projects frac well 3. Contingent post frac coil FCO 4. Slickline install LGLVs 5. Well testers POP well for frac flowback 6. Handover to OPs Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Nordic 3 BOP Stack Recomplete to Kuparuk Well: S-37A PTD: 212-092 Current WBD: Recomplete to Kuparuk Well: S-37A PTD: 212-092 Proposed WBD: Recomplete to Kuparuk Well: S-37A PTD: 212-092 Nordic Rig 3 BOP Schematic Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: January 18, 2023Subject: Changes to Approved Sundry Procedure for Well S-37ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, June 13, 2017 10:52 AM To: Regg,James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO Well Integrity Well Information Subject: Producer S-37A (PTD#2120920) High Inner Annulus Pressure Over NOL Attachments: S-37A.pdf Mr. Regg, Producer S-37A (PTD#2120920) was reported to have high inner annulus pressure over NOL on 6/12/17. The pressures were reported to be T/I/0 = 280/2020/Opsi. The high pressure event occurred during a pad shut down and appears to be caused by a spike in the gas lift supply header pressure. The plan forward is to bleed the IA and perform follow up monitors to ensure this is not an integrity issue; if we see any repressurization the well will be made under evaluation at that time. Please reply with any questions, Joshua Stephens JUN 1 2017 Well Integrity Engineer �(�N Office: 907-659-8110 Cell: 907-341-9068 w 1 • • • 4,000 - 3,800 3.500 3,400 3.200 3,000 - 2.800 2,500 2,400 2,200 - 2,000 1.800 - 1,500 1,400 1,200 - 1,000 - 800 500 400 - 200 STT � � TT�MTR 03'13:1; 03,20'17 032717 O4:03:17 O4:1O:17 O417;17 2 �I is o I I i • I 1 1 1 1 1 I I I I I I I 11 3 o Q 111 X (0 I 2 t 0�Z O L Y 3-1 O. Zu O N a a c c o f4 N 'c +T+ '6 n3 O a aco 7 Q i0 L u E C Q 7 O W �' a a O s m d l7 C C ' ' Q'-J + 'pa) u E + t O N { (0 (C a1 +✓ L Vf ( O IL LL V- C -C N W CO N C 0 a 2 4 44, L C a N N h O ..d f0 O U Z n' i j -0 v QI O O C L ra a -0 N U W 0 0 0 0 0 OD C 0 O } W W W W W VI a) 'L U rF I- LL U. 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(� p Q o O y D 'I a a —y rn C '0 0 o CO a m o o ao) 0 o a) a. m H H 0 3 moo ~ w w _j J w ? 0 a 0 10 0 Ce I co M 9 O N O .41-- ‘-• r N O O N Z r^ Ny od 0 ,! 0 Ncip co N D O z ' F a a 31 J U O z 6 co 1a co rN J 0 Ce Q N O o W o Ce J a W w -J U m o Z < y CO` N d = J o0. irs C.75 I 1 elmI CI EN 1 a. et E co U � 0 0 J E N Q E O r� U a N Z N O N a .- i' Ca m o o ca o 0 Q a o Ili z0 E 1 E o • 0 IOW co z I d • coc c N � m 0 ° N NI a• MD C UO E 0 m o o CO CI 0 U 0 RECI> MAKER PRINT DISTRIBUTION LIS' I" 2 "': N�JGI�ES ' Vicc% yy ltt,,,� } -_C)C COMPANY BP Exploration (Alaska) Inc. INTERMEDTE W`i� FINAL Yes (mandatory,, WELL NAME RUN NUMBER _ (mandatory) FIELD Prudhoe Bay BH SALESMAN Chris Klotz (mandatory) (mandatory) COUNTY_ North Slope Borough BH DISTRICT Alnc4a (mandatory) STATE Alaska (mandatory) LOG DATE: (mandatory) DISTRIB (mandatory) PAGE OF TODAYS DATE: 4/3/2013 UTION LIST AUTHORIZED BY: BP Exploration (Alaska) Inc. mlandatory; HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION tsr Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn Ricky Elgarico PO Box 100360 Anchorage, Alaska 99510 Q 3 ExxonMobil, Alaska Attn Lynda M. Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Alaska 99503 4 State of Alaska - AOGCC Christine Shartzer 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas Attn: Sean Clifton 550 W. 7th Ave, Suite 800 Anchorage, Alaska 99501 TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: FIELD FINAL CD (digital / LOGS LOGS image) FILM 1# # OF PRINTS # Ur HHIN 15 # OF COPIES OF COPIES M n 4- 4� 4 4 3 1 1 1 CANNED C C T 2 2014 1 1 1 0 5 5 0 0 0 0 5 5 0 0 0 egil JD RECEIVE'D riit- AY 2920; , E� _ ;t P I INT DISTRIBUTION LIST HUGHESG C COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) 212-0c)2 WELL NAME RUN NUMBER �10/^ (mandatory) I I FIELD Prudhoe Bay BH SALESMAN Chris Klotz (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE: 4/3/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? 0 COMPANY ' FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION ,#OF PRINTS #Ur PHIN I S #OF COPIES #OF COPIES 111 4 4 4 L. 1 BP Exploration(Alaska)Inc. I 1 3 I 1 I Petrotechnical Data Center k LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I I 1 I I I Attn Ricky Elgarico PO Box 100360 Anchorage,Alaska 99510 3 ExxonMobil,Alaska 1 1 I 1 I I I Attn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 _ J 4 State of Alaska-AOGCC 1 I 1 I 1 I I I Christine Shartzer 1,333 West 7th Ave,Suite 100 11 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas 1 I 1 I I I Attn:Sean Clifton • X550 W.7th Ave,Suite 800 [Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 0 5 5 0 0 0 TOTALS FOR ALL PAGES: 0 5 5 0 0 0 Letter of Transmittal ru BAKERDate: n G� w G U► � October 2, 2012 OCT 12 20 12 HUGHES r To: al From: State of Alaska AOGCC Baker Hughes INTEQ 333 W. 7`h Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): --I C-09BPB 1 C-09B 0 Le C2 C-03CPB 1 C-03C --O.6- C-24BPB 1 C-24B a I 0/4,3 B-27B ;, 1?..— (3 07-22A i CY'? S-3 7APB 1 • %` /1/S-32A — oZ J `" d _ S-12B (� . ( ( ( Enclosed for each well(s): 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files 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 to acknowledge receipt of this data. RECEIVED BY: , State of Alaska AOGCC DATE: - bp Date 14-DEC-2012 0 Transmittal Number: 93270 FittitIVED . BPXA WELL DATA TRANSMITTAL DEC 14 2012 Enclosed are the materials listed below. AOGCC (BPXA FIELD LOG DATA) If you have any questions,please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data& Electronic Log Prints for the following wells: B-27B X2,2=0373 2-22, C-03C 2_v2 O%i 22 c..,9 C-03CPB1 C-09B ZvZ 0G 0,2_25610 C-09BPB1 C-24B- .1—ez.x2:0G'St2276Z I C-24BPB1 S-12B -2k2- .\ 2-2112- S-32A 2_v-z___0 .6 2 22%-.1 ' S- 2- 09 2.,22` S-37AP61 Z-34 2--\2---OG k. 22 e, , / 1 if,k, .4i- ,__J,P ' c--- 1...X.- " Ill ' I oZ , 4)\,4' 13 7 .... 4, , I / / , >,� Please Sign and Return`sne copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 Davies, Stephen F (DOA) From: Lastufka, Joseph N [Joseph.Lastufka@bp.com] Sent: Tuesday, February 12, 2013 4:54 PM To: Davies, Stephen F (DOA) Subject: RE: PBU S-37 and S-37A Surface Location Question Attachments: PBU S-37, 10-05-92.pdf Steve, The recent completion report(s) used the As-Built for the surface locations (and x-y coordinates) which I have attached for you, the N/S, E/W offsets match with our converter as well... I am under the impression that the recently submitted location is the correct one. Please let me know if you would like for me to alert you in the future when I submit a corrected surface location (depending on how different from the original). Hope that I've explained it well, if you have any questions please don't hesitate to let me know. Thanks! Joe Lastufka Alaska Wells Technologist Cell: (907) 227-84961 Office: (907) 564-4091 wt� BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788D1Anchorage,AK From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, February 12, 2013 4:37 PM To: Lastufka, Joseph N Subject: PBU S-37 and S-37A Surface Location Question Joe, The original completion report for PBU S-37 (Permit 192-099) gives the surface location of the well at 1684 FNL, 1929 FWL,Sec, 35, T12N, R12E, UM BP's Well Completion Reports for PBU S-37 and S-37A submitted on 11/9/2012 list the surface location at 1647 FNL, 1922 FWL, Sec, 35,T12N, R12E, UM Could you check this and let me know which is correct? Thanks, .Z-/2--rCl 2.__- 27 26 25 51 I 39%'44' N 1 -1 I i ! fj1S PAD 1 �4 II %U5 36 _ �.4`` T.12N, S PAD 3 T.11 N. 2 VICINITY MAP I c 30 131 33 d 29 936 32 103635i 11363/12A 13 + ,. . 4000' 1--\ , E. 1 1 I5 iLEGEND 1 + AS-BUILT WELLS 11 I 1 t ! ! -4- EXISTING WELLS ! j U,,, % inar G-),•` •9 i/ op / 0' F. ROBERT BELL NOTE ��**. . 3252-S .,• �4 ID 1. DARETE OF SURVEYE FLY OBCT. 2, 199OA 2. ,ti /'FSSI2 • `` (PGS. 25 THRU 29). ����������, 3. ALASKA STATE PLANE COORDINATES SURVEYOR'S CERTIFICATE ARE ZONE 4, ALASKA, NAD27. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LOCATED WITHIN PROTRACTED SECTION 35 T. 12 N , R. 12 E., U.M.. AK. LAND SURVEYING IN THE STATE OF WELL A.S.P. PLANT GEODETIC CELLAR BOX SECTION ALASKA AND THAT THIS PLAT REPRESENTS NO. COORDINATES COORDINATES POSITION ELEV. OFFSETS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL Y-5979855.20 N.1729.40 1 70'21'12.905" FNL 1640' DIMENSIONS AND OTHER DETAILS ARE 33 x= 619649.56 E.1000.09 149'01'42.249' 35.60' FWL 1487' CORRECT AS OF OCT. 2. 1992. Y-5979854.96 N.2023.90 70'21'12.856" . FNL 1645' 3 4i x= 619944.03 E.1000.45 149'01'33.643" 36.04' FWL 1782' F. R. BELL & ASSOCIATES Y=5979855.10 N.2060.40 7021'12.852" FNL 1645' 35i x= 619980.53 £.1000.31 149'01'32.576" 35.74' FWL 1818' BP EXPLORATION I P Y=5979855.04 N.2130.56 70'21'12.640" FNL 1646' ` 35.84' 36i x= 52nn5(1 FR F.1000.41 149'01'30.525" FM.. 1888' 1 ngAwur,uLur• 7 I Y-5979854.57 J N,2164.17 70'21'12.830" 35.64' I FNL +647' j S PAD D x= 620084.30 £.1000.89 149'01'29.543" FWL 1922' f_r1 Y=5979855.01 N.1911.91 7021'12.874" FNL 1643' CONDUCTOR AS-BUILT x= 619832.05 £.1000.35 149'01'36.915" 36.84' EWL 1670' WELLS 33, 34i, 35i, 36i, 37 & 381 DAIS: PRAWN: INLCR: 10/5/92 MINISH FENTIE SCACE; RR.: AFL& \ADD ME A 0 10/5/92 ISSUED FOR INFORMATION ADM JMF 1"=400' XS* Ale Jp6/113AMIW F YRt l: RtVR REV NO. DATE REVISIONS DRAWN CHECK I SK-SPADAB 1 or 1 0 RECEIVED STATE OF ALASKA NOV 13 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LAGJGOC la. Well Status. • ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 1b. Well Class 20AAC 25105 20AAC 25 110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One • IN Development 0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband: 12 Permit to Drill Number: BP Exploration(Alaska) Inc. 10/17/2012 212-092 • 3. Address. 6. Date Spudded: ..,,,/(. 2L)/z. 13. API Number. P.O. Box 196612,Anchorage,Alaska 99519-6612 5./.1•212012 ,jp 1.12.-/3 50-029-22291-01-00 • 4a. Location of Well(Governmental Section). 7.Date T.D.Reached: 14. Well Name and Number: Surface: 8/31/2012 • PBU S-37A • 1647'FNL, 1922' FWL, Sec. 35,T12N, R12E, UM 8. KB(ft above MSL): 69.30' 15.Field/Pool(s) Top of Productive Horizon: 1974' FNL,3665'FWL, Sec. 35,T12N, R12E, UM GL(ft above MSL): --35.64' Prudhoe Bay/Prudhoe Bay , Total Depth: 9. Plug Back Depth(MD+TVD) 4128' FNL,4331'FWL, Sec.35,T12N, R12E, UM 11561' 8657' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 620084• y- 5979855• Zone- ASP4 11583' 8656' • ADL 028257 ' TPI: x- 621833 y- 5979556 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 622536 y- 5977413 Zone- ASP4 None 18 Directional Surve Y: 19 Water depth,if offshore: 20 Thickness of Permafrost(TVD): ®Yes ❑No (Submit electronic and printed information per 20 AAC 25 050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071) 22. Re-Drill/Lateral Top Window MD/TVD. MWD/GR/RES, GR/CCL 9141' 8672' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 76' Surface 76' 30" 11 yds Arctic Set 10-3/4" 45.5# NT-80 36' 2923' 36' 2915' 13-1/2" 1756 cu ft AS III,500 cu ft AS I 7-5/8" 29.9# NT-95HS 32' 9106' 32' 8642' 9-7/8" 1305 cu ft Class'G' 5-1/2" 17# 13Cr80 8894' 9141' 8460' 8672' 6-3/4" 157 cu ft Class'G' 3-1/2"x 3-1/4", 9.3#/6.6# L-80 8863' 10354' 8434' 8677' 4-1/4" 96 sx Class'G', 106 sx Class'G' 2-3/8" 4.7# L-80 10303' 11583' 8680' 8656' 3" Uncemented Slotted Liner 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND) (MD+TVD of Top&Bottom;Perforation Size and Number): _ 2-3/8"Slotted Liner 4-1/2", 12.6#, 13Cr80 8902' 8837'/8412' 26 ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10305'-11561' 8680'-8657' WAS HYDRAULIC FRACTURING USED DURING COMPLETION? 0 Yes ®No `;1) ';'-:.-",:•N, : DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ji t" Freeze Protect w/40 Bbls of Diesel i :MA 1 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc October 22,2012 Gas Lift Date of Test Hours Tested Production For OIL-BBL: GAS-MCF WATER-BBL. CHOKE SIZE: GAS-OIL RATIO: 10/28/2012 6 Test Period 4 157 877 11 176 5581 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF. WATER-BBL: OIL GRAVITY-API(CORR): Press. 300 A 1300 24-Hour Rate 4 628 3506 44 Not Available 28. CORE DATA Conventional Core(s)Acquired? 0 Yes 0 No . Sidewall Core(s)Acquired? 0 Yes 0 No . 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 250.071. NondFIBOMS NOV 14 2011! 'l" t� Form 10-407 Revised 10/2012 CONTINUED ON R V E .Z,7.(Z Submit Original Only V /Z 7 / .SSL •2 iP1'3 29. GEOLOGIC MARKERS(List all formations ar •kers encounter 30 FORMATION TESTS NAME rviJ TVD Well Tested? ,J Yes ®No • Permafrost Top If yes,list intervals and formations tested,briefly summarizing test results. Attach separate sheets to this form,if needed,and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9106' 8642' None Shublik 9150' 8679' Sadlerochit 9287' 8769' Shublik(Invert) 9934' 8779' Sag River(From Base) 10218' 8695' Formation at Total Depth: Sag River(From Base) 10218' 8695' 31.List of Attachment Summary of Daily Drilling Reports, Summary of Post-Rig Work,Well Schematic Diagram,Surveys 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Matt Ross,564-578 •rossmo@bp.com Email: lastuf@bp.com Title. Drilling Technologist Printed Name: .- . tufka Signature' ,k. Phone 564-4091 Date: 1 J/j_//.1_, 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. Item la: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. 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 4b: TPI(Top of Producing Interval) Item 8: The Kelly Bushing and Ground Level elevation 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 13 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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Form 10-407 Revised 10/2012 Submit Original Only BP AMERICA LOT / FIT Summary Well Name: S-37A Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 08/28/12 FIT 10,380.00 8,606.00 8.50 1,000.00 4,803.00 10.73 Page 1 of 1 : . r North America -ALASKA- BP --� . Page 1 of 36 Operation Summary Report . . . Common Well Name:S-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 1X3-0011 WF(3,050,122 00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time. 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/8/2012 18:00 - 00:00 6.00 MOB N WAIT PRE BEGIN RON EVENT WITH NORDIC 2 CTD RIG AT 18:00. STAGE RIG ON CC2A WHILE WAITING FOR DOYON 25 RIG TO CLEAR SPINE ROAD. CONTINUE MAINTENANCE-TYPE ACTIVITIES. PREP AND PAINT EXTERIOR OF RIG. INSTALL BOP RAMS. PERFORM GENERAL CLEANUP AROUND RIG. CONFIRM CLOSURE OF RIG CONDITION/ENVIRONMENTAL ACCEPTANCE AUDIT ACTION ITEMS. 8/9/2012 00:00 - 04:30 4.50 MOB N WAIT PRE STAGE RIG ON CC2A WHILE WAITING ON DOYON 25 RIG TO CLEAR SPINE ROAD. CONTINUE TO PREP AND PAINT EXTERIOR OF RIG. COMPLETE INSTALLATION OF RAMS INTO BOP STACK. PERFORM GENERAL CLEANUP OF RIG FOLLOWING MAINTENANCE PERIOD. PREPARE RIG TO MOVE. 04:30 - 05:00 0.50 MOB _P PRE HOLD PREJOB SAFETY MEETING AND MOVE RIG OFF HERCULITE. STAGE RIG ON EDGE OF PAD. CLEANUP MAINTENANCE -- LOCATION. 05:00 - 07:00 2.00 MOB N WAIT PRE STAGE RIG ON PAD. WAIT ON SECURITY AND CREW CHANGE FOR RIG MOVE. TP AND DRILLER MAKE ACTUAL ROUTE _ DRIVE TOGETHER TO S PAD. 07:00 - 08:00 1.00 MOB P PRE HOLD PJSM FOR MOVE TO S PAD. REVIEW ROUTE DRIVE HAZARDS. DISCUSS COMMS AND POSTIONS FOR EACH HAND. JACK UP RIG. MAKE LAST MINUTE WALK AROUND AND CHECKS. 08:00 - 12:30 4.50 MOB P PRE MOVE RIG FROM CC2-A PAD. FOLLOW SPINE ROAD OVER KUPARUK RIVER BRIDGES. 12:30 - 14:00 1.50 MOB P PRE RIG AT ACCESS ROAD TO S PAD. RIG ON S-PAD AT 1400 HRS(TOTAL MOVE TIME=6 HOURS) 14:00 - 17:00 3.00 MOB P PRE SET RIG MATS AROUND S-37 WELLHEAD AND PREPARE LOCATION. 17:00 - 18:00 1.00 MOB P PRE SPOT AND CENTER RIG OF WELL. -WELLWORK TRANSFER PERMIT OPEN WITH PAD OPERATOR. -ALL VALVES ON TREE AND WELLHEAD CLOSED FOR PULLING OVER WELL. -INITIALT/I/O=TWC/0/0 PSI -ALL PRE-RIG WORK VERIFIED COMPLETE. DOUGLE GATE VALVES INSTALLED ON OA FOR FAILED MIT-OA. -S-11 AND S-05 WING VALVE LOCKED OUT BY WSL AND PAD OPERATOR FOR ANTI-COLLISION -PRE-SPUD MEETINGS HELD WITH BOTH CREWS 18:00 - 20:00 2.00 RIGU P PRE BERM UP AROUND RIG,GENERAL RIG UP OPERATIONS. Printed 10/29/2012 10.37.24AM North America -ALASKA- BP • Page 2 of 36 O.eration Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 21:00 1.00 BOPSUR P PRE ACCEPT NORDIC 2 CTD RIG AT 20:00 ON 8/9/2012. PRESSURE UP DOWN WING VALVE AGAINST CLOSED SSV AND CLOSED SWAB VALVE TO 3000 PSI AND CONFIRM LEAK TIGHT (PROPER STEM EXPOSED ON SSV AND CORRECT#TURNS ON SWAB)TO ESTABLISH BARRIERS FOR BREAKING CONTAINMENT(PASSING TEST). NIPPLE DOWN TREE CAP FLANGE. SPOT SATELLITE CAMP AND OTHER SECONDARY EQUIPMENT. 21:00 - 23:00 2.00 BOPSUR P PRE NIPPLE UP 7-1/16"5K BOP STACKTO4-1/16" SWAB FLANGE WITH FOLLOWING CONFIGURATION FROM TOP DOWN: -HYDRIL GK ANNULAR -TOT BLIND-SHEAR RAMS WITH BOOSTERS -TOT 2-3/8"-COMBI PIPE RAM/SLIPS -FLOW CROSS WITH 2-3/16"INNER HCR VALVE AND 2-1/16"OUTER GATE VALVE ON BOTH KILL AND CHOKE LINE TOT 2-3/8"X 3-1/2"VB RAMS TOT 2-3/8"COMBI PIPE RAM/SLIPS LIFT 2-3/8"COILED TUBING REEL INTO REEL HOUSE 23:00 - 00:00 1.00 BOPSUR P PRE INSTALL LUBRICATOR AND PACKOFF ON TOP OF BOP STACK TO EXTEND PRESSURE CONTROL EQUIPMENT UP TO RIG FLOOR. 8/10/2012 00:00 - 01:30 1.50 BOPSUR P PRE COMPLETE RIGGING UP LUBRICATOR, PACKOFF AND INJECTOR. HARDLINE CREW ON LOCATION TO RIG UP FLOWBACK TANK AND HARDLINE. 01:30 - 02:30 1.00 RIGU P PRE HOLD RIG EVACUATION DRILL AND AAR WITH ALL ON LOCATION. 02:30 - 04:00 1.50 BOPSUR P PRE RIG UP TO PRESSURE TEST BOPE. RECORD RIG FLOOR TO BOP ELEMENT MEASUREMENTS. FILL ALL LINES AND FLOW THROUGH MUD GAS SEPARATOR. RIG UP REEL HARDLINE. 04:00 - 12:30 8.50 BOPSUR P PRE PRESSURE TEST BOPE PER ADWOP AND AOGCC REGULATIONS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH. STATE'S RIGHT TO WITNESS WAIVED BY AOGCC REPRESENTATIVE BOB NOBLE. -PRESSURE TEST ANNULAR PREVENTER WITH 2-3/8"TEST JOINT -PRESSURE TEST VBRS WITH 2-3/8"&3-1/2" TEST JOINT. -TEST AND CALIBRATE GAS ALARMS. -FUNCTION ALL COMPONENTS FROM ALL CONTROL STATIONS -NO FAILURES DURING TESTING. -SEE ATTACHED DOCUMENTATION REPORT AND CHARTS. Printed 10/29/2012 10:37:24AM • ' ' North America -ALASKA- BP11110 g Page 3 of 36 O.eration Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time:11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 15:00 2.50 MOB P PRE HOLD PJSM TO PULL COIL ACROSS TO INJECTOR. RU TUGGER CABLE. TEST SAME. PULL COIL ACROSS PIPE SHED ROOF. ENGAGE AND FULLY STAB IN TO INJECTOR. 15:00 - 16:30 1.50 MOB P PRE FILL COIL WITH KCL. VERIFY SLB PUMP GAUGES IN AGREEMENT WITH NORDIC "-GAUGES. 16:30 - 17:30 1.00 BOPSUR P PRE PRESSURE TEST INNER REEL VALVE AND PACKOFFS 250 PSI AND 3500 PSI. PASSED. CHART SAME. 17:30 - 20:00 2.50 MOB P PRE RIG UP AND PUMP E-LINE SLACK BACK IN COIL. 20:00 - 21:45 1.75 MOB P PRE CUT 256'OF 2-3/8"COILED TUBING WITH HYDRAULIC CUTTER. 21:45 - 22:15 0.50 MOB P PRE INSTALL SLB COILED TUBING CONNECTOR AND PULL TEST TO 35 KLBS. 22:15 - 00:00 1.75 MOB P PRE SLB TECHNICIANS ON LOCATION TO ADJUST GOOSENECK AND CALIBRATE INJECTOR WEIGHT CELL FOR NEW INJECTOR INSTALLED DURING SUMMER _MAINTENANCE). 8/11/2012 00:00 - 01:00 1.00 MOB N SFAL PRE 'TROUBLESHOOT E-LINE JUNCTION BOX AT REEL DUE TO CONNECTIVITY ISSUE WHILE TESTING WIRE. 01:00 - 03:30 2.50 MOB P PRE MAKEUP BHI E-LINE HEAD AND TEST(PASS). PUMP E-LINE SLACK FORWARD. 03:30 - 04:30 1.00 BOPSUR P PRE PRESSURE TEST INJECTOR LUBRICATOR AND DFCVS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS, SEE ATTACHED CHARD. PERFORM LEAK TIGHT TEST ON COILED TUBING CONNECTOR. 04:30 - 08:00 3.50 RIGU P PRE HOLD PJSM. RIG UP VALVE SHOP LUBRICATOR AND PRESSURE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). OPEN SWAB, SURFACE SAFETY AND MASTER VALVES. PULL TWC. PRESSURE ON WELL=VAC. CLOSE MASTER,SSV AND SWAB VALVES. BLEED OFF PRESSURE ON LUBRICATOR AND MONITOR FOR LEAK TIGHT(PASS). RDMO VALVE SHOP LUBRICATOR. 08:00 - 08:30 0.50 RIGU P PRE HOLD PJSM TO DISCUSS KILLING WELL. REVIEW VOLUMES, FLUIDS,MAX PRESS& RATE,VALVE ALIGNMENT. 08:30 - 09:30 1.00 RIGU P PRE HOLD RIG EVACUATION DRILL. RIG EVACUATED IN LESS THAN 2 MIN, INCLUDING VAC TRUCK DRIVERS. ALL HANDS COULD HEAR THE SIREN. SCS HEAD COUNT CORRECT. HOLD AAR IN SAT CAMP AFTER DRILL. DISCUSS WIND DIRECTION IN NEAR CALM CONDITIONS. Printed 10/29/2012 10:37:24AM • North America-ALASKA- BP • Page 4 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:0O:OOAM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 13:00 3.50 RIGU P PRE OPEN WELL. PUMP 5 BBLS MEOH. PUMP 250 BBLS KCL. 500-600 PSI WHP AT 5 BPM. CHECK ALL SURFACE EQUIPMENT FREQUENTLY AFTER MAINTENANCE. PUMP 150 BBLS USED FLO PRO MUD. MAX PRESSURE: 1025 PSI WITH 10 BBLS INTO PERFS. -SHUT DN. BLEED WHP. CIRC ACROSS THE TOP AND MONITOR WELL FOR 30 MIN. ESTIMATE LOSSES AT 25-30 BPM. CALL FOR ADDITIONAL USED MUD FROM NORDIC 1 RIG. 13:00 - 14:00 1.00 STWHIP P WEXIT HOLD PJSM. MU INTEQ/BAKER TT MILLING BHA AS PER WELL PLAN. BHA OAL= 121'. STAB COIL. TEST TOOLS. GET ON WELL. PRESS TEST QTS TO 250 AND 3500 PSI. CHART TEST. PASSES. 14:00 - 18:30 4.50 STWHIP P WEXIT DISPLACE KCL FROM COIL THROUGH EDC. RUN IN HOLE. STOP AND MAKE ADJUSMENTS TO NEW CT INJECTOR. CONTINUE TO RIH TO TIE-IN LOGGING DEPTH AT 8900'MD. LOG KINGAK JB MARKER GR SIGNATURE AT 8930'MD TO TIE-IN TO PDC LOG(APPLY-9' CORRECTION). 18:30 - 19:30 1.00 STWHIP P WEXIT LOG CCL FROM 9000'MD TO 8700'MD IN PREPARATION FOR PLANNING INTERMEDIATE DRILLING LINER TOP. RUN BACK IN HOLE TO 9100'MD. SLOW PUMP RATES,8.7 PPG,9141'MD: MP#1: 0.5 BPM= 1490 PSI,1 BPM= 1553 PSI MP#2: 0.5 BPM= 1509 PSI,1 BPM= 1750 PSI. eo- 19:30 - 20:15 0.75 STWHIP P WEXIT RUN IN HOLE FROM 9100'TO DRY TAG TOP OF WHIPSTOCK AT 9141.4. PICKUP 10', ESTABLISH PUMP RATE AT 2.6 BPM,2800 PSI A. AND RUN BACK IN HOLE TO TAG WHIPSTOCK f . = AT 9141.0'MD. ! 4 20:15 - 00:00 3.75 STWHIP P WEXIT KICKOFF NEW SIDETRACK AND MILL WINDOW IN 5-1/2"LINER FROM 9141.0'MD to 9144.2'MD AT MIDNIGHT;2.6 BPM IN,2.25-2.5 BPM OUT,2800 PSI FREESPIN,2950-3050 PSI PUMP PRESSURE, IA/OA=25/250 PSI. MW IN/OUT=8.7 PPG, ECD= 10 PPG. NO STALLS DURING START OF WINDOW. LOSSES TO FORMATION APPEAR TO BE c-'511/ HEALING WHILE MILLING. AVERAGE DURING TIME PERIOD=10-15 BPH. BLEED OA FROM 735 PSI TO 200 PSI IN<3 MIN,<20 GAL FLUID. Printed 10/29/2012 10:37:24AM North America-ALASKA- BP111 Page 5 of 36 • O•eration Summary Report ;.` f Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/12/2012 00:00 - 06:00 6.00 STWHIP P WEXIT MILL WINDOW IN 5-1/2"CHRQMELINER FROM 9.144.2'MD AT MIDNIGHT TO 9152'MD AT 6 AM;2.6 BPM,2800 PSI FREESPIN, 2900-3100 PSI PUMP PRESSURE,1-3 KLBS DHWOB. MW IN/OUT=8.7, ECD=10.1 PPG. IA/OA=250/500 PSI. NO STALLS OR SIGNS OF EXTRA LOSSES TO FORMATION WHEN EXITING LINER WITH MILLS. LOSSES TO FORMATION HAVE DROPPED TO <5BPH. 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS OPERATIONS AND RIG EQUIPMENT STATUS. MAKE ROUNDS AND CHECKS. CONTINUE TO MILL WINDOW. 06:30 - 09:30 3.00 STWHIP P WEXIT CONTINUE TO MILL WINDOW FROM 9151.4'. 2725 PSI FS AT 2.56 BPM IN/2.49 BPM OUT. 200 PSI MTR WORK. 0.49K#DHWOB. IA/OA/PVT:320 PSI/576 PSI/310 BBLS. BHP/ECD/TVD:4472 PSI/10.09 PPG/309 BBLS. MILL WINDOW TO 9153.5'. NO STALLS. NO INDICATION OF EXITING CASING BASED ON MILLING PARAMETERS. SAG CUTTINGS NOTED IN SAMPLES. 09:30 - 11:30 2.00 STWHIP P WEXIT DRILL NEW FORMATION.TO 9161 6' 11:30 - 13:45 2.25 STWHIP P WEXIT DRESS WINDOW WITH THREE SLOW UP/DOWN PASSES. 2908 PSI FS AT 2.57 BPM IN/2.54 BPM OUT. DRY DRIFT AT 10 FPM. WINDOW SMOOTH. 13:45 - 16:30 2.75 STWHIP P WEXIT FLOW CHECK WELL FOR 10 MINUTES. WELL STABLE. OPEN EDC. CIRCULATE OUT OF HOLE. 2505 PSI AT 3.12 BPM. 16:30 - 17:00 0.50 STWHIP P WEXIT AT SURFACE. GET OFF WELL. UNSTAB COIL. LD BHA. MILL GAUGED 3.79"GO/3.78"NO GO STRING REAMER:3.80"GO/3.79"NO-GO. • 17:00 - 18:45 1.75 DRILL P INTI MU INTERMEDIATE SECTION BUILD DRILLING, BHA. STAB ON WELL WITH INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS) -4-1/8"HUGHES BI-CENTER PDC,RWD 2ST3053.750QF, SLICK COATING -2-7/8"X-TREME HIGH SPEED MUD MOTOR, 2.6°BEND -3"COILTRAK TOOLS WITH RESISTIVITY AND DFCVS -BHAOAL=79' Printed 10/29/2012 10:37:24AM • „,North America -ALASKA- BP S Page 6 of 36 4•eration Summary Report Common Well Name:S-37 l AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:45 - 21:15 2.50 DRILL P INTI TRIP IN HOLE WITH DRILLING ASSEBMLY FROM BHA AT 79'MD TO PREVIOUSLY DRILLED TO DEPTH AT 9162'MD. LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLE-11'CORRECTION COMPARED TO PREVIOUS CORRECTION OF -9'). SLOW PUMP RATES,8.7 PPG,9162'MD: MP#1: 0.5 BPM=1548 PSI,1 BPM=1838 PSI MP#2: 0.5 BPM=1564 PSI,1 BPM=1828 PSI 21:15 - 00:00 2.75 DRILL P INTI DIRECTIONAL DRILL 4-1/8”INTERMEDIATE BUILD HOLE SECTION FROM 9162'MD TO 9204'MD AT MIDNIGHT(42' IN 2.75 HRS= 15 FPH) 2 5 BPM.2875 PSI FREESPIN 2950-3200 PSI PUMP PRESSURE.1-3 KLBS DHWOB MW 1N/OUT=8.7 PPG, ECD= 10.2 PPG, NO LOSSES TO FORMATION WHILE DRILLING AHEAD. PICKUP WEIGHT OFF BOTTOM= 30 KLBS IA/OA=350/250 PSI. DRILLING BUILD SECTION IN SHUBLIK BUILD RATES ARE APPROXIMATELY 25°/100' USING NEAR BIT INCLINATION. 8/13/2012 00:00 - 06:00 6.00 DRILL P INTI DIRECTIONAL DRILL 4-1/8"INTERMEDIATE BUILD HOLE SECTION FROM 9204'MD AT MIDNIGHT TO 9275'MD AT 6 AM(71'IN 6 HRS =12 FPI ;2.5 BPM,2875 PSI FREESPIN, 3000-3250 PSI PUMP PRESSURE,1-4 KLBS DHWOB. MW IN/OUT=8.7 PPG,ECD=10.3 PPG. NO LOSSES TO FORMATION WHILE DRILLING AHEAD. DRILLING BUILD SECTION IN SHUBLIK. TARGETING 30 0/100'DLS. BUILD RATES ARE APPROXIMATELY 27 0/100'USING NEAR BIT INCLINATION. NO OFFICIAL SURVEYS YET DUE TO PROXIMITY TO OLD WELLBORE. 06:00 - 06:30 0.50 DRILL P INTI CREW CHANGE. REVIEW CURRENT OPERATIONS AND RIG EQUIPMENT STATUS. • MAKE RIG CHECKS AND OUTSDIE ROUNDS. CONTINUE TO DRILL BUILD SECTION. 06:30 - 10:00 3.50 DRILL P INTI DRILL AHEAD FROM 9275'. 3010 FS AT 2.64 BPM IN/OUT. 200-300 PSI MTR WORK. 2.2K#DHWOB. IA/OA/PVT:355 PSI/333 PSI/414 BBLS. BHP/ECD/TVD:4634 PSI/10.28 PPG/8660'. 10:00 - 10:30 0.50 DRILL P INTI WIPER TRIP TO WINDOW. HOLE SMOOTH. 10:30 - 11:00 0.50 DRILL P INTI DRILL AHEAD FROM 9300'. Printed 10/29/2012 10:37:24AM North America -ALASKA-BP • Page 7 of 36 O•eration Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 IX3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63. 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:00 1.00 DRILL P INTI MICRO MOTION OUT INDICATING GAS IN RTNS. NOTE 16-18 UNIT AT POSSUM BELLY. DIVERT RTNS OUTSIDE TO FLOW BACK TANK. OBSERVE WHP. NO INCREASE. BRING RTNS BACK INSIDE. FLOW CHECK. TRACE OF FLOW ALTHOUGH NO INCREASE IN PIT VOLUME. ROUTE RTNS THROUGH -GAS BUSTER AND CIRCULATE 10 BBLS. GAS STILL INDICATED BY MICRO MOTION OUT. DECIDE TO SHUT IN WELL WITH HCR. CALL RWO&CTD SUPERINT AND WTL IN TOWN. GET APPROVAL TO CIRCULATE OUT _ WELL THROUGH CHOKE AND GAS BUSTER. 12:00 - 14:15 2.25 DRILL P INTI CIRCULATE BTMS UP WITH BHA ABOVE WINDOW,AND EDC OPEN. WHP INCREASED FRO 100 TO 135 PSI. NO PIT GAIN. WHP DROPPED TO 100(NOMINAL THROUGH GAS BUSTER FLOW PATH). CIRCULATE TWO COMPLETE BTMS UP. FLOW CHECK. NO FLOW OR WHP. CLOSE EDC.RIH TO 10'OFF BTM. CIRCULATE BTMS UP THROUGH GAS BUSTER AND CHOKE. -GET TRACE OF GAS ON MICRO MOTION OUT. NO GAS MEASURED AT POSSUM BELLY. MICRO OUT RETURNED TO CORRECT FLOW OUT READING. CONTINUE TO CIRCULATE BTMS UP. FLOW CHECK. NO FLOW. CALL WTL TO DISCUSS DRILLING AHEAD. 14:15 - 14:30 0.25 DRILL P INTI DRILL AHEAD FROM 9308'. 3010 PSI FS AT 2.57 BPM IN/OUT. DRILL TO 9317'. 14:30 - 15:00 0.50 DRILL P INTI ATTEMPT TO DRILL AHEAD AND HYDRAULIC ORIENTER QUIT WORKING_ PREP TO PULL OUT OF HOLE. FLOW CHECK ABOVE WINDOW. NOTE SLIGHT FLOW AT POSSUM BELLY. NO WHP OR PIT GAIN. POSSIBLE BREATHING. 15:00 - 15:30 0.50 DRILL N DFAL 9,317.00 INTI RUN IN HOLE TO 9310'. 15:30 - 16:30 1.00 DRILL N DFAL 9,317.00 INTI CIRCULATE BTMS UP THROUGH OPEN CHOKE AND GASBUSTER AS A PRECAUTION. 16:30 - 17:00 0.50 DRILL N DFAL 9,317.00 INTI MONITOR WELL AT POSSUM BELLY. SLIGHT FLOW DROPPED OFF. NO MEASUREABLE PIT GAIN. 17:00 - 18:30 1.50 DRILL N DFAL 9,317.00 INTI CIRCULATE OUT OF HOLE WITH EDC OPEN. MAINTAIN 100-200 PSI ON WELLHEAD. MONITOR TRIP VOLUMES CLOSELY. TRIP EVEN UPON REACHING SURFACE. 18:30 - 19:00 0.50 DRILL N DFAL 9,317.00 INTI PERFORM SHALLOW TEST OF COILTRAK TOOLS. CONFIRM UPPER PART OF COILTRAK TOOLSTRING IS WORKING, LOWER SECTION IS NOT. FLOWCHECK WELL PRIOR TO BHA ENTERING STACK. WELL STATIC. 19:00 - 20:00 1.00 DRILL N DFAL 9,317.00 INTI LAYDOWN HOT,DGS AND RESISITIVITY TOOLS AND PICKUP NEW OF SAME. GRADE BIT 2-4-RO-N-X-I-CT-DTF(SEE ATTACHED PHOTOS). CHANGEOUT BIT FOR SAME HUGHES MODEL WITH NO SLICK COATING. Printed 10/29/2012 10 37:24AM North America -ALASKA- BP 11110 Page 8 of 36 Q•#ration Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA I UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 20:00 - 21:00 1.00 DRILL P INTI SLB MECHANICS ONSITE TO CHANGEOUT COUNTER BALANCE VALVE ON INJECTOR. 21:00 - 22:00 1.00 DRILL N DFAL 9,317.00 INTI MU INTERMEDIATE SECTION BUILD DRILLING BHA(WELL BHA#3): STAB ON WELL WITH INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS) -4-1/8"HUGHES REBUILD BI-CENTER PDC, RWD2ST3053.750QF,SER#7026355 2-7/8"X-TREME HIGH SPEED MUD MOTOR, 2.6°BEND -3"COILTRAK TOOLS WITH RESISTIVITY AND DFCVS -BHA OAL=79' 22:00 - 00:00 2.00 DRILL N DFAL 9,317.00 INTI RUN IN HOLE FROM BHA AT 79'MD TO 5-1/2" LINER WINDOW AT 9141' MD AT MIDNIGHT. TRIP SHEET ACTUAL MATCHES CALCULATED DISPLACEMENT CIRCULATE IN HOLE ON MUD-GAS SEPARATOR. NO SIGN OF GAS-CUT MUD ON TRIP IN HOLE. SLB MECHANICS ON LOCATION MAKING ,MINOR ADJUSTMENTS TO INJECTOR ON TIH. LOG JB MARKER GR SIGNATURE IN KINGAK • FOR TIE-IN(APPLY-10'CORRECTION COMPARED TO PREVIOUS CORRECTION OF -11'). TOTAL NPT FOR BHI HYDRAULIC ORIENTING TOOL FAILURE=8 HOURS ON 8/13/12. 8/14/2012 00:00 - 00:45 0.75 DRILL N DFAL 9,317.00 INTI COMPLETE TRIP IN HOLE FROM WINDOW AT 9141'MD AT MIDNIGHT TO PREVIOUSLY DRILLED MD OF 9317'MD. NO HOLE ISSUES TRIPPING THROUGH OPENHOLE. Printed 10/29/2012 10:37:24AM North America-ALASKA- BP Page 9 of 36 O s eration Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00.00AM Rig Release: 9/2/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum:63 : 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:45 - 01:45 1.00 DRILL N DPRB 9,317.00 INTI BEGIN PLANNED BOTTOMS UP CIRCULATION THROUGH MUD GAS SEPARATOR(MGS). OBSERVE ISSUE WITH MICRO MOTION OUT METER AND RE-ROUTE RETURNS FROM MGS TO NORMAL FLOWLINE TO TROUBLESHOOT MICROMOTION METER. -00:45-SHAKER LEL ALARM SOUNDS WHILE CIRCULATING AND WELL IS IMMEDIATELY SHUT-IN WITH CHOKELINE HCR. INITIAL WELLHEAD PRESSURE=500 PSI AT PRESSURE GAUGE NEAR INJECTOR PACKOFF. 01:00-MAKE NOTIFICATIONS AND DISCUSS PLANS TO CONTROL WELL WITH WELLS TEAM LEADER AND OPS SUPERIENTENDENT. RECEIVE APPROVAL FROM WELL OPS MANAGER TO CIRCULATE BOTTOMS UP THROUGH CHOKE. PRESSURE ON WELLHEAD DROPS FROM 500 PSI TO 200 PSI OVER COURSE OF ONE HOUR MONITORING PERIOD. 01:45-EQUALIZE ACROSS HCR WITH 300 PSI AND OPEN WELL TO CLOSED CHOKE. MAINTAIN 300 PSI BACKPRESSURE ON WELLHEAD WHILE ESTABLISHING CIRCULATING AT 1 BPM,2150 PSI. 01:45 - 04:00 2.25 DRILL N DPRB9,317.00 INTI CIRCULATE 1.5 X BOTTOMS UP(140 BBLS)AT 1 BPM,2150 PSI(INCLUDING 300 PSI BACKPRESSURE HELD ON WELLHEAD) THROUGH MUD GAS SEPARATOR OBSERVE GAS CUT MUD(6.5 PPG)THROUGHOUT ENTIRE BOTTOMS UP AT END OF 140 BBLS. MW IN/OUT=8.7 PPG. LOSE 7 BBLS TO FORMATION DURING CIRCULATION. RECIPROCATE PIPE AT 2 FPM WHILE CIRCULATING. 04:00 - 06:00 2.00 DRILL N DPRB 9,317.00 INTI OPEN CHOKE TO REMOVE BACKPRESSURE FROM WELLHEAD AND CIRCULATE ONE BOTTOMS UP(95 BBLS)THROUGH MUD-GAS SEPARATOR AT 1 BPM,1850 PSI. RECIPROCATE PIPE AT 2 FPM WHILE CIRCULATING. MW IN/OUT=8.7 PPG. LOSE 5 BBLS MUD TO FORMATION WHILE CIRCULATING. BLEED IA FROM 425 TO 75 PSI IN 5 MIN TO CONFIRM NO COMMUNICATION BETWEEN IA AND TUBING. 06:00 - 06:30 0.50 DRILL N DPRB 9,317.00 INTI CREW CHANGE. DISCUSS OPERATIONS AND RIG STATUS. MAKE EQUIPMENT CHECKS AND ALL ROUNDS. CONTINUE TO CIRCULATE. CONTINUE TO MAKE ADJUSTMENTS ON CT INJECTOR. 06:30 - 07:30 1.00 DRILL N DPRB 9,317.00 INTI CONTINUE TO CIRCULATE AT 9000'. SLIGHT GAS NOTED BY MICRO MOTION OUT. NO INDICATION AT SHAKERS. 07:30 - 08:00 0.50 DRILL P INTI CLOSE EDC. RUN IN HOLE. Printed 10/29/2012 10:37:24AM IIINorth America-ALASKA- BP • Page 10 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:3710/22/1992 00:00©69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 09:30 1.50 DRILL P INTI DRILL AHEAD FROM 9317'. 3050 PSI FS AT 2.55 BPM IN/OUT. IA/OA/PVT: 110 PSI/267 PSI/342 BBLS BHP/ECD/TVD?4562 PSI/10.35 PPG/8610' LAND BUILD AT 9369'. 88 DEG INC. 09:30 - 12:30 3.00 DRILL P INTI WIPER TO WINDOW. FLOW CHECK. OPEN EDC. CIRCULATE OUT OF HOLE FOR BHA CHANGE 12:30 - 13:00 0.50 DRILL P INTI PJSM FOR CHANGING OUT BHA. 13:00 - 15:00 2.00 DRILL P INTI TAG STRIPPER AND FLOW CHECK WELL. LAY DOWN BHA,BIT S 1-2. CHANGE OUT ALL MWD TOOLS AND BIT. 15:00 - 15:15 0.25 DRILL P INTI M/U INJECTOR TO RISER AND PRESSURE TEST QTS SUB. 15:15 - 17:30 2.25 DRILL P _ INTI RIK WITH BHA#4,CIRCULATING THROUGH MUD GAS SEPARATOR. -HYCALOG 3-3/4"X 4-1/4"SRR3611 M-B4-Z BI-CENTER BIT ULTRA LOW SPEED MUD MOTOR,1.2°BEND -3"COILTRAK TOOLS WITH RES BHA OAL=82' 17:30 - 18:00 0.50 DRILL P INTI TIE IN DEPTH,CORRECT-10.5 FT. STOP AND CLOSE EDC. PASS THROUGH WINDOW AT 9R,RIH TO BOTTOM AND GET SLOW CIRCULATING PRESSURES. SLOW PUMP RATES,8.7 PPG,9369'MD: MP#1: 0.5 BPM=1575 PSI,1 BPM=1816 PSI MP#2: 0.5 BPM=1565 PSI,1 BPM=1805 PSI 18:00 - 18:30 0.50 DRILL P INTI SEE SLIGHT LOSS IN OUT MM DENSITY, GOES FROM 8.7 TO 8.5 PPG. NO PIT GAIN. NOTIFY CTD SUPT. CIRC BOTTOMS UP AT 2.5 BPM THROUGH GAS BUSTER. 18:30 - 19:00 0.50 DRILL P INTI DIRECTIONAL DRILL 4-1/4"FROM 9369'MD TO 9380'MD;2.5 BPM,3075 PSI,2925 PSI FREESPIN. MW IN/OUT=8.7 PPG. DECISION TO TRIP OUT OF HOLE TO TEST BOPE USED DURING WELL CONTROL OPERATIONS. NOTIFY JOHN CRISP OF INTENTION TO TEST BOPE UPON REACHING SURFACE. 19:00 - 22:00 3.00 DRILL N HMAN 9,380.00 INTI TRIP OUT OF HOLE FROM 9380'MD TO BHA AT 82'MD. WELL IS STATIC DURING FLOWCHECKS ON BOTTOM AND AT WINDOW- NO HOLE ISSUES ENCOUNTERED FLOWCHECK PRIOR TO BHA ENTERING STACK" WELL STATIC. ACTUAL HOLE FILL MATCHES CALCULATED FOR TRIP. 22:00 - 22:45 0.75 DRILL N HMAN 9,380.00 INTI UNSTAB INJECTOR AND SETBACK. RACK BACK BHA AND CLOSE SWAB VALVE. Printed 10/29/2012 10:37:24AM • North America-ALASKA- BP Page 11 of 36 Operation Summary Report . Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:45 - 23:15 0.50 BOPSUR N HMAN 9,380.00 INTI PRESSURE TEST CHOKELINE HCR AND INJECTOR PACKOFF TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH FOLLOWING USAGE IN WELL CONTROL SITUATION(PASSING TESTS.SEE ATTACHED CHART). WITNESS OF TEST WAIVED BY AOGCC REPRESENTATIVE JOHN CRISP. OPEN SWAB VALVE TO CLOSED CHOKE. NO PRESSURE ON WELL. 23:15 - 00:00 0.75 DRILL P INTI CHANGEOUT INJECTOR HIGH PRESSURE HYDRAULIC FILTERS. 8/15/2012 00:00 - 00:45 0.75 DRILL N HMAN 9,380.00 INTI MAKEUP AND RUN IN HOLE WITH WELL BHA #5. MAKEUP INJECTOR AND PRESSURE TEST QTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). -HYCALOG 3-3/4"X 4-1/4"SRR3611 M-B4-Z BI-CENTER BIT -ULTRA LOW SPEED MUD MOTOR,1.2°BEND -3"COILTRAK TOOLS WITH RES -BHA OAL=82' 00:45 - 03:00 2.25 DRILL N HMAN 9,380.00 INTI RUN IN HOLE WITH INTERMEDIATE LATERAL DRILLING ASSEMBLY FROM 82'MD TO PREVIOUSLY DRILLED MD OF 9380'MD. NO HOLE ISSUES DURING TRIP. LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY-10'CORRECTION COMPARED TO PREVIOUS CORRECTION OF -11'). 03:00 - 03:45 0.75 DRILL N HMAN 9,380.00 INTI CIRCULATE ONE BOTTOMS UP THROUGH MUD GAS SEPARATOR;2.5 BPM,2885 PSI, NO LOSSES WHILE CIRCULATING. NO SIGN OF GAS-CUT MUD UPON BOTTOMS UP. SLOW PUMP RATES,8.7 PPG,9380'MD: MP#1. 0.5 BPM= 1545 PSI,1 BPM= 1802 PSI MP#2: 0.5 BPM=1553 PSI,1 BPM= 1832 PSI 03:45 - 06:00 2.25 DRILL P INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 9380'MD TO 9414'MD AT 6 AM(45' IN 2.25 HRS=20 FPH); 2.7 BPM,213 BIT RPM,2985 PSI FREESPIN, 3175-3300 PSI PUMP PRESSURE,3-4.5 KLBS DHWOB. MW IN/OUT=8.8 PPG, ECD= 10.3 PPG. NO LOSSES TO FORMATION WHILE DRILLING AHEAD. 06:00 - 11:45 5.75 DRILL P INTI CONTINUE DRILLING FROM 9414 FT. SLOW ROP PASSING THROUGH APPARENT SHALE ZONE FROM 9380 FT ONWARDS. INCREASE PUMP RATE TO 2.9 BPM, ROP IMPROVES SLIGHTLY. 11:45 - 13:00 1.25 DRILL P INTI AFTER 9475 FT ROP IMPROVES TO 60 FT/HR. DRILL TO 9500 FT. 13:00 - 13:30 0.50 DRILL P INTI WIPER TRIP FROM 9500 FT TO WINDOW. CLEAN PASS UP AND DOWN. 13:30 - 14:00 0.50 DRILL P INTI DRILL FROM 9500 FT TO 9506 FT. ROP IS STAYING AROUND 10 FT/HR,AND EXCESSIVE DWOB IS REQUIRED TO KEEP DRILLING. Printed 10/29/2012 10.37.24AM North America -ALASKA- BP 110 Page 12 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:30 2.50 DRILL P INTI POOH FROM 9506'MD TO SURFACE FOR BIT/MOTOR CHANGE. FLOW CHECK AT WINDOW IS GOOD. TAG STRIPPER AND FLOW CHECK WELL AT SURFACE,GOOD. TRIP SHEET IS-3 BBS CUMULATIVE. 16:30 - 17:30 1.00 DRILL P INTI LAYDOWN DRILLING BHA. GRADE BIT: 17:30 - 18:00 0.50 BOPSUR P INTI FUNCTION TEST ALL BOPE EXCEPT BLINDS FROM OPS CAB CONTROL PANEL. 18:00 - 19:30 1.50 DRILL P INTI CUT 100'2-3/8"COILED TUBING FOR CHROME MANAGEMENT. NEW COIL LENGTH=14962' 19:30 - 21:30 2.00 DRILL P INTI INSTALL NEW SLB EXTERNAL DIMPLE COILED TUBING CONNECTOR AND PULL TEST TO 34 KLBS. LEAK TIGHT TEST TO 4000 PSI. MAKEUP AND TEST BHI E-LINE HEAD (PASSING TEST) 21:30 - 22:00 0.50 BOPSUR P INTI STAB ON WELL WITH INJECTOR AND PRESSURE TEST LUBRICATOR AND NEW DFCVS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH AGAINST CLOSED SWAB VALVE(PASSING TESTS,SEE ATTACHED CHART). UNSTAB INJECTOR AT QTS AND SET BACK ON RIG FLOOR. 22:00 - 22:30 0.50 DRILL P INTI HOLD RIG EVACUATION DRILL AND AAR. 22:30 - 23:45 1.25 DRILL P INTI MAKEUP BHA#6 FOR WELL,INTERMEDIATE LATERAL DRILLING ASSEMBLY,AND SCRIBE IN HOLE TO BHA OAL AT 82'MD. STAB ON WELL AND PRESSURE TEST QTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). -HYCALOG 3-3/4"X 4-1/4"SRRE3611 M-B3 BI-CENTER BIT,SER#128532 -2-7/8"HIGH SPEED X-TREME MUD MOTOR, 1.2°BEND -3"COILTRAK TOOLS WITH RESISTIVITY -BHAOAL=82' 23:45 - 00:00 0.25 DRILL P INTI RUN IN HOLE FROM BHA AT 82'MD TO 1000' MD AT MIDNIGHT. 8/16/2012 00:00 - 02:00 2.00 DRILL P INTI TRIP IN HOLE FROM 1000'MD AT MIDNIGHT TO PREVIOUSLY DRILLED DEPTH OF 9506' MD. CIRCULATE IN HOLE THROUGH MUD GAS SEPARATOR AS PRECAUTION,NO GAS CUT MUD OBSERVED. NO HOLE ISSUES DURING TIH. LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY-11'CORRECTION COMPARED TO PREVIOUS CORRECTION OF -10'). SLOW PUMP RATES,8.7 PPG,9380'MD: MP#1: 0.5 BPM=1545 PSI,1 BPM=1802 PSI MP#2: 0.5 BPM=1553 PSI,1 BPM=1832 PSI Printed 10/29/2012 10:37:24AM • 3 North America -ALASKA- BP � � -��� ��� ��� - Page 13 of6 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 I End Date: 9/7/2012 'X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.. NORDIC 2 Spud Date/Time. 11/6/1992 12:00:OOAM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 08:30 6.50 DRILL P INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 9506'MD TO 9610'MD(104'IN 6.5 HRS=16FPH);25BPM 428 BIT RPM,3100 PSI FREESPIN,3300-3600 PSI PUMP PRESSURE,2.5-4 KLBS DHWOB. MW IN/OUT=8.8 PPG,ECD=10.4 PPG. NO LOSSES TO FORMATION WHILE DRILLING --AHEAD. DISPLACE WELL TO NEW 8.6 PPG POWERVIS MUD SYSTEM WHILE DRILLING AHEAD IN EFFORT TO IMPROVE ROP. NEW MUD DECREASES ECD FROM 10.4 TO 9.8 PPG AND FREESPIN PRESSURE FROM 3100 PSI TO 2500 PSI. ' SLOW PUMP RATES,8.6 PPG,9555'MD: MP#1: 0.5 BPM,=1134 PSI,1 BPM=1344 PSI MP#2: 0.5 BPM=1160 PSI,1 BPM=1390 PSI 08:30 - 10:00 1.50 DRILL P INTI CONTINUE DRILLING PAST 9610 FT. HOLD 90R TF FOR NOW TO CONTINUE RH TURN AND HOLD ANGLE. DRILL TO 9650 FT. 10:00 - 11:00 1.00 DRILL P INTI WIPER TRIP FROM 9650 FT TO WINDOW. OVERPULLS THROUGH SHALE ZONE. SET DOWN WEIGHT AT 9375 FT ON THE WAY IN. REDUCE PUMP RATE AND POP THROUGH. LOST 2 BBLS ON TRIP. 11:00 - 16:15 5.25 DRILL P INTI DRILL FROM 9650 FT. ROP IS 10-30 FT/HR INITIALLY. DIFFICULT TO HOLD DESIRED INCLINATION. DROPPING ANGLE AT 30R TF GO TO OR TF AND TRY TO GET BACK TO 100 DEG DRILL TO 9738 FT. 16:15 - 18:45 2.50 DRILL P INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 9738'MD TO 9775'MD(37'IN 2.5 HRS= 15 FPH);2.5 BPM, 428 BIT RPM,2650 PSI FREESPIN,2950-3150 PSI PUMP PRESSURE,2.5-4 KLBS DHWOB. MW IN/OUT=8.6 PPG, ECD=9.5 PPG. NO LOSSES TO FORMATION WHILE DRILLING AHEAD. GR TRENDS NOT MATCHING EXPECTED SHUBLIK GR SIGNATURE. DECISION WITH GEOS TO MAD PASS LOG UP TO WINDOW TO • COMPARE PRESENT GR READINGS WITH EARLY DRILLNG LOGS. 18:45 - 22:00 3.25 DRILL P INTI MAD PASS LOG FROM 9775'MD TO 5-1/2" LINER WINDOW AT 9141'MD;250 FPH,1.7 BPM,2125 PSI. BEGIN LOSING FLUID TO WELLBORE AT 20 BPH DURING MAD PASS AND TRIP BACK IN HOLE. GR TOOL CONFIRMED TO BE WORKING. PULL UP HOLE TO 8970'MD AND LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY+4'CORRECTION). Printed 10/29/2012 10.37:24AM North America -ALASKA- BPPage 14 of 36 Operation Summary Report • Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:15 1.25 DRILL P INTI RUN IN HOLE FROM TIE IN POINT AT 8970'MD TO PREVIOUSLY DRILLED DEPTH OF 9775' MD. ENCOUNTER TWO TIGHT SPOTS AT 9330'MD AND 9374'MD. ABLE TO WORK THROUGH AT 1.7 BPM,5-10 FPM. NOTE: ZONE 4 CLAYS PRESENT 9370'MD TO 9490' MD. SLOW PUMP RATES,8.6 PPG,9775'MD: MP#1: 0.5 BPM=1170 PSI,1 BPM=1490 PSI MP#2: 0.5 BPM=1220 PSI,1 BPM=1640 PSI 23:15 - 00:00 0.75 DRILL P INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL`HOLE SECTION FROM 9775'MD TO 9789'MD AT MIDNIGHT(14'IN 0.75 HRS=19 FPH);2.5 BPM,428 BIT RPM,2800 PSI FREESPIN,2950-3200 PSI PUMP PRESSURE, 3-4 KLBS DHWOB..MW IIWOUT=8.6 PPG, ECD=9.6 PPG. • LOSSES TO WELLBORE AVERAGING 45-55 BPH(-35%OF DRILLING RATE). 8/17/2012 00:00 - 06:30 6.50 DRILL P INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 9789'MD TO 9900'MD(101' IN 6.5 HRS= 15.5 FPI-1);2.5 BPM,428 BIT RPM,2575 PSI FREESPIN(NEW MUD ADDED TO SYSTEM),2850-3000 PSI PUMP PRESSURE,3-5 KLBS DHWOB. MW IN/OUT=8.6 PPG, ECD=9.6 PPG. LOSSES TO WELLBORE IMPROVE AFTER 9815'TO 20-30 BPH(-20%OF DRILLING RATE). ROUGH COMPARISON BETWEEN SHUBLIK DRILLING ROP 9150'-9292'MD VS INVERTED SECTION 9490'-9880'MD: COMPARABLE 15-20 FPH AVERAGE ROPS IN EACH SECTION. SLOW PUMP RATES,8.6 PPG,9880'MD: MP#1: 0.5 BPM= 1060 PSI,1 BPM= 1351 PSI MP#2: 0.5 BPM=1020 PSI,1 BPM=1380 PSI 06:30 - 08:00 1.50 DRILL P INTI WIPER TRIP FROM 9900 FT TO TD. OVERPULLS TO 70K THROUGH FAULT ZONE FROM 9620-9680 FT. STUCK TWICE,CAN'T GO UP OR DOWN. ABLE TO WORK THROUGH AND CONTINUE WIPER TRIP. RETURNS FALL OFF TO 0.3 BPM WHILE IN FAULT ZONE. 08:00 - 08:50 0.83 DRILL P INTI PULL THROUGH WINDOW AND OPEN EDC. PUMP A HI-VIS SWEEP AROUND. Printed 10/29/2012 10:37:24AM North America-ALASKA- BP 111, Page 15 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) ' Start Date: 8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00©69.30ft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT l NPT Depth Phase Description of Operations (hr) (ft) 08:50 - 09:30 0.67 DRILL P INTI CLOSE EDC. RUN BACK IN THROUGH WINDOW. STILL LOSING 0.5-1 BPM. NEW MUD COMING OUT IS TREATED WITH 4%KCL AND 14 PPB KLAGARD FOR INHIBITION OF REACTIVE CLAYS FROM 9400-9500 FT. SOME ADDITIONAL CUTTINGS SEEN WHEN HI-VIS SWEEP COMES AROUND. STACK WEIGHT GOING THROUGH 9400-9500 FT,STOP CT AND POP THROUGH EACH TIME. REDUCE PUMP RATE TO 1 BPM GOING THROUGH FAULT ZONE. STACK OUT AT 9620 FT AT REDUCED RATE, AT AS DRILLED TF. PICK UP SEVERAL TIMES AND TRY WITH AS DRILLED TF, NO LUCK. TURN TO HS TOOLFACE,TRY ONCE,NO LUCK. GO BACK TO AS DRILLED TF,1.5 BPM,20 FT/MIN,ABLE TO GET THROUGH. 09:30 - 11:00 1.50 DRILL -P INTI WORK CT DOWN THROUGH FAULT ZONE, KEEP AS DRILLED TF,1.5 BPM. PUMP 20 BBLS HI-VIS SWEEP AROUND AFTER GETTING PAST FAULT ZONE. ABOUT 50 FT FROM TD, HOLE IS PACKING OFF BEHIND US. OVERPULL,ANNULAR PRESSURE INCREASES 500 PSI, LOSING RETURNS DOWN TO 0.3 BPM. PICK UP BACK THROUGH FAULT ZONE TO TRY AND CLEAR PACKED OFF HOLE. PUMP ANOTHER HI-VIS SWEEP AROUND WHEN PULLING THROUGH FAULT ZONE. PULL THROUGH WINDOW AND TIE-IN DEPTH, CORRECT+2 FT. 11:00 - 12:00 1.00 DRILL P INTI PASS THROUGH WINDOW. STACKING WEIGHT AROUND 9250 FT AT LOW PUMP RATE. INCREASE RATE AND POP THROUGH. CONTINUE RIH AT 1.1 BPM,CLEAN PASS TO 9750 FT THEN START STACKING WEIGHT. PICK UP AND WORK PAST. TAG BOTTOM AT 9899 FT. 12:00 - 12:30 0.50 DRILL P INTI PICK UP TO WINDOW. PUMP NEW MUD AROUND. OVERPULLS ON THE WAY UP,CAN'T GO DOWN. PULL 60K EACH TIME TO GET FREE. 12:30 - 13:30 1.00 DRILL N DPRB 9,900.00 INTI OVERPULL AT 9760 FT TO 70K. TRY TO GO BACK DOWN, CAN'T MOVE EITHER DIRECTION CAN'T TURN ORIENTER. STILL HAVE CIRCULATION,ANNULAR PRESSURE INDICATES WE AREN'T PACKED OFF. CYCLE PIPE 15 TIMES,-10K TO 85K. DWOB INDICATES ALL FORCE IS BEING SEEN AT THE BIT. PARK WITH 8K DWOB,RELAX TOOL. ORIENTER STARTS TURNING,LIKELY TURNING ENTIRE MOTOR HOUSING. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP • Page 16 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date: 9/7/2012 IX3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor NORDIC CALISTA UWI: Active Datum:63 : 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 15:10 1.67 DRILL N DPRB 9,900.00 INTI PARK IN MAX COMPRESSION(-14K),WAIT FOR MINERAL OIL. CONTINUE TURNING ORIENTOR 15:10 - 15:30 0.33 DRILL N DPRB 9,900.00 INTI WHILE WAITING,BHA MOVES DOWNWARD AND IS FREE. POOH. OVERPULLS AGAIN COMING THROUGH 'REACTIVE CLAYS FROM 9500-9400 FT. WORK BACK THROUGH. 15:30 - 16:20 0.83 DRILL N DPRB 9,900.00, INTI 1 PULL THROUGH WINDOW AND BACK TO TUBING TAIL. DISCUSS SIDETRACK OPTIONS WITH ODE. WILL LIKELY SET A BILLET AT 9280 FT. CLEANOUT DOWN TO 9300 FT. 16:20 - 18:00 1.67 DRILL N DPRB 9,900.00 INTI PULL BACK ABOVE WHIPSTOCK AND PERFORM 100 FT JOG. STOP AND FLOWCHECK WELL,OPEN EDC. CONTINUE TRIP OUT OF HOLE TO SURFACE. 18:00 - 19:00 1.00 DRILL N DPRB 9,900.00 INTI FLOW CHECK WELL AT BHA. WELL STATIC. UNSTAB INJECTOR FROM WELL. CHANGEOUT PACKOFFS. INSPECT COILED TUBING CONNECTOR AND INJECTOR CHAINS. 19:00 - 19:30 0.50 DRILL N DPRB 9,900.00 INTI LAYDOWN DRILLING ASSEMBLY. GRADE BIT 1-1-PN-N-X-I-NO-BHA. 19:30 - 20:00 0.50 BOPSUR N DPRB 9,900.00 INT1 STAB ON WELL WITH INJECTOR AND PRESSURE TEST INJECTOR PACKOFFS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH AGAINST CLOSED SWAB VALVE (PASSING TESTS,SEE ATTACHED CHART). UNSTAB FROM WELL WITH INJECTOR AND SET BACK. 20:00 - 21:30 1.50 STKOH N DPRB 9,900.00 INTI DISCUSS SIDETRACK DIRECTIONAL PLANS WITH ANCHORAGE TEAM. LOAD BAKER BILLET TOOLS INTO PIPE SHED AND SCRIBE HIGHSIDE ON TOOLS BETWEEN TWO SLIPS. 21:30 - 22:00 0.50 STKOH N DPRB 9,900.00 INTI MAKEUP AND SCRIBE IN HOLE WITH ALUMINUM BILLET ASSEMBLY. STAB ON WELL WITH INJECTOR AND PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). -3-5/8"9' LONG BAKER ALUMINUM BILLET ON (5)SLIP ANCHOR. 3"COILTRAK TOOLS WITH HOT -BHA OAL=75' 22:00 - 00:00 2.00 STKOH N DPRB 9,900.00 INTI RUN IN HOLE WITH ALUMINUM BILLEST ASSEMBLY FROM BHA AT 75'MD TO TIE-, IN POINT,8970'MD,AT MIDNIGHT. CIRCULATE AT 0.3 BPM THROUGH OPEN EDC. LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY-8'CORRECTION COMPARED TO PREVIOUS CORRECTION OF -11'). 8/18/2012 00:00 - 00:45 0.75 STKOH N DPRB 9,900.00 INT1 TRIP IN HOLE WITH BILLET ASSEMBLY FROM TIE-IN POINT AT 8970'MD AT MIDNIGHT TO SETTING DEPTH AT 8266'MD. PICKUP WEIGHT=38 KLBS,SLACKOFF=20 KLBS. Printed 10/29/2012 10:37:24AM North America-ALASKA- BP Page 17 of 36 Operation Summary Report rnE , • g Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date. 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 11/6/1992 12.00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:45 - 01:00 0.25 STKOH N DPRB 9,900.00 INTI PRESSURE UP TO 4000 PSI TO SET 3-5/8"9' LONG BAKER ALUMINUM SIDETRACK BILLET WITH(5j SLIP ANCHOR WITH TOP AT 9255' MD AND 30°ROHS. ESTABLSIH CIRCULATIONG THROUGH CLOSED EDC TO CONFIRM RELEASE FROM BILLET. SHUT DOWN PUMPS AND FLOWCHECK WELL. -WELL STATIC. 01.00 - 03:00 2.00 STKOH N DPRB 9,900.00 INTI PULL OUT OF HOLE FORM BILLET DEPTH AT 9255'MD TO BHA AT 75'MD. FLOWCHECK WELL AT CHA. WELL STATIC. UNSTAB INJECTOR AND SETBACK. 03:00 - 03:30 0.50 STKOH N DPRB 9,900.00 INTI LAYDOWN BAKER SETTING TOOLS AND COILTRAK SETTING BHA. 03:30 - 04:30 1.00 STKOH N DPRB 9,900.00 INTI MAKEUP SIDETRACK/BUILD BHA(BHA#8 FOR WELL). STAB INJECTOR ON WELL AND RPESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). -HYCALOG-3-3/4"X 4-1/4"SRRE3611 M-B3 BI-CENTER BIT(RAZOR EDGE CUTTERS), SER#128532(RE-RUN FROM BHA#6) -HIGH SPEED MUD MOTOR,2.9°BEND -3"COILTRAK TOOLS WITH RES BHA OAL=79' 04:30 - 07:00 2.50 STKOH N DPRB 9,900.00 INT1 LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY-11'CORRECTION COMPARED TO PREVIOUS CORRECTION OF 07:00 - 07:30 0.50 STKOH N DPRB 9,900.00 INTI PASS THROUGH WINDOW AND GET SLOW PUMP PRESSURES AT 9220 FT. PUMP 1: 0.5 BPM= 1000 PSI,1 0 BPM= 1300 PSI PUMP 2: 0.5 BPM= 1018 PSI,1.0 BPM= 1289 PSI END S-37APB1 RON EVENT AND SWITCH OVER TO WELLBORE S-37A WELLBORE RO EVENT(DAILY REPORT#11 B) 07:30 - 09:10 1.67 STKOH N DPRB 9,900.00 INTI BEGIN RON EVENT FOR WELLBORE S-37A AT 07:30 AM ON 8/18/2012. START TIME MILLING 1 FT ABOVE BILLET AT 1 FT/HR AT 90R TF AS PER BHI SIDETRACK PROCEDURE. START TO SEE A BIT OF MOTOR WORK AT 9255.6 FT. 09:10 - 10:00 0.83 STKOH N DPRB 9,900.00 INTI AT 9256.1 FT,SEE PARTIAL LOSS OF RETURNS DOWN TO 2 BPM. 10:00 - 10:25 0.42 STKOH N DPRB 9,900.00 INTI CONTINUE DRILLING 1 FT/HR AT 9256.70 FT. 2.57/2.05 BPM @ 2310 PSI,DWOB=-0.4 KLBS. 10:25 - 11:15 0.83 STKOH N DPRB 9,900.00 INTI START TO DRILL AT 2 FT/HR FROM 9257.1 FT. ALUMINUM SEEN AT SHAKERS. 11:15 - 11:30 0.25 STKOH N DPRB 9,900.00 INTI GO TO 3 FT/HR AT 9258.0 FT. 11:30 - 12:30 1.00 STKOH N DPRB 9,900.00 INTI AT 9259 START DRILLING AT 7 FT/HR,TRY TO MAINTAIN 100 PSI MOTOR WORK. AT 9261 START DRILLING AT 10 FT/HR,1.4K DWOB. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP Page 18 of 36 Operation Summary Report , Common Well Name:S-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date:9/7/2012 'X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.. NORDIC 2 Spud Date/Time. 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 14:00 1.50 STKOH N DPRB 9,900.00 INTI AT 9267 FT DRILL NORMALLY. 15-20 FT/HR, 2-3K DWOB. DRILL TO 9302 FT. 14:00 - 15:30 1.50 STKOH N DPRB 9,900.00 INTI PICK UP AT 9302 FT TO GET A NEW FREE SPIN PRESSURE. CONTINUE DRILLING FROM 9302 FT. GOOD ROP AFTER 9310 FT,LIKELY PENETRATION -INTO IVISHAK. AT 9370 FT PUMP 20 BBLS HI-VIS SWEEP AROUND. DRILL TO END OF BUILD AT 9380 FT. WELL IS TAKING ABOUT 30 BBUHR AT 2.55 BPM. 15:30 - 16:20 0.83 STKOH N DPRB 9,900.00 INTI POOH. REDUCE PUMP TO 0.5 BPM PULLING PAST BILLET AND WINDOW. PULL THROUGH WINDOW AND PERFORM 100 FT JOG. STOP AND OPEN EDC,FLOW CHECK WELL. FLOW CHECK IS GOOD,POOH. 16:20 - 18:30 2.17 STKOH N DPRB 9,900.00 INTI POOH TO SURFACE, PUMPING THROUGH OPEN EDC;3.5 BPM WELL STILL ON 30-50 BBUHR LOSSES. FLOW CHECK WELL AT BHA. WELL IS STATIC. UNSTAB INJECTOR AND SETBACK. 18:30 - 19:00 0.50 STKOH N DPRB 9,900.00 INTI LAYDOWN SIDETRACK/BUILD DRILLING ASSEMBLY. GRADE BIT 1-1-WT-A-X-I-NO-TD. CHANGEOUT HOT/DGS/RES TOOLS. 19:00 - 20:00 1.00 STKOH N DPRB 9,900.00 INTI MAKEUP DRILLING ASSEMBLY(BHA#9 FOR WELL). STAB INJECTOR ON WELL AND RPESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). -HYCALOG 3-3/4"X 4-1/4"SRRE3611 M-B3 BI-CENTER BIT(RAZOR EDGE CUTTERS), SER#128532(RE-RUN FROM BHA#6&8) -HIGH SPEED MUD MOTOR,1.1°BEND -3"COILTRAK TOOLS WITH RES -BHA OAL=79' 20:00 - 23:30 3.50 STKOH N DPRB 9,900.00 INTI TRIP IN HOLE FROM BHA AT 79'MD TO PREVIOUSLY DRILLED DEPTH OF 9380'MD LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY-12'CORRECTION COMPARED TO PREVIOUS CORRECTION OF -11'). SLOW PUMP RATES: 8.6 PPG,9380'MD PUMP 1 0.5 BPM=1250 PSI,1.0 BPM= 1472 PSI PUMP 2: 0.5 BPM= 1227 PSI,1.0 BPM= 1454 PSI 23:30 - 00:00 0.50 STKOH N DPRB 9,900.00 INTI DIRECTIONAL DRILL4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 9380'MD TO 9395'MD AT(15' IN 0.5 HRS=30 FPH),2.5 BPM IN&1.3 BPM OUT,428 BIT RPM,2500 PSI FREESPIN,2750-3000 PSI PUMP PRESSURE, 2-5 KLBS DHWOB. MW IN/OUT=8.6 PPG, ECD=9.7 PPG. IA/OA=0/0 PSI. LOSSES TO WELLBORE AVERAGING 65-70 BPH(-45%OF DRILLING RATE). Printed 10/29/2012 10:37:24AM -- 0 North America-ALASKA- BPPage 19 of 36 r Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ' (ft) 8/19/2012 00:00 - 03:45 3.75 STKOH N DPRB 9,900.00 INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 9395'MD AT MIDNIGHT TO 9550'MD(155' IN 3.75 HRS=41 FPH); 2-5 BPM IN,1.3 BPM OUT,428 BIT RPM, 2500 PSI FREESPIN,2800-3300 PSI PUMP PRESSURE,2-5 KLBS DHWOB. MW IN/OUT= 8.6 PPG, ECD=9.6 PPG. IA/OA=0/0 PSI. LOSSES TO WELLBORE AVERAGING 70 BPH (-45%OF DRILLING RATE). 03:45 - 04:15 0.50 STKOH N DPRB 9,900.00 INTI COMPLETE WIPER TRIP FROM 9550'MD TO 5-1/2"LINER WINDOW AT 9141'MD;2.5 BPM PULLING OUT,1.5 BPM RUNNING IN. PICKUP WEIGHT OFF BOTTOM=32 KLBS,SLACKOFF RUNNING IN HOLE=20 KLBS. NO HOLE ISSUES DURING WIPER. 04:15 - 05:30 1.25 STKOH N DPRB 9,900.00 INTI DIRECTIONAL DRILL4-1/4"INTERMEDIATE HOLE SECTION FROM 9550'MD TO 9604'MD AT 6 AM(54'IN 1.25 HRS=43 FPH);2.5 BPM IN,1.5 BPM OUT,428 BIT RPM,2500 PSI FREESPIN,2800-3100 PSI PUMP PRESSURE, 2-5 KLBS DHWOB. MW IN/OUT=8.6 PPG, ECD=9.6 PPG. LOSSES TO WELLBORE AVERAGING 60 BPH ' 5-45%OF DRILLING RATE). 05:30 - 06:15 0.75 STKOH N DPRB 9,900.00 INTI DRILL AHEAD IN 4-1/4"INTERMEDIATE HOLE FROM 9604'MD WELL BEGIN LOSING 95-120 BPH AT 9604' MD. AT 9630'MD, RETURNS DROP TO MINIMAL LEVEL AT 0.1 BPM. LINEUP AND BEGIN MAINTAINING HOLE FILL ON BACKSIDE WITH SECOND MUD PUMP DOWN KILL LINE. MONITOR ANNULAR PRESSURE ON DH PRESSURE SENSOR. 06:15 - 07:30 1.25 STKOH N DPRB 9,900.00 INTI CONTINUE DRILLING FROM 9624 FT. ONE PUMP GOING ACROSS KILL LINE, ONE PUMP DOWN THE CT. LOSSES ABOUT 150 BBUHR AT THIS POINT 07:30 - 08:30 1.00 STKOH N DPRB 9,900.00 INTI MUD PLANT CAN'T KEEP UP WITH LOSSES, SWITCH TO A KCL WATER FLUID SYSTEM. ECD FALLS TO ABOUT 8.0 PPG, LINE UP THROUGH HAND CHOKE AND PINCH IT IN TO GET MORE KILL LINE FLUID DOWNHOLE. DRILL TO 9690 FT. PICK UP ABOVE LOSS ZONE TO CHECK HOLE CONDITION,CLEAN PICKUP. SLIGHT WEIGHT STACKING AT A COUPLE POINTS GOING BACK DOWN. CONTINUE DRILLING FROM 9690 FT. DRILL TO 9700 FT. 08:30 - 09:00 0.50 STKOH N DPRB 9,900.00 INTI WIPER TRIP FROM 9700 FT TO WINDOW. CLEAN PASS UP THROUGH FAULT ZONE. GO TO 90R AND REDUCE PUMP RATE GOING PAST BILLET. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP "` Page 20 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12.00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00.00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09.00 - 10:30 1.50 STKOH N DPRB 9,900.00 INTI PULL THROUGH WINDOW AND PERFORM JOG UP TO TUBING TAIL,THEN REDUCE RATE AND WAIT FOR TRUCKS TO CATCH UP. PULLING ABOUT 4K OVER GOING THROUGH WINDOW. GO TO 9100 FT AND PUMP 0.8 BPM NET DOWN THE KILL LINE,1.5 BPM DOWN THE -CT. ECD IS ABOUT 8.1 PPG,ANNULAR PRESSURE 3590 PSI. 10:30 - 11:15 0.75 STKOH N DPRB 9,900.00 INTI FLUID VOLUME ON LOCATION IS SUFFICIENT. RUN BACK DOWN TO CONTINUE DRILLING. TAG BOTTOM OF WINDOW TWICE AT 9R,15 FT/MIN,0 PUMP. PICK UP AND GO TO OR,20 FT/MIN,POP THROUGH. ONE SETDOWN IN 9460-9500 FT SHALE ZONE. SETDOWN AT 9640 FT IN FAULT ZONE. 11:15 - 14:15 3.00 STKOH N DPRB 9,900.00 INTI DRILL FROM 9700 FT. CONTINUE 2.5 BPM DOWN THE CT,1.15 BPM 'DOWN KILL LINE,0.4 BPM RETURNS. CHOKE PINCHED BACK,ECD=8.35 PPG. DRILL TO 9760,PICK UP TO CHECK HOLE CONDITION. PICK UP 50 FT,HOLE IS IN GOOD SHAPE. PICK UP AGAIN AT 9820 FT,HOLE IS IN GOOD CONDITION. PUMP 20 BBLS HI-VIS SWEEP AROUND. DRILL TO 9850 FT. 14:15 - 14:50 0.58 STKOH N DPRB 9,900.00 INTI WIPER TRIP FROM 9850 FT TO 9500 FT,JUST ABOVE LOSS ZONE. CLEAN PASS UP AND DOWN. 14:50 - 15:50 1.00 STKOH N DPRB 9,900.00 INTI DRILL FROM 9850 FT. START BUILDING ANGLE FROM HERE TO PUSH UP THROUGH THE SHUBLIK. NOW DRILLING WITH 4%KCL WATER WITH LUBES,AND 14 PPB KLAGARD. DRILL TO 9920 FT. NOTE: END OF CHANGE OF SCOPE CODING BECAUSE NEW SIDETRACK IS PAST PLUGBACK DEPTH OF S-37APB1 OF 9900'MD. 15:50 - 16:30 0.67 DRILL P INTI PICK UP FROM 9920 FT TO CHECK HOLE CONDITIONS. CLEAN PICKUP. DRILL FROM 9920 FT TO 9950 FT. RE-ENTER SHUBLIK AT 9934 FT. 16:30 - 17:00 0.50 DRILL P INTI PICK UP ABOVE WINDOW AGAIN TO WAIT ON TRUCKS TO BUILD FLUID VOLUME ON LOCATION. CLEAN WIPER TRIP THROUGH OPENHOLE. Printed 10/29/2012 10:37:24AM • North America -ALASKA- BP • Page 21 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 00:00 7.00 STKOH N DPRB 9,949.00 INTI RECIPROCATE PIPE INSIDE 5-1/2"LINER WINDOW WHILE BUILDING SURFACE VOLUME AND ORGANIZING VAC TRUCKS. ANNULUS BOTTOMHOLE PRESSURE STABILIZED AT—3400 PSI,7.7 PPG ECD(150 PSI OVERBALANCE)BY PUMPING 3 BPM DOWN BACKSIDE THROUGH KILL LINE AND 1 BPM DOWN COIL. LOSING 240 BBLS/HR OF '8.5 PPG FLUID. APPROXIMATELY 630 BBLS KCL AND 420 BBLS MUD(1050 BBLS TOTAL)ON LOCATION AS OF MIDNIGHT. WORKING TOWARDS -1600 BBLS PRIOR TO DRILLING AHEAD. LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY+2'CORRECTION). 8/20/2012 00:00 - 01:30 1.50 DRILL N DPRB 9,950.00 INTI RECIPROCATE PIPE INSIDE 5-1/2"LINER WINDOW WHILE BUILDING SURFACE VOLUME AND ORGANIZING VAC TRUCKS. ANNULUS BOTTOMHOLE PRESSURE STABILIZED AT—3400 PSI,7.7 PPG ECD(150 PSI OVERBALANCE)BY PUMPING 3 BPM DOWN BACKSIDE THROUGH KILL LINE AND 1 BPM DOWN COIL. 01:30 - 02:30 1.00 DRILL P INTI RUN IN HOLE FROM 5-1/2"WINDOWAT9141' MD TO PREVIOUSLY DRILLED MD OR 9950' MD;25 FPM,1.5 BPM DOWN COIL,1.75 BPM DOWN BACKSIDE AGAINST CLOSED CHOKE. SLACKOFF WEIGHT=24 KLBS. ✓ 02:30 - 09:00 6.50 DRILL P INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 9950'MD TO 10085'MD AT 6 AM(135'IN 3.5 HRS=39 FPH); 2.5 BPM IN DOWN COIL,0.7 BPM PUMPED DOWN BACKSIDE AGAINST CLOSED CHOKE, NO RETURNS,428 BIT RPM,1550 PSI FREESPIN,2000-2400 PSI PUMP PRESSURE, 2-5 KLBS DHWOB. MW IN=8.5 PPG, ECD= 8.0 PPG. IA/OA=0/0 PSI. LOSSES TO WELLBORE AVERAGING 190 BPH (100%OF DRILLING RATE). BOTTOMHOLE ANNULAR PRESSURE=3625 PSI(360 PSI OVERBALANCE). 09:00 - 09:30 0.50 DRILL P INTI LOAD PITS WITH KCL. 09:30 - 10:00 0.50 DRILL P INTI CONTINUE DRILLING. OPEN CHOKE TO ALLOW SOME RETURNS, GET RETURNS RIGHT AWAY. INCREASE RATE DOWN KILL LINE,TRY TO INCREASE ECD AT TOOL Printed 10/29/2012 10:37:24AM • • "'" North America -ALASKA- BP • Page 22 of 36 0•eratlon S mmary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12.00:OOAM Rig Release: 9/2/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00 00 @69 30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12:00 2.00 DRILL P INTI PUMP 3.7 BPM INTO KILL LINE,2.5 BPM DOWN CT,0.5 BPM RETURNS. ECD=8.25 PPG,ANNULAR PRESSURE=3720 PSI. CONTINUE DRILLING. PICK UP PERIODICALLY TO CHECK HOLE CONDITION. AT 10196 FT PUMP 20 BBLS HI-VIS SWEEP. DRILL TO 10196, PICK UP FOR DIRECTIONAL UNEASE. TOOL ISN'T RESPONDING TO LOWSIDE TF, NEED TO START DROPPING ANGLE. 12:00 - 13:10 1.17 DRILL P INTI AGREE TO TRY 10 MORE FEET DRILLING 180L WITH HIGH DWOB TO TRY AND START DROPPING ANGLE. DIRECTIONAL CONTROL IS BETTER AFTER 10205 FT, STARTING TO DROP ANGLE. DRILL TO 10230 FT. RE-ENTER SAG RIVER AT 10218'MD 13:10 - 17:30 4.33 DRILL P INTI WIPER TRIP FROM 10230 FT TO ABOVE LOSS ZONE. SLOW DOWN WIPER TRIP SPEED AND REDUCE PUMP RATES TO GET AHEAD ON FLUID AGAIN. KILL LINE RATE=1.37 BPM,1.15 BPM DOWN CT,OUT RATE IS 0.21 BPM, ECD=8.21 PPG, ANNULAR PRESSURE=3715 PSI. 17:30 - 19:00 1.50 DRILL P INTI DIRECTIONAL DRILL 4-1/4"INTERMEDIATE LATERAL HOLE SECTION FROM 10230'MD TO 10355'MD(125' IN 1.5 HRS=83 FPH);2.5 BPM IN DOWN COIL,1 BPM PUMPED DOWN BACKSIDE,MAINTAINING 0.2 BPM RETURNS, 428 BIT RPM,1585 PSI FREESPIN,1750-1900 PSI PUMP PRESSURE,2-5 KLBS DHWOB. MW IN=8.5 PPG, IA/OA=0/320 PSI. HELD KICK WHILE DRILLING DRILL AND AAR. 19:00 - 20:00 1.00 DRILL P INTI COMPLETE WIPER TRIP FROM 10360'MD TO TIE-IN POINT INSIDE WINDOW;25 FPM. PICKUP WEIGHT OFF BOTTOM=35 KLBS. AT 9400'MD, PICKUP WEIGHT INCREASED TO 44 KLBS AND REMAINED AT LEVEL UNTIL WINDOW. ATTEMPT TO RUN IN HOLE AND SET DOWN HARD IN WINDOW SEVERAL TIMES. LOG JB MARKER GR SIGNATURE IN KINGAK FOR TIE-IN(APPLY+7'CORRECTION). 20:00 - 22:15 2.25 DRILL N DPRB 10,355.00 INTI RECIPROCATE PIPE INSIDE 5-1/2"LINER WINDOW WHILE BUILDING SURFACE VOLUME AND ORGANIZING VAC TRUCKS. MAINTAIN FULL WELLBORE WITH 3.5 BPM DOWN ANNULUS AND 2.5 BPM DOWN COIL. 22:15 - 23:00 0.75 DRILL P INTI RUN IN HOLE FROM WINDOW AT 9141'MD TO RE-TAG BOTTOM AND CONFIRM SECTION TOTAL DEPTH AT 10354'MD;30 FPM,8.4 PPG ECD, MAINTAINING 0.2 BPM RETURNS. SUCCESSFUL WORKING THROUGH WINDOW AT 20°ROHS AND 20 FPM. Printed 10/29/2012 10:37:24AM 411 North America -ALASKA- BPs Page 23 of 36 O•eration Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date. 8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 11/6/1992 12.00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 DRILL P INTI PULL OUT OF HOLE FROM SECTION TOTAL DEPTH AT 10254'MD TO WINDOW AT 9141' MD. PAINT FLAGS AT 8630'EOP(ORANGE)FOR LINER 100'OFF BOTTOM AND 7516'EOP (WHITE)FOR LINER AT WINDOW. 8/21/2012 00:00 - 02:00 2.00 DRILL P INTI PULL OUT OF HOLE FROM WINDOW AT 9141' MD TO 5300'MD, MAINTAINING 8.5 PPG ECD WITH 7.0-7.4 BPM DOWN BACKSIDE WITH BOTH PUMPS;35 FPM. 02:00 - 03:00 1.00 DRILL N DPRB 10,354.00 INTI STOP PULLING OUT OF HOLE AT 5300'MD TO CATCH UP AND ESTIMATE RATE REQUIRED TO FILL WELL. SWITCH OVER ONE MUD PUMP TO COIL AND ATTEMPT TO ESTIMATE RATE IN VERSUS RATE OUT. UNABLE TO ESTABLISH SOLID TREND. FLOW CHECK WELL TO ENSURE FORMATION IS NOT BEING CHARGED. WELL IS ON VAC. FLUID LEVEL APPEARS TO DROP TO-500' BASED ON BOTTOMHOLE PRESSURE CALCULATIONS. RESTABLISH CIRCULATION DOWN ANNULUS WITH 2 MUD PUMPS AT TOTAL RATE OF 6.8 BPM TO BUILD AND MAITAIN ECD AT 8.5 PPG. 03:00 - 05:30 2.50 DRILL P INTI PULL OUT OF HOLE FROM 5000'MD TO BHA AT 79'MD;50 FPM,8.5-8.6 PPG ECD, MAINTAINING FULL BACKSIDE BY PUMPING 6.8-7.1 BPM DOWN ANNULUS WITH BOTH PUMPS TOGETHER. 05:30 - 08:30 3.00 DRILL N DPRB` 10,354.00 INTI CIRCULATE 100 BBL HI-VIS(100+LSRV)PILL DOWN TO WINDOW. CHASE WITH 8.5 PPG 4%KCL AT 6 BPM. POOH. 08:30 - 10:15 1.75 DRILL N DPRB 10,354.00 INTI STOP 100 FT FROM SURFACE. DETERMINE LOSS RATE THROUGH KILL LINE, WELL TAKES 65 BBLS IN 10 MIN TO STAY FULL. CONTINUE KEEPING HOLE FULL WITH KCL UNTIL THICK MUD(150K+LSRV)ARRIVES. 10:15 - 11:40 1.42 DRILL N DPRB 10,354.00 INTI PUMP 80 BBLS OF HI-VIS MUD DOWNHOLE, THIS MUD IS AROUND 120K LSRV. A PARTIAL LOAD FROM LAST NIGHT. RETURNS INCREASE FROM 0.2 BPM TO 1.1 BPM. START LOADING PITS 1,2 WITH 150K+LSRV MUD. MEANWHILE SWITCH BACK TO PUMPING KCL OFF 2 TRUCKS AT ONCE,TO ALLOW TIME TO LOAD THICK MUD. 11:40 - 13:30 1.83 DRILL N DPRB 10,354.00 INTI START THICK MUD DOWN THE KILL LINE. PJSM FOR LID BHA. AFTER THICK MUD REACHES THE OPEN HOLE, LOSSES GO TO AROUND 2.6 BPM. OPEN RISER AND LID BHA. MAINTAIN HOLE FILL WHILE LID BHA. BIT IS 2-1. Printed 10/29/2012 10'37:24AM • North America-ALASKA- BP � �: � � � s•.0 m,_< f 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63. 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 14:40 1.17 DRILL N DPRB 10,354.00 INTI LIFT UP INJECTOR AND CUT OFF CT CONNECTOR. INSTALL BOOT ON END OF CABLE. PUMP 177 FT OF CABLE SLACK OUT AND CUT IT OFF. 14:40 - 16:30 1.83 DRILL N DPRB 10,354.00 INTI INSTALL BOOT ON END OF CABLE. PREP THE END OF THE CT FOR INSTALLING —CT CONNECTOR. CONTINUE SWAPPING PITS TO THICK MUD. 16:30 - 19:30 3.00 DRILL N DPRB 10,354.00 INTI GET DIRECTION FROM ODE TO STAND BY FOR DIFFERENT CEMENTING PLAN FORWARD. WITH CHARGE PUMP OFF,0 RETURNS PUMPING 2 BPM POWER-VIS. 19:30 - 21:30 2.00 DRILL N DPRB 10,354.00 INTI CONTINUE PUMPING 2 BPM IN OF FLO-PRO. RETURNS INCREASING WITH OUT RATE OF 0.25 BPM,0 PSI WHP. 21:30 - 00:00 2.50 DRILL N DPRB 10,354.00 INTI CIRCULATING AT 2BPM IN FLO-PRO,OUT RATE FLUCTUATING BETWEEN 0.05 AND 0.35 BPM. WAIT ON KCL TO PUMP 3/4"BALL. 8/22/2012 00:00 - 01:00 1.00 DRILL P INTI PJSM WITH NORDIC AND SLB TO PUMP 3/4" .BALL THROUGH COIL.LINE UP WITH PUMP#2 TO CIRCULATE KCL TO DRIFT COIL WITH 3/4" BALL.CONTINUE TO PUMP MUD DOWNHOLE WITH PUMP#1 AT 2 BPM IN/0.1 BPM OUT. 01:00 - 02:00 1.00 DRILL P INTI LAUNCH 3/4"BALL IN KCL AND PUMP THROUGH COIL AT 2.25 BPM, RECOVER BALL. 02:00 - 02:35 0.58 DRILL P INTI PUMP 50 BBL HI-VIS PILL DOWN HOLE AT 2.05 BPM.DOWN ON PUMP. 02:35 - 03:00 0.42 DRILL P INTI CLOSE SWAB. FUNCTION TEST BOPE FROM DRILLER'S CONSOLE. r (, ALL RAMS,ANNULAR AND HCRS FUNCTIONED. 03:00 - 04:00 1.00 DRILL P INTI OPEN SWAB AND FILL HOLE DOWN THE KILL LINE WITH 8.54 POWER-VIS AT 2 BPM IN/0.27 BPM OUT. RIG UP FLOOR TO RUN LINER. 04:00 - 06:00 2.00 DRILL P INTI CONTINUE TO CIRCULATE PUMPING 2 BPM WITH 0.4 BPM RETURNS. PROCEED WITH RUNNING LINER PER BOT. 06:00 - 06:30 0.50 CASING P INTI PJSM FOR PICKING UP LINER. WELL CONTROL AND CREW RESPONSIBILITES WERE DISCUSSED. 06:30 - 09:40 3.17 CASING P INTI START M/U LINER AS PER LINER SUMMARY. BAKER LOCK ALL LOWER PUP JOINTS AND JEWELRY,ALONG WITH FIRST 5 JTS OF 3.25" ,,h LINER. �T,✓� MAINTIAN HOLE FILL WHILE RUNNING LINER, ` � PUMP 1.2-1.5 BPM DOWN KILL LINE 1fr" CONTINUOUSLY. VISUALLY CHECK FLUID LEVEL IN STACK PERIODICALLY, STAYING AT THE BOP LEVEL. SEPARATE TRIP SHEETS BEING MAINTAINED BY NORDIC DRILLER AND SLB SUPERVISOR. UPDATE AOGCC WITH BOPE TEST TIMING FOR 9 AM TOMORROW. Printed 10/29/2012 10:37:24AM • North America-ALASKA- BP Page 25 of 36 O•eration Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 )(3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:40 - 12:00 2.33 CASING P INTI AFTER 10 JTS,STOP AND FILL LINER. LINER DOESN'T FILL WITH WATER HOSE,AFTER 20 MIN. BRING MORE MUD INTO PITS. CONDUCT KICK WHILE TRIPPING PIPE DRILL. 12:00 - 16:00 4.00 CASING P INTI CONTINUE M/U LINER AS PER LINER SUMMARY. STOP AT 30 JTS AND FILL LINER,DOESN'T FILL. LOSSES NOW DOWN TO 0.2 BPM. 16:00 - 17:00 1.00 CASING P INTI M/U SWIVEL AND CT RISER. PRESSURE TEST QTS SUB. 17:00 - 19:30 2.50 CASING P INTI START RUNNING LINER IN HOLE COIL CONVEYED. PUMP AT MINIMUM RATE DOWN THE COIL OF 0.3 BPM,CIRC PRESSURE OF 950 PSI. PUMP DOWN THE KILL LINE TO FILL THE HOLE AT 1.0 BPM WITH 0.4 BPM RETURNS. 19:30 - 19:45 0.25 CASING P INT1 FIRST FLAG AT EOP OF 7506'(-10'FROM PAINTED EOP, BUT WE CUT 14'OFF WHEN REHEADING). 19:45 - 19:50 0.08 CASING P INTI POW 44K,SOW 10KAT WINDOW. .9642'SAW SHALE WITH WEIGHT,BUT -CONTINUED IN HOLE 19:50 - 20:15 0.42 CASING P INTI RIH AT 30 FPM PUMPING 0.3 BPM DOWN COIL TAG BOTTOM AT 10354.7'WITH LINER, CONFIRM DEPTH WITH 10K WEIGHT STACKED. PAINT FLAG AT 10355(EOP 8746')WITH WEIGHT STACKED. 20:15 - 20:20 0.08 CASING P INTI BRING PUMP DOWN THE COIL UP TO 1.25 BPM TO RELEASE GS RUNNING TOOL PULL UP WITH WEIGHT OF 35K,POH LEAVING LINER ON BOTTOM 20:20 - 22:50 2.50 CASING N DPRB 10,354.00 INTI START TRIP SHEET AND POH AT 65 FPM FROM 10,355'. PUMP 1 BPM DOWN THE KILL,0.8 BPM DOWN COIL WITH 1730 CIRC PRESSURE,1.1 BPM RETURNS. 22:50 - 23:15 0.42 CASING N DPRB 10,354.00 INTI TAG AT SURFACE,SHUT DOWN PUMPS LAY DOWN BHA. 23:15 - 00:00 0.75 CEMT N DPRB 10,354.00 INTI UNSTAB INJECTOR BTT MAKE UP SLIM KENLEY CONNECTOR PULL TEST SAME TO 33K PRESSURE TEST TO 250 PSI LOW/3500 HIGH FOR 5 MIN.GOOD TEST. 8/23/2012 00:00 - 01:20 1.33 CEMT P INTI CONFIRM CEMENTING BHA EQUIPMENT. MAKE-UP BHA#11 TO CEMENT LINER. 01:20 - 01:35 0.25 CEMT P INTI STAB ON INJECTOR. PRESSURE TEST QTS. 01:35 - 04:00 2.42 CEMT N DPRB 10,354.00 INTI RIH AT 70 FPM PUMPING 0.6 BPM DOWN THE KILL LINE AND 0.3 BPM DOWN THE COIL AT 1245 PSI CIRC PRESSURE. 04:00 - 04:30 0.50 CEMT N DPRB 10,354.00 INTI SLOW RIH SPEED TO 30 FPM. AT 10,000'GET PUMP RATES AND PRESSURES: 1 BPM @ 2190 PSI,0.5 BPM @ 1600 PSI. Printed 10/29/2012 10:37:24AM North America-ALASKA- BP • Page 26 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM Rig Release: 9/2/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 05:00 0.50 CEMT N DPRB 10,354.00 INTI TAG WITH STINGER IN DUAL FLAPPER AT 10341',SET 9K DOWN. PUMP 1 BPM @ 2500 PSI,0.5 BPM @ 1700 PSI TO VERIFY STINGER IS ENGAGED. 05:00 - 05:30 0.50 CEMT P INTI RIG UP CEMENTERS, PREP BIOZAN FOR CONTAMINATING. TAKE ON 20 BBLS KCL PRE-FLUSH ON TO CEMENT TRUCK. 05:30 - 09:40 4.17 CEMT P INTI PRESSURE TEST CEMENT LINE WITH KCL. SLB AND NORDIC CREW CHANGE. PREP FOR CEMENT JOB,MIX 120 BBL BIOZAN. 09:40 - 10:10 0.50 CEMT P INTI PJSM FOR BATCHING AND PUMPING LINER CEMENT JOB. 10:10 - 10:30 0.33 CEMT P INTI START BATCHING UP CEMENT. 10:30 - 11:00 0.50 CEMT P INTI CEMENT IS UP TO WEIGHT. SHUT DOWN KILL LINE PUMP AND LINE UP SLB TO PUMP 20 BBL KCL SPACER. 11:00 - 11:50 0.83 CEMT P INTI PUMP 20 BBLS CEMENT INTO COIL. (r SHUT DOWN SLB PUMP UNIT AND CLEAN UP (jw✓� LINE GOING TO PUMP. (.�/' USE RIG TO DISPLACE WITH BIOZAN. ZERO OUT MM WHEN CEMENT EXITS SHOE. PUMP ENTIRE CEMENT VOLUME,WHICH INCLUDES 20%EXCESS FOR OPEN HOLE AND 5.8 BBLS EXCESS FOR LOSSES,WITH yo RETURNS.-- - 11:50 - 12:10 0.33 CEMT P INTI LEAVE 2 BBLS ABOVE THE STINGER,PICK UP AND PULL OUT OF BACK DOOR FLAPPER. UP WT IS 39K,THE SAME AS BEFORE THE CEMENT JOB. PICK UP AND LAY IN REMAINING 2 BBLS AT 1:1,THEN RIH AND CONTAMINATE WITH BIOZAN TO JUST ABOVE 0-RING SUB. 12:10 - 15:00 2.83 CEMT P INTI POOH,START FILLING WELL FROM TOP TO MAINTAIN HOLE FILL. CONTINUE PUMPING BIOZAN UP PAST 7000 FT. 15:00 - 15:30 0.50 CEMT P INTI OPEN RISER AT 100 FT,NOTHING TO TAG UP WITH. POOH REMAINING DISTANCE. UD 6 JTS OF 1.25 CSH. 15:30 - 16:00 0.50 CEMT P INTI UD CEMENT STINGER. APPEARS TO HAVE BEEN HELICALLY BUCKLED FROM COMPRESSIVE LOAD. DISCUSS WITH ODE, DECIDE TO MAKE CLEANOUT RUN. 16:00 - 16:30 0.50 CEMT P INTI CONTINUE FILLING WELL. RIG UP TO CUT 100 FT OF CT FOR 13CR MANAGEMENT. 16:30 - 17:30 1.00 CEMT P INTI CUT 115'COIL,154'E-LINE. CONTINUE FILLING HOLE THROUGH THE KILL LINE. 17:30 - 18:30 1.00 CEMT N DPRB 10,354.00 INTI RECEIVE OPS NOTE FROM TOWN FOR CLEANOUT RUN. MU UP SLIM CONNECTOR. 18:30 - 19:00 0.50 CEMT N DPRB 10,354.00 INTI PRESSUE TEST BAKER BPV TO 3500 PSI ON BENCH. Printed 10/29/2012 10:37:24AM 4110 North America -ALASKA- BP Page 27 of 36 Operation Summary Report Common Well Name:S-37 1AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) • (ft) 19:00 - 20:45 1.75 CEMT N DPRB 10,354.00 INTI CUT ADDITIONAL 10'OF E-LINE AND REBOOT. INSTALL STINGER AND END CAP ON COIL CONNECTOR. PRESSURE TEST TO 3600 PSI,GOOD TEST. PULL TEST CONNECTOR TO 30K. 20:45 - 21:20 0.58 CEMT N DPRB 10,354.00 INTI MAKE UP CLEANOUT BHA. PUMPING 0.66 BPM DOWN THE KILL WITH NO RETURNS. 21:20 - 21:45 0.42 CEMT N DPRB 10,354.00 INTF STAB ON INJECTOR. TEST QTS TO 3500 PSI. 21:45 - 22:10 0.42 CEMT N DPRB 10,354.00 INTI RIH WITH CLEANOUT ASSY. PUMPING 0.4 BPM 8.6 MUD DOWN THE COIL AT 1480PS1,1 BPM DOWN THE KILL LINE,0.8 BOM RETURNS 22:10 - 00:00 1.83 CEMT N DPRB 10,354.00 INTI START PUMPING BIOZAN DOWN THE COIL AT 04 BPM WHILE RIH AT 90 FPM. SLOW SPEED TO 30 FPM WHEN APPROACHING LINER TOP. 8/24/2012 00:00 - 01:00 1.00 CEMT N DPRB 10,354.00 INTI RUN IN THROUGH TOP OF LINER, NO INDICATION AT LINER TOP OF ENTERING. 8.3 PPG BIOZAN IS AT THE BIT, PUMPING —DOWN THE COIL AT 1 BPM,700 PSI. :PUMPING DOWN KILL WITH MUD AT 1 BPM, 0.8 BPM RETURNS. NO EVIDENCE OF CEMENT OR STRINGERS. . RIH TO 10,280'. 01:00 - 02:00 1.00 CEMT N DPRB 10,354.00 INTI POH FROM 10,280'SWAP BACK TO PUMPING 8.6 MUD DOWN THE COIL AT 1 BPM. 02:00 - 02:30 0.50 CEMT N bPRB- 10,354.00 INTI KICK WHILE TRIPPING DRILL.ALL HANDS RESPONDED.SIMULATED CLOSING THE HCR FOR HARD SI. AAR WITH CREW,NEW ROUSTABOUT RECEIVED INSTRUCTIONS ON VERIFYING HCR IS CLOSING IN THE CELLAR. 02:30 - 03:30 1.00 CEMT N DPRB 10,354.00 INTI CONTINUE POH AT 90 FPM PUMPING MIN RATE DOWN COIL AND 1 BPM DOWN KILL LINE TO SURFACE. 03:30 - 04:00 0.50 CEMT N DPRB 10,354.00 INTI NEAR SURFACE,UN STAB INJECTOR AND WATCH FOR CONNECTOR SINCE IT IS SLIM. LAY DOWN CLEANOUT BHA. 04:00 - 06:00 2.00 BOPSUR P INTI PREP FOR BOPE TESTING. PJSM FOR TESTING TREE VALVES. CLOSE MASTER,SSV AND SWAB.RIG UP HOSE TO NEEDLE VALVE ON WING VALVE BLIND FLANGE. OPEN WING AND PRESSURE UP TO 3100 PSI IN BETWEEN SWAB AND SSV,LEAK TIGHT. BLEED TO 0 PSI. INSTALL LOW PRESSURE GUAGE TO MONITOR DURING TIME RAM (,ZAIP DOORS ARE OPEN. 06:00 - 11:00 5.00 BOPSUR P INTI OPEN DOORS ON BOPS AND INSPECT RAMS AND CAVITES. REPLACE TOP SEALS AND BLADE SEALS ON BLIND/SHEAR RAMS. REPLACE TOP SEAL ON ONE UPPER COMBI RAM. REPLACE VBR SEAL AND TOP SEAL ON VBR RAMS. REPLACE LOWER COMBI SEALS AND TOP SEALS. Printed 10/29/2012 10:37:24AM • North America-ALASKA- BP , Page 28 of 36 Operation Summary Report Common Well Name:S-37 I AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date.8/8/2012 LEnd Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 15:00 4.00 BOPSUR P INTI START BOP TEST. TEST BLIND SHEAR AND CHOKE MANIFOLD VALVES. STOP FOR ABOUT 30 MIN AND LOAD SCAFFOLD MATERIALS ONTO RIG. CONTINUE BOP TESTING. 15:00 - 15:30 0.50 BOPSUR P INTI AFTER BLIND/SHEAR RAMS PASS PRESSURE TEST, PERFORM TEST OF MANUAL LOCKS WITH MANIFOLD PRESSURE BLED TO ZERO. TEST IS SUCCESSFUL. 15:30 - 19:00 3.50 BOPSUR P INTI CONTINUE PRESSURE TESTING BOPS. PERFORM DRAWDOWN TEST ON ACCUMULATOR,4 SPARE N2 BOTTLES. 19:00 - 21:30 2.50 BOPSUR P INTI TEST MANUAL LOCKS ON LOWER COMBIS, VBR 2-3/8"x 3-1/7,UPPER COMBIS PER NORDIC PROCEDURE.ALL MANUAL LOCKS PASSED. 21:30 - 22:00 0.50 BOPSUR P INTI TEST INNER REEL VALVE AND PACK-OFF TO 250/3500 RSI. _. 22:00 - 22:30 0.50 BOPSUR P INTI UNSTAB INJECTOR,STRIP UP TO CHECK PIPE FOR SLIP MARKS 22:30 - 22:45 0.25 BOPSUR -N DPRB 10,354.Q0 INTI TEST TREE CAP TO 250 LOW AND 3500 PSI HIGH 22:45 - 00:00 1.25 CEMT N DPRB 10,354.00 INTI -PUMP OPEN SSV,OPEN MASTER AND SWAB TO BULLHEAD.WELL ON VAC. PUMP DOWN KILL LINE AT 4.5 BPM OF HI-VIS FLOW-PRO,FOR 240 TOTAL BBLS PUMPED. 8/25/2012 00:00 - 00:45 0.75 CEMT N CEMT 10,354.00 INTI FILL HOLE PUMPING 1.5 BM FLO-PRO DOWN KILL 00:45 - 01:30 0.75 CEMT N CEMT .1.0,354.00 INTI PJSM FOR BHA. MU SEAL ASSY BHA PER BTT,TOTAL BHA LENGTH=138'. 01:30 - 02:00 0.50 CEMT N CEMT 10,354.00 INTI GET ON WELL TEST QTS TO 250/3500 PSI. 02:00 - 03:30 1.50 CEMT N CEMT 10,354.00 INTI RIH AT 80 FPM PUMPING 0.5 BPM DOWN COIL,1.5 BPM DOWN THE BACKSIDE,0.4 BPM RETURNS. LOSS RATE OF 60 BPH DURING RIH. 03:30 - 04:00 0.50 CEMT N CEMT 10,354.00 INTI PUW 35K,SOW 21K SLOW RIH SPEED TO 20 FPM AT 8700' CIRC PRESSURE 880 PSI AT 0.5 BPM. 04:00 - 04:30 0.50 CEMT N CEMT 10,354.00 INTI TAG LINER TOP AT 8895' PRESSURE UP TO 1100 PSI TUCCOMIFTW SEAL ENGAGED. STACK 5K DOWN ENGAGING SEAL ASSY AT 8897.4'. PRESSURE UP AND SHEAR BALL SEAT AT 2500 PSI. ESTABLISH CIRCULATION:0.5 BPM @1070 PSI,1 BPM @1550 PSI,2 BPM @ 2400 PSI. 04:30 - 06:00 1.50 CEMT N CEMT 10,354.00 INTI POH WITH SEAL ASSY. PUMP 0.5 BPM DOWN COIL AND 1.8 BPM DOWN BACKSIDE. 1.3 BPM RETURNS WHILE POH AT 90 FPM. 06:00 - 07:30 1.50 CEMT N CEMT 10,354.00 INTI CONTINUE UD BHA. CONFIRM BALL SEAT HAS SHEARED ON TEST TOOL USED TO VERIFY PUMP THROUGH OF LINER SHOE. 07:30 - 13:00 5.50 CEMT N CEMT 10,354.00 INTI WAIT ON CEMENT PILOT TEST. FILL HOLE CONTINOUSLY WHILE WAITING, TAKING ABOUT 60 BBUHR. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP • Page 29 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 15:30 2.50 CEMT N CEMT 10,354.00 INTI P/U BHA#14. CEMENT STINGER+6 JTS 1.25 CSH. PRESSURE TEST QTS SUB LOW AND HIGH, GOOD. 15:30 - 16:00 0.50 CEMT N CEMT 10,354.00 INTI TRY TO RIH WITH BHA#14. AFTER 5 FT, STACKING-19K SURFACE WT. TROUBLESHOOT WEIGHT INDICATOR. 16:00 - 16:30 0.50 CEMT N CEMT 10,354.00 INTI LIFT INJECTOR OFF WELL. MAKE UP SAFETY JOINT AND PLACE ACROSS BOPS WHILE TROUBLESHOOT INJECTOR. DISASSEMBLE STRIPPER, RUN PIPE UP AND DOWN. PUT NEW COMPONENTS IN STRIPPER. 16:30 - 17:00 0.50 CEMT N CEMT 10,354.00 INTI L/D BHA#14. 17:00 - 17:30 0.50 CEMT N CEMT 10,354.00 INTI PRESSURE TEST PACKOFF 250/3500 PSI. GOOD TEST 17:30 - 19:00 1.50 CEMT N CEMT 10,354.00 INTI PJSM FOR BHA. MU CEMETING BHA#14,TOTAL LENGTH 206'. STAB ON WELL. TEST QTS. 19:00 - 21:00 2.00 CEMT N CEMT 10,354.00 INTI RIH PUMPING 0.5 BPM DOWN COIL,1.3 BPM DOWN KILL WITH 1 BPM RETUNS WITH RUNNING SPEED OF 100 FPM. RIG UP CEMENTERS,TAKE 20 BBLS KCL ONTO CEMENT TRUCK. 21:00 - 21:40 0.67 CEMT N CEMT 10,354.00 INTI AT 8700'SOW OF 19K,POW 37K. SLOW SPEED TO 20 FPM UNTIL PASSED LINER TOP. CONTINUE IN LINER AT 50 FPM. 21:40 - 22:30 0.83 CEMT N CEMT 10,354.00 INTI AT 10,000'PUMPING 0.5 BPM DOWN COIL @ 920 PSI,1 BPM @ 1225 PSI,2 BPM @ 1800 PSI. CALL ODE TO CONFIRM PLAN FORWARD TO PUMP 20 BBL CEMENT AND THEN UNSTING. 22:30 - 22:50 0.33 CEMT N CEMT 10,354.00 INTI RIH AT 30 FPM, PUMPING 0.5 BPM DOWN COIL AT 835 PSI,1.36 BPM DOWN BACKSIDE, 1.12 BPM RETURNS. 40K POW AT 10,200'. RIH AT 20 FPM.21K RIH WEIGHT. TAG 0-RING FLAPPER SUB AT 10,345'. INDICATION OF SHEAR BY-2K,THEN WEIGHT CAME BACK TO RIH WEIGHT OF 21K BEFORE DROPPING.STACK 8K AND ENGAGE AT 10,347'. PUMP DOWN COIL AT 0.5 BPM=830 PSI, 1 BPM= 1135 PSI,2 BPM=1800 PSI 22:50 - 23:10 0.33 CEMT N CEMT 10,354.00 INTI PJSM FOR CEMENT JOB WITH NORDIC CREW,TP,SLB,CEMENTERS,BTT,TRUCK PUSHER,SITE CONTROL. 23:10 - 00:00 0.83 CEMT N CEMT 10,354.00 INTI PRESSURE TEST CEMENT LINES TO 4500 PSI. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP • Page 30 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/26/2012 00:00 - 01:35 1.58 CEMT N CEMT 10,354.00 INTI BATCH 20 BBLS CEMENT,FLOOD RIG LINES WITH BIOZAN,SWAP TO CEMETERS. MAINTAIN HOLE FILL DOWN THE BACKSIDE OF 1.3 BPM,1.3 BPM RETURNS. PUMP THE FOLLOWING: 18 BBLS KCL,2 BPM @ 1765 PSI 22 BBLS 15.8 PPG CLASS G CEMENT,2 BPM C" ' -@ 2440 PSI 5 BBLS FRESH WATER 20 BBLS 8.55 PPG BIOZAN 2 BPM @ 1400 PSI WITH CEMENT COMING OUT THE SHOE, CIRC PRESSURE CLIMBING FROM 1800 PSI TO 2400 PSI. 21 BBLS OUT THE COIL,SHUT DOWN PUMP AND PULL UP 10'TO CLOSE THE FLAPPER. 01:35 - 04:00 2.42 CEMT N CEMT 10,354.00 INTI POH AT 55 FPM PUMPING 1 BPM BIOZAN DOWN THE COIL FOR AN ADDITIONAL 120 BBLS BIOZAN PUMPED. FILL BACKSIDE AT 1.5 BPM,1.5 BPM RETURNS. INCREASE POH SPEED TO 90 FPM AT 7000'. AT 3AM A VAC TRUCK THAT WAS STAGED ON LOCATION HAD A FITTING LEAK UPSTREAM OF THE VALVES IN THE BACK OF THE TRUCK.THE DRIVER DISCOVERED THE SUMP FULL AND-1/2 GAL KCL LEAKED ONTO THE PAD(IR-4214952). 04:00 - 06:00 2.00 CEMT N CEMT 10,354.00 INTI INSTAB FROM WELL,MONITOR COIL WHILE COMING UP TO CONNECTOR. PJSM FOR LAYING DOWN BHA. LAY DOWN CEMENTING BHA. 06:00 - 07:00 1.00 STMILL P INTI INSTALL BTT EXTERNAL CONNECTOR AND PREP RIG FLOOR FOR M/U MILLING BHA. 07:00 - 07:30 0.50 STMILL P INTI PULL TEST CT CONNECTOR TO 35K,GOOD. PRESSURE TEST TO 300/3500 PSI,GOOD. 07:30 - 08:00 0.50 STMILL P INTI PJSM FOR PICKING UP MILLING BHA WITH 50 JTS OF 2.06 CSH. 08:00 - 11:30 3.50 STMILL P INTI M/U BHA#15. 2.74"MILL,STRING REAMER AND MOTOR,50 JTS OF 2.06"CSH. M/U SWIVEL AND CT RISER. PRESSURE TEST QTS TO 250/3500 PSI, GOOD. 11:30 - 14:20 2.83 STMILL P INTI RIH BHA#15. WEIGHT CHECK AT LINER TOP IS 35K. GO TO 1.6 BPM THROUGH MOTOR AFTER ENTERING LINER. 14:20 - 18:00 3.67 STMILL P INTI WEIGHT CHECK AT 10320 FT IS 38K. TAG AT MIN RATE AT 10344 FT. START MILLING OUT 0-RING SUB. STALL AT 10345.3 FT. PICK UP 100 FT,CLEAN PICKUP. CONTINUE MILLING,WORK PAST 10345 FT. 18:00 - 18:45 0.75 STMILL P INTI STALL AT 10,346', UNABLE TO PULL UP, WORK PIPE,CAME FREE ON 2ND JAR LICK. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP Page 31 of 36 Operation Summary Report Common Well Name:S-37 1 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122 00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:OOAM 'Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:45 - 21:15 2.50 STMILL P INTI FREE SPIN 2180 PSI,EASE BACK DOWN AT 0.5 FPM,200 PSI MOTOR WORK AT 10,342'. PUMPING DOWN THE COIL AT 1.43 BPM.0.77 BPM DOWN THE BACKSIDE WITH 0.81 BPM RETURNS. NO PROGRESS IN 2.5 HOURS OF MILLING 21:15 - 23:15 2.00 STMILL N DPRB 10,346.00 INTI CALL ODE WITH PLAN TO POH FOR MORE AGGRESSIVE MILL. POH FROM 10,343'. 23:15 - 23:30 0.25 STMILL N DPRB 10,346.00 INTI PJSM FOR LAYING DOWN BHA. 23:30 - 00:00 0.50 STMILL N DPRB 10,346.00 INTI LAY DOWN 2-3/8"PH6 8/27/2012 00:00 - 02:30 2.50 STMILL N DPRB 10,344.00 INTI STAND BACK 2-1/16"CSH,PARABOLIC MILL SHOWS VERY LITTLE WEAR. 02:30 - 04:00 1.50 STMILL N DPRB 10,344.00 INTI MU BHA#16 WITH BOT PIRANHA MILL(JUNK MILL WITH OFF-CENTER JUNK BLADES)AND ACCELERATOR AND 50 JOINTS OF 2-1/16" CSH. MAINTAIN HOLE FILL DOWN KILL LINE OF 0.9/0.3 BPM IN/OUT. 04:00 - 04:30 0.50 STMILL _N DPRB 10,344.00 INTI STAB INJECTOR.TEST QTS TO 250/3500 PSI. 04:30 - 06:00 1.50 STMILL N DPRB 10,344.00 INTI RIH -PUMPING.4 BBUMIN DOWN COIL AT 1100 PSI SURFACE PRESSURE TRIPPING IN HOLE AT 85 FPM -PUMPING.9 BBUMIN DOWN BACKSIDE WITH .6 BBUMIN RETURNS-8.6 PPG FLOWPRO -LOSSES CALCULATED AT 40 BBLS/HR 06:00 - 08:30 2.50 STMILL P INTI BEGIN MILLING O-RING SUB OUT FROM 10344 FT. MAKE STEADY PROGRESS_. 08:30 - 09:10 0.67 STMILL P INTI CONTINUE MILLING. AT 10357 FT APPEAR TO BE MILLING CEMENT. PICKUP TO CHECK WEIGHT PERIODICALLY. DURING ONE PICKUP. SEE A 3K WT BOBBLE WITH MOTOR WORK AT 10312 FT.WELL ABOVE THE 0-RING SUB. 09:10 - 10:00 0.83 STMILL P INTI MILL TO 10360 FT. PULL WIPER TRIP BACK ABOVE LINER TOP. CLEAN PASS BACK TO 8800 FT. SHUT DOWN PUMP GOING DOWN CT, FILL WELL FROM TOP. 10:00 - 12:00 2.00 STMILL P INTI RIH,TRY AND TAG LINER TOP FOR DEPTH CONTROL. WEIGHT BOBBLE AT 8892 FT, LIKELY TOP OF LINER. THIS DEPTH CORRECTION OF-22 FT WILL PLACE THE 0-RING SUB EXACTLY ON DEPTH WITH THE TALLY. CLEAN PASS DOWN TO 10360 FT,CONTINUE MILLING. 12:00 - 12:50 0.83 STMILL P INTI AT 10365.5 FT,MILLING SLOWS DOWN, WEIGHT NOT COMING BACK. MILLING FLOAT SUB OUT,BASED ON DEPTHS. AT 10367.5 FT PICK UP THROUGH FLOAT SUB,CLEAN PASS UP AND DOWN. 12:50 - 13:30 0.67 STMILL P INTI CONTINUE MILLING FROM 10367.3 FT. MILL TO 10370 FT. Printed 10/29/2012 10.37:24AM • North America -ALASKA- BP Page 32 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 16:10 2.67 STMILL P INTI 100 FT WIPER TRIP FROM 10370 FT. CONTINUE MILLING FROM 10368 FT. 16:10 - 18:30 2.33 STMILL P INTI STILL AT 10368.8 FT. VIRTUALLY NO PROGRESS IN THE LAST 2.5 HRS. POOH TO CHANGE MILL AND STRING REAMER THIS LEAVES ABOUT 8 FT OF CEMENT AND THE GUIDE SHOE LEFT TO MILL OUT 18:30 - 19:00 0.50 STMILL P INTI TAG UP AT SURFACE. PJSM FOR BHA. 19:00 - 21:30 2.50 STMILL P INTI DROP 1/2"BALL TO OPEN CIRC SUB. LAY DOWN 4 JTS 2-3/8"PH-6,STAND BACK 50 JTS 2-1/16"CSH. FILL HOLE EVERY 5 STANDS AT SURFACE WITH MILL,MILL SHOWS VERY LITTE WEAR,A CIRCULAR WEAR SPOT ABOUT THE SIZE OF A DIME OFF CENTER WAS THE ONLY NOTICABLE CHANGE IN THE MILL FROM WHEN IT WAS RIH. RECOVERED 1/2"BALL FROM CIRC SUB. 21:30 - 22:15 0.75 STMILL P INTI CHANGE OUT 4 WAY SLING ON INJECTOR WHICH IS DUE FOR INSPECTION. 22:15 - 22:30 0.25 STMILL ` P 1NT1 _PJSM FOR PU BHA 22:30 - 00:00 1.50 STMILL P INTI MU BHA#17 TO MILL OUT SHOE TRACK RUN 25 STANDS OF 2-1/16"CSH,4 JTS 2-3/8" 8/28/2012 00:00 - 00:35 0.58 STMILL P INTI STAB INJECTOR PRESSURE TEST QTS TO 250/3500 PSI. 00:35 - 02:00 1.42 STMILL P INTI RIH PUMPING 0.4 BPM DOWN THE COIL,1 BPM DOWN THE BACKSIDE WITH 1 BPM RETURNS. 02:00 - 03:00 1.00 STMILL P INTI POW 8800'ABOVE LINER AT 33K,RUN IN WAIT OF 19K.SEE LINER TOP AT 8892'(-22' CORRECTION). POW AT 10290'OF 37K, FREESPIN 2680 PSI AT 1.5 BPM. 03:00 - 04:00 1.00 STMILL P INTI START MILLING AT 10368'WITH,PUMPING 1.5 BPM DOWN COIL,1.15 BPM DOWN BACKSIDE AND 1 BPM RETURNS. 120-320 PSI MW. 04:00 - 06:00 2.00 STMILL P INTI MILLING SPEED PICKS UP WITH 330 PSI MW, MILLING FORMATION FROM 10376'(SHOULD BE MILLING FORMATION). 06:00 - 11:00 5.00 STMILL P INTI MILL FORMATION TO 10,383'. REAM AND BACK REAM SEVERAL TIMES. 11:00 - 14:00 3.00 STMILL P INTI POOH. KEEP HOLE FULL. HOLD PJSM NEAR SURFACE. _ 14:00 - 15:30 1.50 STMILL P INTI GET OFF WELL. UNSTAB COIL. LD MILLING BHA. 15:30 - 16:30 1.00 STMILL N CEMT 10,380.00 INTI MU PORTES SEAL STEM BHA(NO CHECKS) STAB COIL. GET ON WELL. 16:30 - 19:00 2.50 STMILL N CEMT 10,380.00 INTI RUN IN HOLE. PUMPING 1 BOM ACROSS THE TOP FOR HOLE FILL,0.5 BPM DOWN THE COIL. Printed 10/29/2012 10:37:24AM North America-ALASKA- BP Page 33 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 !X3-0011 WF(3,050,122.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 20:00 1.00 STMILL N CEMT 10,384.00 INTI RIH,18K RUN IN WEIGHT,35K POW AT 8800'. PUMPING 0.5 BPM DOWN THE COIL AT 1230 PSI,0.7 BPM ON THE BACKSIDE,0.6 BPM RETURNS. TAG LINER TOP AT 8895',STACK DOWN 10K TO ENGAGE SEALS.PRESSURE UP TO PSI TO SHEAR PINNED BALL SEAT AT 3800 PSI, --BLEED OFF PRESSURE TO 1000 PSI AND HOLD FOR 5 MIN,PRESSURE DROP TO 930 'PSI IN 5 MIN. 20:00 - 22:00 2.00 STMILL N CEMT 10,380.00 INTI CALL ODE WITH TEST RESULTS. POH PUMPING 0.5 BPM DOWN THE COIL, 1 BPM DOWN THE BACKSIDE,0.9 BPM RETURNS. 22:00 - 22:30 0.50 STMILL N CEMT 10,380.00 INTI STAND BACK INJECTOR. PJSM FOR LAYING.:DOWN BHA. 22:30 - 00:00 1.50 STMILL N CEMT 10,380.00 INTI REVERSE 3BPM TO PUMP SLACK BACK.CUT 253'OF COIL FOR CHROME AND SLACK MANAGEMENT DRESS END OF COIL FOR CONNECTOR, TEST E-LINE FOR CONDUCTIVITY. 8/29/2012 00:00 - 01:40 1.67 DRILL P PROD1 INSTALL SLIM CONNECTOR,PULL TEST TO 38K. REHEAD E-LINE 01:40 02:45 1.08 DRILL P PROD1 INSTALL QUICK CONNECT,PRESSURE TEST TO 3800 PSI 02:45 - 03:20 0.58 DRILL P PROD1 PRESSURE TEST NIGHT CAP PRIOR TO - BULLHEADING 250/3500 PSI.GOOD TEST. 03:20 - 04:15 0.92 DRILL P PROD1 PJSM.BULLHEAD 240 BBLS OF 8.6 PPG FLO-PRO AT 4.5 BPM AND 900 PSI.WELL WAS ON VACUUM. 04:15 - 05:00 0.75 DRILL P c PROD1 PJSM TO MU BHA. MU 2-3/8"DRILLING BHA(69.64'TOTAL LENGTH). 05:00 - 06:00 1.00 DRILL P PROD1 GET ON WELL,TEST SMART TOOLS. TEST QTS. 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS RIG STATUS AND CURRENT OPS. CONTINUE TO RUN IN HOLE. 06:30 - 08:30 2.00 DRILL P PROD1 CONTINUE TO RUN IN HOLE. 08:30 - 09:00 0.50 DRILL P PROD1 LOG GR TIE IN FROM 8900'. SUBTRACT 11' CORRECTION. 09:00 - 11:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 10,354'. 3810 PSI FS AT 1.51 BPM IN/0.48 BPM OUT DOWN COIL. ALSO PUMP 0.68 BPM DOWN CT ANNULUS. 1.21K#DHWOB. BHP/ECD/TVD:4784 PSI/10.48 PPG/8605' IA/OA/PVT:0 PSI/28 PSI/VARIABLE. DRILL TO 10,530' 11:00 - 13:00 2.00 DRILL P PROD1 WIPER TRIP TO TOP OF LINER WITH OPEN EDC INSIDE PIPE. LOG GR TIE IN TO CONFIRM DEPTH. NO CORRECTION. 13:00 - 14:00 1.00 DRILL P PROD1 RUN IN HOLE. CLOSE EDC AT SHOE. WIPER TRIP TO BOTTOM. Printed 10/29/2012 10:37:24AM • North America -ALASKA- BP • Page 34 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 14:00 - 17:30 3.50 DRILL P PROD1 DRILL AHEAD FROM 10,530'. 3750 PSI FS AT 1.51 BPM DOWN COIL. 0.68 BPM DOWN CT ANNULUS. 0.47 BPM RTNS. 1.54 K#DHWOB. DRILL TO 10,650'. 17:30 - 20:15 2.75 DRILL P PROD1 WIPER TRIP TO LINER TOP. 20:15 - 23:30 3.25 DRILL P PROD1 _ BACK ON BOTTOM DRILLING AT 10,650'. 3080 PSI AT 1.5 BPM OF 8.6 PPG FLO-PRO. FILLING BACKSIDE WITH 0.7 BPM,0.7 BPM RETURNS DHWOB:2.1K, ROP:50 FPH. DRILL TO.10,800' 23:30 - 00:00 0.50 DRILL P PROD1 WIPER TRIP TO LINER TOP,OPEN EDC ONCE IN LINER AND PUMP AT 2.5 BPM 8/30/2012 00:00 - 02:00 2.00 DRILL P PROD1 WIPER TRIP TO LINER TOP,OPEN EDC ONCE IN LINER AND PUMP AT 2.5 BPM. 02:00 - 02:25 0.42 DRILL P PROD1 OBTAIN SLOW PUMP RATES 02:25 - 05:00 2.58 DRILL P PROD1 DRILL AHEAD FROM 10,800'PUMPING 1.5 BPM AND 3100 PSI CIRC PRESSURE,0.8 BPM DOWN THE BACKSIDE,0.8 BPM RETURNS. DHWOB: 1.8K, ROP:70 FPH,PVT:300 BBLS DRILL TO 10,900' 05:00 - 05:50 0.83 • DRILL P PROD1 CONTINUE TO DRILL AHEAD FROM 10,900' PUMPING 1.5 BPM AND 3100 PSI CIRC • PRESSURE,0.8 BPM DOWN THE BACKSIDE, 0.8 BPM RETURNS. DHWOB:2.5K,ROP:55 FPH, DRILL TO 10,955' **START KCL DOWN COIL AT 1.5 BPM TO EVALUATE HOW LOSSES WILL CHANGE. 05:50 - 06:00 0.17 DRILL - P PROD1 START WIPER TRIP TO LINER TOP 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS RIG STATUS AND OPERATIONS. CONTINUE WIPER TRIP. 06:30 - 07:45 1.25 DRILL P PROD1 WIPER TRIP TO TOP OF LINER. 07:45 - 08:15 0.50 DRILL P PROD1 LOG GR TIE IN FROM 8900'. ADD 4' CORRECTION. 08:15 - 09:15 1.00 DRILL P PROD1 RUN IN HOLE TO BOTTOM. 09:15 - 12:30 3.25 DRILL P PROD1 DRILL AHEAD FROM 10,965'. 1650 PSI FS AT 1.60 BPM KCL DOWN COIL. CIRC 0.8 BPM MUD ACROSS TOP OF WELL. 0.8 BPM RTNS. 150-250 PSI MTR WORK. 2.11 K#DHWOB. IA/OA/PVT:0 PSI/465 PSI/VARIABLE BHP/ECD/TVD:4377 PSI/10.48 PPG/8601'. 12:30 - 14:00 1.50 DRILL P PROD1 WIPER TRIP TO 8900'. OPEN EDC IN LINER. 2510 PSI AT 1.78 BPM IN. 14:00 - 15:00 1.00 DRILL P PROD1 RIH. CLOSE EDC. WIPER TO BOTTOM. 15:00 - 18:30 3.50 DRILL P PROD1 DRILL AHEAD FROM 11,101'. 1800 PSI FS AT 1.5 BPM DOWN COIL. CIRC 0.8 BPM ACROSS WELL. 0.75 BPM TOTAL RTNS. 200 PSI MTR WORK. DHWOB:2.11K# 18:30 - 20:00 1.50 DRILL P PROD1 WIPER TRIP TO LINER TOP FROM 11255' 20:00 - 20:30 0.50 DRILL N DFAL 11,255.00 PROD1 ON WIPER TRIP AT 10,340 RIGHT ABOVE INTERMEDIATE LINER SHOE EDC FAILURE, DECISION TO POH TO CHANGE OUT TOOLS. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP I/ Page 35 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date: 9/7/2012 .X3-0011 WF(3,050,122.00) Project:Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 22:30 2.00 DRILL N DFAL 11,255.00 PROD1 POH FROM 10340',KEEPING HOLE FULL AS POH BY PUMPING 1.5 BPM THROUGH PARTIALLY OPEN EDC. 22:30 - 23:00 0.50 DRILL N DFAL 11,255.00 PROD1 AT SURFACE,STAND BACK INJECTOR. LAY DOWN BHA.BIT SHOWS LITTLE WEAR, RATED 1:1. 23:00 - 00:00 1.00 DRILL P PROD1 _PERFORM WEEKLY BOPE FUNCTION TEST, ALL RAMS AND VALVES FUNCTIONED PROPERLY. CHANGE OUT SWABS ON MUD PUMP#1 8/31/2012 00:00 - 00:30 0.50 DRILL N DFAL PROD1 MU DRILLING BHA WITH NEW MWD SUB AND BIT, PROGRAM TOOL AND VERIFY DATA ACQUISITION. 00:30 - 00:50 0.33 DRILL N DFAL _ • PROD1 GET ON WELL. PRESSURE TEST QTS TO 250/3500 PSI. GOOD TEST. 00:50 - 02:45 1.92 DRILL N DFAL PROD1 RIH PUMPING 0.6 BPM 8.4 PPG KCL DOWN THE COIL 0.8 BPM 8.5 PPG FLO-PRO DOWN THE BACKSIDE WITH RETURNS WHILE RIH. 02:45 - 03:00 0.25 DRILL -N DFAL PROD1 TIE-IN AT JB MARKER IN KINGAK WITH(-13)' CORRECTION. 03:00 - 04:00 1.00 DRILL N DFAL PROD1 CONTINUE IN HOLE PUMPING 0.5 BPM,60 PSI CIRC PRESSURE. BACKSIDE ON 0.8 BPM WITH 0.5 BPM RETURNS WHILE RUNNING IN HOLE. 04:00 - 06:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 11255'. PUMPING 1.6 BPM KCL DOWN THE COIL AT 2260 PSI,0.7 BPM MUD DOWN THE BACKSIDE,0.7 BPM RETURNS. DHWOB:2.1K#,ROP:90-110' PUMP 20 BBL MUD PILL 06:00 - 06:15 0.25 DRILL P PROD1 CREW CHANGE. DISCUSS OPERATIONS AND RIG/EQUIPMENT STATUS. CONTINUE DRILLING AHEAD. 06:15 - 12:30 6.25 DRILL P PROD1 DRILL AHEAD FROM 11,400'. 1350 PSI FS ON KCL. 2130 PSI FS ON MUD. 1.0-1.9K#DHWOB 200-300 PSI MTR WORK. IA/OA/PVT: 0 PSI/27 PSI/VARIABLE BHP/ECD/TVD:4377 PSI/10.48 PPG/8607' POOR WT TRANSFER WITH KCL. BEGIN TO PUMP MUD WHILE DRILLING. PUMP KCL WHILE TRIPPING. DRILL TO 11,545' 12:30 - 16:00 3.50 DRILL P PROD1 WIPER TRIP TO TOP OF 3-1/4"LINER. CIRCULATE KCL DURING WIPER TRIP. 16:00 - 17:15 1.25 DRILL P PROD1 DRILL AHEAD FROM 11,545'. 2950 PSI FS AT 1.55 BPM IN. MUD DOWN COIL. 0.73 BPM KCL DOWN CT ANNULUS. 0.68 BPM is' LITT DRILL TO 11583'. \ EIGHT-IRAN R VERY POOR. TOWN-ELECTS TO CALL THIS TD. 17:15 - 19:15 2.00 DRILL P PROD1 WIPER TRIP TO TOP OF LINER. MAINTAINING BACKSIDE HOLE FILL AT 0.7 BPM IN/OUT, PUMPING 2 BPM KCL DOWN COIL WITH EDC OPEN IN 3-1/4"LINER. _ 19:15 - 19:30 0.25 DRILL P PROD1 TIE-IN AT 8940'TO JB MARKER WITH(+5.5)' CORRECTION. Printed 10/29/2012 10:37:24AM North America -ALASKA- BP Page 36 of 36 Operation Summary Report Common Well Name:S-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/8/2012 End Date:9/7/2012 X3-0011 WF(3,050,122.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63: 37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 21:30 2.00 DRILL P PROD1 RIH AT 25 FPM PUMPING 1.5 BPM,0.7 BPM/0.55 BPM IN/OUT ON THE BACKSIDE. TAG TD AT 11,583'WITH 1K WOB,CONFIRM TAG. 21:30 - 00:00 2.50 DRILL P PROD1 POH FROM TD, LEAVE LINER PILL OF CLEAN 8.6 PPG FLO-PRO AT 1 BPM DOWN THE COIL. CONTINUE FILLING HOLE DOWN BACKSIDE 0.7 BPM,0.8 BPM RETURNS. 9/1/2012 00:00 - 01:25 1.42 DRILL P PROD1 POH, LEAVE LINER PILL OF CLEAN 8.6 PPG FLO-PRO AT 1 BPM DOWN THE COIL. CONTINUE FILLING HOLE DOWN BACKSIDE 0.7 BPM,0.8 BPM RETURNS. ***SWITCH TO COMPLETIONS REPORT*** • Printed 10/29/2012 10:37:23AM North America -ALASKA- BP Page 1 of 2 Operation Summary Report Common Well Name:S-37 AFE No Event Type:COM-ONSHORE(CON) Start Date: End Date:9/2/2012 X3-0011 WF(1,682,212.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release:9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00©69.30ft(above Mean Sea Level) Date r From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/1/2012 01:25 - 01:30 0.08 CASING P RUNPRD PJSM FOR LAYING DOWN BHA, LAY DOWN BHA 01:30 - 02:45 1.25 CASING P RUNPRD INSTALL NIGHT CAP,FILL WELL WITH MUD, REBUILD BHI TOOLS, R/U FLOOR FOR RUNNING 2 3/8"COMPLETION LINER 02:45 - 03:10 0.42 CASING P RUNPRD PJSM WITH BAKER OIL TOOLS FOR MAKING UP COMPLETIONS BHA AND LINER 03:10 - 05:20 2.17 CASING P RUNPRD_ M/U AND RUN IN HOLE 42 JOINTS OF 2 3/4" _ LINER, KEEP HOLE FILLED ON BACKSIDE AT 1 BPM,.15 BPM RETURNS 05:20 - 05:45 0.42 CASING P RUNPRD M/U COMPLETION BHA ONTO LINER AND STAB ON INJECTOR HEAD 05:45 - 08:00 2.25 CASING P RUNPRD RUN IN HOLE. 08:00 - 08:30 0.50 CASING P RUNPRD LOG GR TIE FROM 8900'. SUBTRACT 14'CORRECTION. 08:30 - 09:15 0.75 CASING P RUNPRD RUN IN HOLE. 09:15 - 09:30 0.25 CASING P RUNPRD TAG TD AT 11584'. 36K#UP WT. CIRC AT 1.5-BPM AT 3850 PSI. PU. 32K#UP WT. LINER IS RELEASED. 09:30 - 10:00 0.50 CASING -P RUNPRD DISPLACE 3-1/4"LINER WITH KCL FROM TOP OF SLOTTED LINER. -LINER TOP AT 10,305'. LINER BTM AT 11,583'. ELM. 10:00 - 12:00 2.00 CASING P RUNPRD POOH. FILL DOWN COIL AND ACROSS WELLHEAD. 12:00 - 13:30 1.50 CASING P_ RUNPRD HOLD PJSM. AT SURFACE. GET OFF WELL. LD BHA TOOLS. 13:30 - 14:30 1.00 CONS P POST DISPLACE WELL TO KCL FROM SURFACE. PUMP 100 BBLS TO TOL. 14:30 - 15:30 1.00 CONS P POST RU LRS TO PUMP DIESEL FP. HOLD PJSM. PT LINES. PUMP 40 BBLS DIESEL DOWN TBG. 15:30 - 16:30 1.00 BOPSUR P POST GREASE TREE VALVES. SET BPV WITH DRY ROD. 16:30 - 17:30 1.00 BOPSUR P POST SET INJECTOR ON LEGS. CLEAR FLOOR. CLOSE MASTER,SSV,AND SWAB. PT FROM WING VALVE. 17:30 - 23:00 5.50 BOPSUR P POST PREP TO OPEN RAM DOORS AND INSPECT BOPS. CHANGEOUT BLADE SEALS ON BLINDS. CHANGEOUT 2-3/8"TOP SEAL ON UPPER RAMS. MAINTENANCE ON POWERPACK,INJECTOR AND REEL STAND. CLEANOUT PITS. 23:00 - 00:00 1.00 BOPSUR P POST PJSM ND BOPE. 9/2/2012 00:00 - 02:00 2.00 BOPSUR P POST _ND BOPE 02:00 - 02:30 0.50 WHSUR P POST INSTALL TREE CAP AND RIG UP TO TEST TREE CAP 02:30 - 04:40 2.17 BOPSUR P POST TEST TREE CAP TO 250 LOW AND 3500 HIGH FOR 5 MINUTES EACH. 10 ATTEMPTS,SUSPECTED SWAB VALVE LEAKING.CYCLED SWAB VALVE AND ABLE TO GET SUCCESSFUL TEST. Printed 10/29/2012 10:38:13AM • North America -ALASKA- BP • Page 2 of 2 Operation Summary Report Common Well Name:S-37 AFE No Event Type:COM-ONSHORE(CON) Start Date: End Date: 9/2/2012 X3-0011WF(1,682,212.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NORDIC 2 Spud Date/Time: 11/6/1992 12:00:00AM Rig Release: 9/2/2012 Rig Contractor:NORDIC CALISTA UWI: Active Datum:63:37 10/22/1992 00:00 @69.30ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:40 - 06:00 1.33 DEMOB P POST FLUSH MUD LINES AND CLEAR PITS OF REST OF MUD.OFF LOAD SAME ONTO TRUCK(16 BBLS). RELEASE RIG AT 0600 HRS ON 9-2-2012 -ALL TREE AND WELLHEAD VALVES LEFT CLOSED TO PRESSURE GAUGES. -FINAL IA/OA=0/0 PSI -TREE/WELLHEAD AND CELLAR CLEAN WELLWORK TRANSFER PERMIT CLOSED OUT WITH PAD OPERATOR. -WELL HANDOVER COMPLETED WITH WELLS GROUP(NOTE: LINER TOP PACKER MUST BE SET POST RIG) 25.25 DAYS FROM RIG ACCEPT TO RIG RELEASE ORIGINAL AFE P50 TARGET=17.5 DAYS PREPARE TO MOVE RIG TO NEXT WELL S-32. Printed 10/29/2012 10:38:13AM S-37A, Well History (Post Rig Sidetrack) Date Summary 09/07/12 T/I/O=Vac/0/0 Conducted PJSM. Opened Master, SSV, and Swab valves. Confirmed 0 psi. at tree cap. Torqued all tree flanges to specs. 09/08/12 T/I/O =Vac/0/0. Conduct PJSM. Used SV and SSV as barriers. PT'd tree cap to 500 psi.for 5 min. (passed) prior to removal of tree cap. Bled off pressure and performed LIT. (passed). RU lubricator w. 1- 1' ext. and CIW 4" pulling tool. PT'd lubricator to 200-300 psi. low for 5 min. (passed)and 3500 psi. high for 5 min. (passed). Pulled 4"CIW BPV# 131 tagging at 114". SI SSV and SV(23 1/2 turns) and bled off pressure. Made C/O with night crew. Night crew rigged down lubricator and rigged up with 1-1'ext., CIW setting tool, and 4"CIW TWC#279. PT'd lubricator(same steps as above) passed. Set TWC tagging at 114". PT'd tree using TWC as barrier to 200-300 psi. low for 5 min. (passed) and 5000 psi. high for 5 min. (passed). Tests charted and documented in QC reports, (field charted tests). SI. SSV and SV. Bled off pressure and Rigged down lubricator. Pt'd tree cap to 500 psi. (passed). 10/17/12 DRIFT W/2.53"CENT., 1-3/4" S. BAILER TO DEVIATION @ 9375' SLM. DRIFT&TAG DEPLOYMENT SLEEVE W/10'x 3.70" DMY WHIPSTOCK DRIFT&3.50" LIB @ 8874'SLM. LRS PUMPED 150 BBLS CRUDE DOWN TBG TO ASSIST W/B&F. B&F W/3.805"GAUGE RING, 8'x1.5" STEM,4-1/2" BLB, AND 2.15" CENT. SD @ 8866' SLM AND SAW TRAVEL DOWN TO 8874' SLM. SET BAKER KB LTP W/HES DPU IN DEPLOYMENT SLEEVE @ 8863" MD (MID ELEMEN]. SET 4 1/2 CAT STANDING VALVE LTTP IN LTP @ 8878'SLM. LRS MIT-T TO 250 PSI FOR 5 MIN. (PASS). LRS MIT-T TO 2400 PSI PASSED. CCP 10/18/12 PULL 4-1/2" CAT STANDING VALVE LTTP FROM 8857'SLM. Page 1 of 1 BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB S Pad S-37 S-37APB1 Survey: MWD Survey Report - Geographic 14 September, 2012 BAKER HUGHES Survey Report-Geographic 0 big INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-37 Project: Prudhoe Bay TVD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Site: PBS Pad MD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Well: S-37 North Reference: True Wellbore: S-37APB1 Survey Calculation Method: Minimum Curvature Design: S-37APB1 Database: EDM.16-ANC Prod-WH24P 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 PBS Pad,TR-12-12 Site Position: Northing: 5,980,854.54ft Latitude: 70°21'23.002 N From: Map Easting: 617,919.92ft Longitude: 149°2'32.343 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 0.90 ° Well S-37 API No 500292229100 Well Position +N/-S 0.00 ft Northing: 5,979,854.57 ft Latitude: 70°21'12.830 N +E/-W 0.00 ft Easting: 620,084.30 ft Longitude: 149° 1'29.543 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore S-37APB1 API No 500292229170 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 8/15/2012 20.72 81.04 57,650 Design S-37APB1 Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,044.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 33.66 0.00 0.00 111.36 Survey Program Date: 9/14/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 372.00 9,044.00 1 :MWD-Standard(S-37) MWD MWD-Standard 9,141.00 9,900.00 MWD(S-37APB1) MWD MWD-Standard 9/14/2012 4:05:18PM Page 2 COMPASS 2003.16 Build 73 //%I BAKER HUGHES Survey Report-Geographic � 'I' INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-37 Project: Prudhoe Bay TVD Reference: 63:37 10/22/1992 00:00©69.30ft(generic drillir Site: PB S Pad MD Reference: 63:37 10/22/1992 00:00©69.30ft(generic drillir Well: S-37 North Reference: True Wellbore: S-37APB1 Survey Calculation Method: Minimum Curvature Design: S-37APB1 Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,044.00 31.20 111.70 8,588.39 -314.80 1,713.53 5,979,567.30 621,802.51 70°21'9.732 N 149°0'39.460 W TIP 9,141.00 30.58 111.70 8,671.63 -333.22 1,759.80 5,979,549.63 621,849.07 70°21'9.551 N 149°0'38.108 W KOP 9,161.40 33.33 112.29 8,688.94 -337.26 1,769.81 5,979,545.74 621,859.14 70°21'9.511 N 149°0'37.815 W 9,191.26 41.57 112.92 8,712.63 -344.24 1,786.55 5,979,539.03 621,875.99 70°21'9.442 N 149°0'37.326 W 9,215.38 48.30 113.31 8,729.69 -350.93 1,802.21 5,979,532.60 621,891.75 70°21'9.377 N 149°0'36.868 W 9,236.71 54.53 113.60 8,742.99 -357.56 1,817.50 5,979,526.21 621,907.14 70°21'9.311 N 149°0'36.421 W 9,270.70 64.22 113.99 8,760.28 -369.36 1,844.23 5,979,514.85 621,934.06 70°21'9.195 N 149°0'35.640 W 9,300.66 72.69 112.46 8,771.27 -380.33 1,869.82 5,979,504.29 621,959.81 70°21'9.087 N 149°0'34.892 W 9,331.06 81.26 112.16 8,778.12 -391.56 1,897.19 5,979,493.50 621,987.36 70°21'8.977 N 149°0'34.092 W 9,360.88 89.63 114.33 8,780.49 -403.28 1,924.48 5,979,482.22 622,014.83 70°21'8.862 N 149°0'33.295 W 9,390.87 93.91 117.27 8,779.56 -416.32 1,951.46 5,979,469.61 622,042.01 70°21'8.733 N 149°0'32.506 W 9,420.94 94.70 120.99 8,777.30 -430.91 1,977.64 5,979,455.44 622,068.43 70°21'8.590 N 149°0'31.741 W 9,450.96 96.09 125.23 8,774.48 -447.24 2,002.67 5,979,439.53 622,093.72 70°21'8.429 N 149°0'31.010 W 9,479.71 98.13 130.30 8,770.92 -464.70 2,025.22 5,979,422.43 622,116.54 70°21'8.257 N 149°0'30.351 W 9,509.86 98.44 134.95 8,766.57 -484.90 2,047.17 5,979,402.59 622,138.80 70°21'8.059 N 149°0'29.710 W 9,540.82 100.90 138.98 8,761.37 -507.20 2,067.99 5,979,380.63 622,159.98 70°21'7.839 N 149°0'29.101 W 9,570.78 100.22 144.09 8,755.87 -530.25 2,086.30 5,979,357.87 622,178.66 70°21'7.612 N 149°0'28.566 W 9,600.66 98.39 147.98 8,751.04 -554.70 2,102.77 5,979,333.69 622,195.51 70°21'7.372 N 149°0'28.085 W 9,630.67 98.92 150.40 8,746.52 -580.18 2,117.97 5,979,308.46 622,211.12 70°21'7.121 N 149°0'27.641 W 9,660.67 95.45 158.35 8,742.77 -606.99 2,130.82 5,979,281.86 622,224.39 70°21'6.857 N 149°0'27.266 W 9,690.64 95.42 164.04 8,739.93 -635.22 2,140.43 5,979,253.78 622,234.46 70°21'6.580 N 149°0'26.985 W 9,720.84 93.81 170.76 8,737.49 -664.58 2,146.99 5,979,224.54 622,241.49 70°21'6.291 N 149°0'26.793 W 9,750.58 96.68 172.49 8,734.77 -693.88 2,151.31 5,979,195.32 622,246.27 70°21'6.003 N 149°0'26.668 W 9,780.62 99.35 175.44 8,730.59 -723.45 2,154.44 5,979,165.80 622,249.87 70°21'5.712 N 149°0'26.576 W 9,810.65 100.10 179.36 8,725.51 -753.02 2,155.78 5,979,136.26 622,251.69 70°21'5.421 N 149°0'26.537 W 9,840.65 99.50 184.46 8,720.40 -782.55 2,154.79 5,979,106.72 622,251.18 70°21'5.131 N 149°0'26.566 W 9,900.00 99.50 184.46 8,710.61 -840.91 2,150.24 5,979,048.30 622,247.56 70°21'4.557 N 149°0'26.700 W TD 9/14/2012 4:05:18PM Page 3 COMPASS 2003.16 Build 73 BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB S Pad S-37 S-37A Survey: MWD Survey Report - Geographic 10 September, 2012 X0 by 0 1riir HBAUER ►9« GHES Survey Report-Geographic "w«4" .gyp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-37 Project: Prudhoe Bay TVD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Site: PBS Pad MD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Well: S-37 North Reference: True Wellbore: S-37A Survey Calculation Method: Minimum Curvature Design: S-37A Database: EDM.16-ANC Prod-WH24P 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 PBS Pad,TR-12-12 Site Position: Northing: 5,980,854.54ft Latitude: 70°21'23.002 N From: Map Easting: 617,919.92ft Longitude: 149°2'32.343 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.90 ° Well S-37 API No 500292229100 Well Position +N/-S 0.00 ft Northing: 5,979,854.57 ft Latitude: 70°21'12.830 N +E/-W 0.00 ft Easting: 620,084.30 ft Longitude: 149° 1'29.543 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore S-37A API No 500292229101 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 8/17/2012 20.71 81.02 57,629 I Design S-37A Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,236.71 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 33.66 0.00 0.00 135.80 Survey Program Date: 9/4/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 372.00 9,044.00 1 :MWD-Standard(S-37) MWD MWD-Standard 9,141.00 9,236.71 MWD(S-37APB1) MWD MWD-Standard 9,255.00 11,583.00 MWD(S-37A) MWD MWD-Standard 9/10/2012 2:54:12PM Page 2 COMPASS 2003.16 Build 73 BAKER HUGHES Survey Report-Geographic op INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-37 Project: Prudhoe Bay TVD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Site: PBS Pad MD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Well: S-37 North Reference: True Wellbore: S-37A Survey Calculation Method: Minimum Curvature Design: S-37A Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,236.71 54.53 113.60 8,742.99 -357.56 1,817.50 5,979,526.21 621,907.14 70°21'9.311 N 149°0'36.421 W TIP 9,255.00 59.74 113.60 8,752.91 -363.71 1,831.57 5,979,520.29 621,921.31 70°21'9.251 N 149°0'36.010 W KOP 9,285.55 59.46 125.84 8,768.41 -376.74 1,854.39 5,979,507.63 621,944.34 70°21'9.123 N 149°0'35.343 W 9,317.75 68.17 130.82 8,782.61 -394.67 1,877.00 5,979,490.07 621,967.22 70°21'8.946 N 149°0'34.683 W 9,346.94 77.21 135.24 8,791.29 -413.68 1,897.32 5,979,471.39 621,987.85 70°21'8.759 N 149°0'34.089 W 9,377.18 86.62 140.15 8,795.55 -435.80 1,917.44 5,979,449.59 622,008.31 70°21'8.542 N 149°0'33.501 W 9,407.97 88.83 144.72 8,796.77 -460.18 1,936.19 5,979,425.52 622,027.45 70°21'8.302 N 149°0'32.953 W 9,437.43 91.17 149.20 8,796.77 -484.87 1,952.24 5,979,401.09 622,043.90 70°21'8.059 N 149°0'32.484 W 9,467.91 91.04 152.70 8,796.18 -511.50 1,967.04 5,979,374.70 622,059.12 70°21'7.797 N 149°0'32.052 W 9,497.15 90.21 157.39 8,795.86 -538.00 1,979.37 5,979,348.40 622,071.87 70°21'7.536 N 149°0'31.692 W 9,532.05 89.72 160.37 8,795.88 -570.56 1,991.94 5,979,316.06 622,084.97 70°21'7.216 N 149°0'31.324 W 9,557.17 88.22 161.07 8,796.33 -594.26 2,000.24 5,979,292.49 622,093.64 70°21'6.983 N 149°0'31.082 W 9,588.38 88.98 156.83 8,797.10 -623.37 2,011.44 5,979,263.57 622,105.30 70°21'6.697 N 149°0'30.755 W 9,616.99 90.00 152.80 8,797.35 -649.26 2,023.61 5,979,237.88 622,117.89 70°21'6.442 N 149°0'30.399 W 9,646.72 91.63 149.07 8,796.93 -675.24 2,038.05 5,979,212.14 622,132.74 70°21'6.187 N 149°0'29.978 W 9,687.21 90.18 152.74 8,796.29 -710.60 2,057.73 5,979,177.09 622,152.98 70°21'5.839 N 149°0'29.403 W 9,706.88 91.90 154.46 8,795.93 -728.22 2,066.48 5,979,159.62 622,162.01 70°21'5.665 N 149°0'29.147 W 9,737.08 93.16 158.57 8,794.60 -755.88 2,078.50 5,979,132.16 622,174.47 70°21'5.393 N 149°0'28.796 W 9,766.76 91.84 161.95 8,793.30 -783.79 2,088.51 5,979,104.42 622,184.93 70°21'5.119 N 149°0'28.504 W 9,796.97 90.15 166.51 8,792.78 -812.85 2,096.72 5,979,075.50 622,193.60 70°21'4.833 N 149°0'28.264 W 9,827.09 91.53 170.03 8,792.34 -842.33 2,102.84 5,979,046.12 622,200.19 70°21'4.543 N 149°0'28.085 W 9,857.01 94.65 169.41 8,790.72 -871.72 2,108.17 5,979,016.82 622,205.99 70°21'4.254 N 149°0'27.930 W 9,891.17 98.81 171.19 8,786.72 -905.15 2,113.89 5,978,983.49 622,212.24 70°21'3.925 N 149°0'27.763 W 9,917.23 100.90 173.20 8,782.26 -930.59 2,117.37 5,978,958.11 622,216.14 70°21'3.675 N 149°0'27.661 W 9,947.15 103.57 175.32 8,775.92 -959.68 2,120.30 5,978,929.08 622,219.53 70°21'3.389 N 149°0'27.576 W 9,979.35 104.17 176.76 8,768.20 -990.86 2,122.46 5,978,897.93 622,222.19 70°21'3.082 N 149°0'27.513 W 10,006.83 106.90 176.00 8,760.84 -1,017.28 2,124.13 5,978,871.54 622,224.28 70°21'2.822 N 149°0'27.465 W 10,036.86 109.70 176.98 8,751.41 -1,045.74 2,125.88 5,978,843.12 622,226.49 70°21'2.542 N 149°0'27.414 W 10,066.80 108.93 181.76 8,741.51 -1,073.98 2,126.18 5,978,814.89 622,227.25 70°21'2.265 N 149°0'27.405 W 10,097.89 109.64 187.00 8,731.23 -1,103.23 2,123.95 5,978,785.61 622,225.48 70°21'1.977 N 149°0'27.471 W 10,126.75 108.81 189.88 8,721.73 -1,130.18 2,119.95 5,978,758.61 622,221.91 70°21'1.712 N 149°0'27.588 W 10,156.21 108.39 193.97 8,712.33 -1,157.49 2,114.18 5,978,731.21 622,216.58 70°21'1.443 N 149°0'27.757 W 10,188.49 106.39 193.92 8,702.68 -1,187.39 2,106.75 5,978,701.20 622,209.64 70°21'1.149 N 149°0'27.974 W 10,217.25 104.32 192.71 8,695.06 -1,214.37 2,100.37 5,978,674.12 622,203.69 70°21'0.884 N 149°0'28.161 W 10,250.89 101.03 194.77 8,687.68 -1,246.25 2,092.57 5,978,642.12 622,196.40 70°21'0.571 N 149°0'28.389 W 10,277.26 98.55 195.72 8,683.20 -1,271.32 2,085.74 5,978,616.95 622,189.97 70°21'0.324 N 149°0'28.589 W 10,312.01 95.16 196.18 8,679.05 -1,304.48 2,076.26 5,978,583.64 622,181.03 70°20'59.998 N 149°0'28.866 W 10,354.12 91.32 196.00 8,676.67 -1,344.87 2,064.61 5,978,543.07 622,170.03 70°20'59.601 N 149°0'29.207 W 10,384.15 90.52 195.27 8,676.19 -1,373.79 2,056.52 5,978,514.03 622,162.40 70°20'59.316 N 149°0'29.443 W 10,414.02 90.71 191.21 8,675.87 -1,402.86 2,049.68 5,978,484.86 622,156.03 70°20'59.030 N 149°0'29.644 W 10,444.02 91.01 187.07 8,675.42 -1,432.46 2,044.91 5,978,455.18 622,151.74 70°20'58.739 N 149°0'29.783 W 10,474.15 91.11 182.35 8,674.86 -1,462.48 2,042.44 5,978,425.13 622,149.75 70°20'58.444 N 149°0'29.856 W 10,505.57 91.29 177.52 8,674.20 -1,493.88 2,042.48 5,978,393.74 622,150.29 70°20'58.135 N 149°0'29.855 W 10,534.19 92.27 172.99 8,673.31 -1,522.38 2,044.84 5,978,365.28 622,153.11 70°20'57.855 N 149°0'29.786 W 10,564.22 92.37 168.56 8,672.10 -1,551.99 2,049.65 5,978,335.75 622,158.39 70°20'57.564 N 149°0'29.646 W 10,594.36 91.84 164.27 8,670.99 -1,581.26 2,056.72 5,978,306.60 622,165.93 70°20'57.276 N 149°0'29.439 W 10,623.44 91.26 159.82 8,670.20 -1,608.91 2,065.68 5,978,279.11 622,175.33 70°20'57.004 N 149°0'29.177 W 10,650.34 90.37 155.86 8,669.82 -1,633.82 2,075.83 5,978,254.37 622,185.87 70°20'56.759 N 149°0'28.881 W 10,680.25 90.46 152.28 8,669.60 -1,660.71 2,088.90 5,978,227.69 622,199.38 70°20'56.494 N 149°0'28.499 W 10,710.38 90.92 148.38 8,669.24 -1,686.88 2,103.81 5,978,201.76 622,214.70 70°20'56.237 N 149°0'28.064 W 10,740.37 92.70 151.64 8,668.29 -1,712.84 2,118.79 5,978,176.05 622,230.10 70°20'55.982 N 149°0'27.626 W 10,770.34 93.01 154.97 8,666.80 -1,739.58 2,132.24 5,978,149.53 622,243.97 70°20'55.719 N 149°0'27.234 W 10,802.22 92.09 160.20 8,665.38 -1,769.01 2,144.38 5,978,120.30 622,256.58 70°20'55.429 N 149°0'26.879 W 9/10/2012 2:54:12PM Page 3 COMPASS 2003.16 Build 73 /Hill BAKER 00 HUGHES Survey Report-Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-37 Project: Prudhoe Bay TVD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Site: PB S Pad MD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drillir Well: S-37 North Reference: True Wellbore: S-37A Survey Calculation Method: Minimum Curvature Design: S-37A Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,830.41 91.60 162.78 8,664.47 -1,795.72 2,153.32 5,978,093.74 622,265.95 70°20'55.166 N 149°0'26.618 W 10,860.44 90.98 166.35 8,663.80 -1,824.66 2,161.31 5,978,064.94 622,274.40 70°20'54.882 N 149°0'26.385 W 10,890.40 90.92 170.78 8,663.30 -1,854.01 2,167.25 5,978,035.68 622,280.80 70°20'54.593 N 149°0'26.212 W 10,920.40 90.95 174.91 8,662.81 -1,883.77 2,170.98 5,978,005.99 622,285.01 70°20'54.300 N 149°0'26.103 W 10,950.48 91.48 180.16 8,662.17 -1,913.80 2,172.28 5,977,975.99 622,286.79 70°20'54.005 N 149°0'26.065 W 10,980.38 89.42 177.56 8,661.94 -1,943.69 2,172.87 5,977,946.11 622,287.86 70°20'53.711 N 149°0'26.048 W 11,010.40 88.89 173.07 8,662.38 -1,973.60 2,175.32 5,977,916.25 622,290.79 70°20'53.417 N 149°0'25.977 W 11,040.40 89.63 169.14 8,662.77 -2,003.23 2,179.96 5,977,886.70 622,295.90 70°20'53.125 N 149°0'25.841 W 11,070.46 90.49 165.04 8,662.73 -2,032.53 2,186.68 5,977,857.52 622,303.09 70°20'52.837 N 149°0'25.645 W 11,100.45 90.55 161.19 8,662.46 -2,061.22 2,195.38 5,977,828.98 622,312.25 70°20'52.555 N 149°0'25.391 W 11,130.34 91.07 157.45 8,662.04 -2,089.17 2,205.94 5,977,801.19 622,323.25 70°20'52.280 N 149°0'25.083 W 11,160.65 90.68 152.83 8,661.58 -2,116.66 2,218.67 5,977,773.91 622,336.43 70°20'52.010 N 149°0'24.711 W 11,190.58 90.77 149.10 8,661.20 -2,142.83 2,233.20 5,977,747.99 622,351.37 70°20'51.752 N 149°0'24.287 W 11,220.68 92.40 144.72 8,660.37 -2,168.03 2,249.62 5,977,723.06 622,368.19 70°20'51.505 N 149°0'23.807 W 11,249.24 92.85 140.18 8,659.06 -2,190.64 2,267.00 5,977,700.73 622,385.93 70°20'51.282 N 149°0'23.299 W 11,280.61 90.80 135.99 8,658.06 -2,213.97 2,287.94 5,977,677.74 622,407.24 70°20'51.053 N 149°0'22.688 W 11,309.68 89.75 135.55 8,657.92 -2,234.79 2,308.22 5,977,657.24 622,427.85 70°20'50.848 N 149°0'22.096 W 11,340.69 88.37 140.05 8,658.43 -2,257.76 2,329.04 5,977,634.62 622,449.03 70°20'50.622 N 149°0'21.487 W' 11,370.99 89.32 145.12 8,659.04 -2,281.81 2,347.44 5,977,610.87 622,467.81 70°20'50.385 N 149°0'20.950 W 11,401.00 90.06 150.84 8,659.20 -2,307.24 2,363.34 5,977,585.69 622,484.12 70°20'50.135 N 149°0'20.485 W 11,430.69 90.25 155.00 8,659.12 -2,333.67 2,376.86 5,977,559.49 622,498.05 70°20'49.875 N 149°0'20.091 W 11,463.34 91.11 159.23 8,658.73 -2,363.74 2,389.55 5,977,529.62 622,511.23 70°20'49.579 N 149°0'19.720 W 11,494.55 91.63 164.85 8,657.99 -2,393.41 2,399.17 5,977,500.12 622,521.32 70°20'49.287 N 149°0'19.439 W 11,520.55 91.10 169.71 8,657.37 -2,418.76 2,404.89 5,977,474.87 622,527.44 70°20'49.038 N 149°0'19.272 W 11,550.44 90.95 174.51 8,656.83 -2,448.35 2,408.99 5,977,445.34 622,532.02 70°20'48.747 N 149°0'19.153 W 11,583.00 90.95 174.51 8,656.29 -2,480.76 2,412.10 5,977,413.00 622,535.65 70°20'48.428 N 149°0'19.062 W TD-2 7/8" 9/10/2012 2:54:12PM Page 4 COMPASS 2003.16 Build 73 TREE= 4-1/16"5M CIW SA NOTES:WELL ANGLE>70 @ 9325'***4- VVE-LHEAD= 11"5M FMC PJC C DRAFT S-3 7 A 1/2"CHROME TBG&5-1/2"LNR*** ACTUATOR= BAKER C r ;J�✓ IVITTAL KB.BEV= 69.3 BF.BEV= 32' KOP= 5000' 20"CONDUCTOR 110' Max Angle= 110°@ 10098' 2228' -4-112"OTIS HXO SSSV NP,0=3.813" 91.5#,H-40, 0 Datum ND= =19.124" Datum TVD= 8800'SS' [ GAS LIFT MANDRELS 10-3/4"CSG,45.5#,NT-80 BTC,D=9.953" H 2923' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3018 3009 1 CA DOME BK r 16 10/21112 5 5104 5095 4 CA SO BK r 20 10/18/12 4 6713 6624 29 CA DMY BK r 16 02/03112 3 7885 7612 33 CA DMY BK r 16 02/03/12 I 2 8333 7987 33 CA DMY BK r 0 01/24/10 Minimum ID = 1.91" @ 10303' 1 8438 8075 33 CA DMY BK r 24 X02/03/12 2.70" DEPLOYMENT SLEEVE ', 8777' 14-1/2"PKR SINS NP,ID=3813" M8837' {7-5/8 X 4-1/2" BKR S-3 FCR,ID=3.875" v 4-1/2"BKR BK LTP,ID=2.38"(10/17/12) — 8863' , 8869' —3.70"DEPLOY SLV,ID=3.00" F 8870' -4-112"FKR SWS NP,ID=3.813" 8876' —13.70"BKR HGR SUB,ID=2.813" F. 8890' —4-112"PKR SWN NIP, F MILLED TO 3.80"(07/29/12) F8894' 7-5/8"X 5-1/2"TIEBACK SLV, TOP OF 5-1/2"LNR —18894' — K: " / W 1 ISOLATION PKR,ID=? 4-1/2"TBG,12.6#,13CR NSCT, —1 8902' Z F ` 8902' H4-1/2"WLEG,D=3.958" 0152 bpf,®=3.958" • \ 8898' H{ 13MD TT LOGGED 0?I08/93 8806' —17-5/8"X 5-1/2"FLEX LOCK HGR,ID"? 7-5/8"CSG,29.7#,NT-95-HS NSCC,ID=6.875"' ---19108' 4 , 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf,ID=2.992" —19114' 9114' -3-112"X 3-3/16"XO,ID=2.786 � 5-112"BKR WHPSTOCK(07/29/12) H 9145' 5-1/2"LNR, 17#,13CR FL4S,. — —9151 0232 bpf,ID=4.892" MILLOUT WINDOW(S-37A)9141'-9151' 3-1/4"LNR,6.6#,L-80 TCII,.0079 bpf,0=2.850" - 10354' 10303' —12.70"BKR DEPLOY SLV,D=1.91 10354' 1\ 10303' —BKR ALlAv1IF'JMFOR IEUBULLNOSE PERFORATION SUMMARY 10354' I REF LOG: I GUIDE SHOE,MILLED TO 2.74" ANGLE AT TOP PERF:°@' I Note:Fifer to Production DB for historical perf data I I SIZE SPF KTERVAL Opn/Sqz DATE I 2-3/8" SLOT 10305-11561 O 08/31/12 ' I I I _ I PBTD H 11561' I-- 2-3/8"LNR,4.70#,L-80 STL, .0039 bpf, ID=1.995"—{ 11583' , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/06/92 N28E ;INITIAL COMPLETION 11/07/12 PJC LTP CORRECTION WELL: S-37A 09/02/12 NORDIC 2 CTD SIDETRACK(S-37A) PERMIT No:12120920 09/06/12 PJC DRLG 110 CORRECTION API No: 50-029-22291-01 09/16/12 PJC DRLG DRAFT CORRECTONS 1 1 SEC 35,T12N,T12E, 1648'FNL& 1922'FWL 10/29/12 SWC/JMD'SET BKR KB LTP(10/17/12) 1 10/29/12 SWC/JMD GLV C/O(10/18-21/12) l BP Exploration(Alaska) 410 -Mut. 2-I Z c'zo Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, August 14, 2012 7:52 PM To: Crisp, John H (DOA) ��` (6.116((z/ Cc: DOA AOGCC Prudhoe Bay Subject: Re: Nordic 2 well control event You did right. "Crisp, John H (DOA)" <john.crisp©alaska.gov> wrote: Just got a page from Nordic 2 asking for a call back about a question they had for recent well control event on PBU S-37. They were out of the hole for some reason &did not test the well control equipment that was used to control well & circulate the kick out of the hole.They asked me if they needed to POOH &test or could they test after drilling this section of the hole.This confused me because the regulations are clear& I had no idea if they were requesting variance to keep drilling or what. I know BP will not request variance so I told the WSL Tom that if he wanted to be in compliance he needed to stop drilling & POOH to test equipment used for well control.This CTD is different due to the equipment used for well control is what they normally use for surface circulating equipment except for the choke HCR. Their BOP usage report on_the 13`h states they do not have to test anything.The report for the 14th states they have to test HCR & striper. I think they had a crew change &they fumbled on the handoff. I don't know how big a deal BP will make out of this but since they did not use stack components&they have many backups for well control, in my opinion it did not jeopardize well control.They were out of compliance so they stopped operations to POOH &get in compliance with HCR &Stripper test. I told them I would not hold them to 24 hour notice of equipment test. 1 Pact P� z'1z (y, R`egg, James B (DOA) From: Sarber, Greg J [SarberJG@BP.com] tv Sent: Tuesday, August 14, 2012 8:25 AM �� t To: Regg, James B (DOA) Cc: Willingham, James M; Daniel, Ryan; McMullen, John C; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); DOA AOGCC Prudhoe Bay Subject: BOP Usage on Nordic 2 -Well S-37A Attachments: Shublik Phenomenon RP.doc; Nordic 2 BOP Usage Report to AOGCC 8-13-12.docm; Nordic 2 BOP Usage Report to AOGCC 8-14-12.docm Dear Mr. Regg, There have been 2 minor BOP usage events on the CTD riq Nordic 2 within the last 24 hours. These events occured while drilling a sidetrack in the Shublik formation in the GPB field. For Event#1, a minor amount of gas was encountered with no pit gain. The CTD rig circulated the gas out of the hole and resumed operations. For Event#2, was again encountered, there was no pit gain, but the well was shut in. The initial SI pressure was 500 psi on the production tubing by coiled tubing annulus. This pressure was attribute to trapped pressure on the wellhead. The well was shut in prior to stopping rig pumps, and the pressure was slowly was bleeding down after SI. The WHP was at 250 psi when the circulation was begun. The well was circulated to remove the gas from the wellbore. After circulating the well following Event#2, a flow check was made and there was no sign of flow. The mud was not weighted up for either of these events which is consistent with BP's recommended practice when drilling in the Shublik formation. The plan forward on Nordic 2 is to complete drilling the intermediate section of hole on well S-37A with the current mud weight of 8.7 ppg. The intermediate section of hole on this well is a J shaped wellbore that kicks off from the parent well in the Sag river sand, drills down into the Shublik, inverts, drills up thru the Shublik, and lands in the Sag River sand. After landing the intermediate section of hole, the rig will run and cement an intermediate liner string. Attached to this document you will find BOP usage forms for the 2 events as well as BP's Recommended Practice for drilling in the Shublik formation. Please contact me if you should need additional information. Sincerely, Greg Sarber, PE Greg Sarber Operations Superintendent RWO/CTD +1 (907)659-5329(Office-slope) +1 (907)242-8000(Cell Phone) Harmony 2157 Alternate: Rich Burnett 1 • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name:Greg Sarber Wellsite Leader Name: Gary Goodrich Contact Number: 659-5329 Contact Number: 659-4393/4543 Traction Number: n/a Well Location/Name & Rig Name:Greater Prudhoe Bay S-37A / Nordic Rig 2 Permit To Drill (PTD) Number:212-092 - Date and Time of Incident: 1100 hrs 8-13-12 Original Scope of Work: CTD sidetrack of S-37. Operational Description Leading up to Well Control Event: Drilling ahead in build section after a short trip. BOPE Used and Reason: Closed HCR as a precaution after observing traces of gas in mud returns Is a BOPE Test Required after use ( Yes / No): If no, why? No. The event is not considered well control and the HCR was used as a precaution only. - No rams or annular were closed. No pit gain was observed and no well head pressure indicated. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Circulate bottoms up and flow check. Drill ahead in build section. Additional Comments: None. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayalaska.gov Email CC List Well Integrity Team Leader: Ryan Daniel HSE Advisor: Jeff Kilfoyle Engineering Team Leader: Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager: Steve Rossberg Wells Intervention Manager: Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC Rev 1 September 1, 2010 hol Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: Ryan Cadenhead Contact Number: 659-5329 Contact Number: 659-4393/4543 Traction Number: 2012-IR-4205917 Well Location/Name & Rig Name: Greater Prudhoe Bay S-37A / Nordic Rig 2 Permit To Drill (PTD) Number: 212-092 Date and Time of Incident: 00:45 hrs 8-14-12 Original Scope of Work: CTD sidetrack of S-37. Operational Description Leading up to Well Control Event: Circulating on bottom while preparing to resume drilling build section after trip for new BHA. There was no flow or pit gain, but gas cut mud observed in the pits. BOPE Used and Reason: Closed HCR after observing gas cut mud and LEL alarm at shaker. Is a BOPE Test Required after use ( Yes / No): If no, why? Yee After shutting in the well at the HCR, 500 psi of was trapped on the wellbore. While making telephone notifications, the WHP bled down to 250 psi. The well was circulated holding 300 psi with the choke. After 2 bottoms up circulations, the well was flow checked. No gas or flow was observed. The Chokeline HCR and Coiled Tubing Injector packoff will be tested when at surface during next trip. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Circulate bottoms up and flow check. Drill ahead in build section. Additional Comments: None. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayalaska.gov Email CC List Well Integrity Team Leader: Ryan Daniel HSE Advisor: Jeff Kilfoyle Engineering Team Leader: Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager: Steve Rossberg BOPE Usage Report for AOGCC Rev 1 September 1, 2010 Wells Intervention Manager: Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC Rev 1 September 1, 2010 FP-Ax. s-374 PhS zt 2,ogzo RP:The Shublik Phenomenon Page 1 of 13 Recommended Practice: The Shublik Phenomenon Authority: NSU ADW Drilling Team Custodian: NSU ADW Drilling Engineer Lead Scope: ACT, GPB, CTD Document ADW Document Control Administrator: Specialist Issue Date: August 12, 2009 Issuing Dept: ADW Revision Date: August 12, 2009 Control Tier: 4 Next Review August 12, 2013 Date: ngamil INTELLECTUAL PROPERTY AND CONFIDENTIALITY NOTICE ©2009 BP America Inc. (for all US copyright notices)All rights reserved. This document contains confidential information,which is the exclusive and proprietary property of BP America Inc. and affiliates. In whole or part,this document or its attachments MAY NOT be reproduced by any means,disclosed or used for any purpose without the express written permission of BP America Inc. or affiliates. 1.0 Purpose This document details the Hydrocarbon Influx While Drilling the Shublik Formation. This document is designed as a recommendation to be applied when dealing with initial signs of gas cut mud from the Shublik.Any influx of hydrocarbons into the well should be treated initially as a kick and therefore,the well should be shut in and evaluated accordingly.The Shublik formation consists of varying degrees of shale,siltstone, limestone and sandstone. The Shublik in general is a hard,very brittle,very low permeable formation,consequently it is extremely hard to fracture unless it is weakened.Once fractured or weakened through faulting,the fractures will continue to grow and frac out due to the brittleness of the formation. Localized porous lenses or intervals within the Shublik have the potential to contain pockets of hydrocarbons which can enter the wellbore through existing fault related fractures of drilling induced fractures. Hydrocarbon content depends on where you are in the field and where the gas-oil contact is within the structure. The Shublik has an extended history of lost circulation throughout the field.The potential for loses is increased when penetrating the formation at higher angles. This risk is exacerbated when drilling across or near major faults and or their rubble zones within the Shublik due to the inherent increase of the complexity within the area. These rubble fault zones are also much weaker due to the tectonic stresses,thus making fracture induction and or linking more probable.According to the"1999 PBU Fault/Lost Circulation Study"faults trending in the NW/SE direction tend to be more open and thus more conductive then faults trending in other directions. 2.0 Definitions Drainback is the volume of mud(in barrels)that will flow from the settling and mud processing pits into the active pits after the mud pump is turned off. Drainback will occur whether the formation is ballooning or not. It is a function of the layout of the mud processing system. Flowback is the volume of mud (in barrels) that flows out of the top of the well when the pump is turned off. 3.0 General Requirements BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12, 2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date: 8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ • a RP: The Shublik Phenomenon Page 2 of 13 Prior to drilling through the Shublik formation,all necessary risks must be mitigated to achieve a successful outcome. 4.0 Key Responsibilities Drilling Engineer: Ensure that WSL and Rig Crew are aware of the Shublik phenomenon when drilling through the Shublik and understand the issues surrounding it. Well Site leader: Convey to rig crew the possibility of Shublik gas and procedure for controlling it. 5.0 Procedure 5.1 Problem Well History: Z-38 and V-03 have experienced similar problems when crossing a fault prior to drilling within the Shublik. On both wells the intermediate casing string was set across the fault prior to drilling out into the Shublik. The separation from the fault at the landing point varied between the wells.There does not seem to be a clear correlation between horizontal fault separation and the problems encountered.The size of the fault rubble zone will vary depending on the formation strength and the size of the throw on the fault. In either case,both wells experienced an influx of hydrocarbons within this interval.Z-38 circulated up more oil then V-03,which could be a result of the TVD of the GOC.This phenomenon does not seem to be typical breathing for a couple reasons: 1)The Shublik is not a plastic shale, it is a more brittle,hard shale,thus it is more likely to take fluid and not give it back when the pressure is reduced. 2)When a well breathes,it normally gives back the same fluids it gets, i.e. drilling fluid,not hydrocarbons. One theory that could explain this phenomenon is that drilling through the Shublik within a rubblized zone increases the likelihood of induced fractures becoming big and long enough to intersect the localized porous,permeable intervals containing hydrocarbons.Once these intervals are exposed dynamically,the added ECD pressure from drilling charges the hydrocarbons contained within these lenses. Once the pumps are shut down,this trapped energy is then returned to the well through the expulsion of the more mobile gas and or oil contained within the lens. Increasing the MW to combat this phenomenon only increases the reach of the already induced fractures, thus exposing and charging up more hydrocarbons,which will come into the wellbore once circulation is reduced and or stopped.Therefore having to raise the mud weight to kill the well,could cause more fracturing and or additional over pressure to the Shublik and other formations,causing a snowball effect of having to cure one,then fix the other. Based on lessons learned from Z-38 and V-03, it is possible to evacuate the hydrocarbons contained within the connected lens,given enough time.Z-38 was able to finish drilling the production interval after decreasing the MW to seawater.The strongest correlation between Z- 38 and V-03 is the presence of a nearby fault and or rubble zone.This may be one of the major contributing factors to this phenomenon,as L-01 did not cross a fault and did not have this problem.A review of the data from well V-03, in summary,showed loses of 15-30 bph occurring when drilling just above the base of the Shublik B. LCM(Barafiber)was added,reducing loses to 10 bph,when continuing to drill ahead,an influx of gas was introduced to the well bore.Thus,a hydrocarbon influx was taken,after some loses occurred while drilling in the Shublik. Prior to drilling in the Shublik,have a discussion with Geology to confirm that there is no potential to see overpressure in this interval from injection.This knowledge will help to ascertain if this is a well control incident or this Shublik phenomenon.The normal pressure gradient for the Shublik in the L-02 area is a 9.0 ppg EMW. It is less in most areas due to production off take. The frac gradient of the Shublik is not known due to conducting the LOT's and FIT's at or just above the Sag prior to drilling the Shublik. BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date:8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ RP:The Shublik Phenomenon Page 3 of 13 5.2 Operational Recommendations Prior to drilling into the reservoir,establish good ECD baseline data and monitor ECD's while drilling ahead. 1. If an influx is taken,and this phenomenon is occurring,the shut-in equivalent pressure recorded should be similar to the drilling ECD's prior to taking the influx. 2.This data could provide learning's for operational practice adjustments on future wells. Prior to drilling in the reservoir it is recommended to ensure that a heightened awareness of accurate fluids tracking is incorporated on the rig. Losses within the Shublik are linked to the beginning stages of initiating this phenomenon. This heightened awareness could help lessen its severity. 1. Ensure the mud system is a"closed system"while drilling the Shublik interval. a.No dilutions b.No product additions 2. Know where every barrel is going. a.Zero out the gain/loss monitors b.Utilize the trip tank if possible to monitor returns 3.If losses occur while drilling the Shublik,shut down and monitor the well. a. If the well is static or losses continue,evaluate severity of the losses,and if manageable,drill ahead while preparing LCM treatments as needed to treat losses. While drilling ahead,monitor returns for gas/oil cut mud.This may be a result of formation fluids and mud swapping within the Shublik fractures and entering the wellbore.If seen,be prepared to shutdown and evaluate/shut-in the well as required. b. If the well exhibits any signs of flow after shutting down(breathing back mud and/or formation fluids which have swapped with the mud),plan to shut-in the well and proceed as listed below. 4. If the well exhibits any well control warning sign while drilling the Shublik,follow standard well control procedures for shutting-in the well. Contact the Drilling Manager and ODE;throughout this operation continual communication with all team members will be critical to effectively talk through and choose the path forward. Each well has acted slightly different and will need to be evaluated on an individual and ongoing basis. a. Record SICP, SIDPP and monitor for build-up b.Record Pit Gain,if any c. Once pressures have stabilized,the base plan is to utilize the"Drillers Method"of well control to circulate out the influx.Attempt to minimize any additional losses(or charging of the formation) during this circulation by limiting additional back-pressure on the reservoir(above and beyond what is required to keep a value equal to the final stabilized shut-in bottom hole pressure). d. Once the initial influx is circulated out,shut-in and monitor the well.The"Drillers Method" may need to be done several times at reduced effective bottom hole pressures in order to bleed down and expel the charged formation fluids. 6.0 Key Documents/Tools/References This section should include, as applicable, references to other documents/tools that interface with this procedure. The references can be modified administratively by the Custodian without creating a new revision to the document. BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number:UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date:8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ RP:The Shublik Phenomenon Page 4 of 13 Revision Log Revision Date Authority Custodian Revision Details August 12, 2009 GPB Team Chris Original Issue Lead Tzvetcoff June 29, 2010 Andy Kirk C. Tzvetcoff Add BP Confidentiality Statement (or, see attached e-mail ❑) Approving Authority signature Date BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12, 2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date:8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ S RP:The Shublik Phenomenon Page 5 of 13 Appendix 1 Information on the Shublik Phenomenon;the following Lessons Learned were gathered from the WEPF: http://epforums.bpweb.bp.com/wepf/Eclips.asp?PT=Question&Category=3&Subject=18&Question=11546 Appendix 2: DS Z-38 Shublik Well Control Incident I'd like to share a recent problem we've had in PBU and would be interested if anyone has had similar problems with a better solution. (Better grab a coffee because this will take a while to read !). We've just finished controlling a well control incident that occurred just below our 7"casing shoe set in the Sag sand on PBU well Z38. The well encountered high pressure oil/gas, in the Shublik carbonate immediately below the low pressure(upto 8.4ppg), Sag sand/gas zone. The well exhibited two irregular phenomena that we have experienced in several regions of the North Slope which complicated the kill and inhibited forward progress. The first was "breathing" from the highly permeable Sag due to the high mud weights required to control the Shublik.This results in the sand taking fluid during the increased ECD's from circulating kill fluid and "breathing" it back when the pump is shut off.(SPE papers "Anatomy of ballooning borehole using PWD, Mechanisms of shallow waterflows&drilling practices for intervention are good references).The problem is that you don't know whether its a well kick or"breathing" .the general way we tackle it is to circulate out using the drillers method and ascertain the influx properties. Once we know its"breathing"we VERY carefully drill ahead monitoring loss gains and circulating up suspicious discrepancies. The second phenomenon is fracture propagation and separator effect inversion from the Shublik. We first experienced this phenomenon on a long horizontal X pad well. Basically on X pad drilling with 8.8ppg mud,extremely high continuous levels of gas cut mud were experienced and the well was indicating(not too subtly either),that it was at balance and required more MW(0.5ppg). Increasing the MW resolved the problem for 3-400ft when similar levels of gas cutting again stopped operations,MW increased by 0.5ppg and after 3-400ft same problem. This continued until we got to l 1ppg mud,with lots of head scratching all round until "the penny then dropped" on separator effect and we reduced the MW by 0.5ppg and the gas dropped from 70percent to 40 percent,continued dropping and circulating MW until we got back to 9.5ppg and background gas.Then successfully drilled ahead and ran the liner.(Don't try this without a LOT of forethought,consideration and consultation). Simply put we think that the mechanism may be that the extra ECD/MW opens up and increases connectivity to more fractures and you have a separator effect between the mud and the gas that liberates gas into the horizontal well bore(these are upto 5,000ft long). So,getting back to Z-38 and the combined problem,to cut a long story short(and this was three weeks worth of scratching ahead),we finally managed to get a balance between the two problems,got out the hole drilled up the rest of the Shublik with 10.5 MW and ran a DST and bled down the high pressure Shublik oil lens in 24 hrs prior to drilling ahead with our current 8.8 MW needed for the losses we expect when we cross a fault in the horizontal section. During the DST we ran into the problem outlined in the attached note,which was the reason I put pen to paper before I got carried away with the story. BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date: 8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ (1111 RP: The Shublik Phenomenon Page 6 of 13 Last week,on Z-38,we ran a DST on 4-1/2"Mod-Butt. When running the DST,there were two downhole ball valves in the string; one used as the primary DST valve and one as a circulating valve. Prior to pulling the DST,we ran a downhole pressure bomb on slickline.Upon completion of the slickline operations,we attempted to close the LPRN(tester)valve but could not close the valve thus leaving us open to bottomhole pressure. In addition,the upper(OMNI)valve was also stuck in the open position.Fortunately,the well was depleted and we were able to trip out of the hole with no influx or loss. Upon breaking the tools out and inspecting the valves for the cause of closing failure, it was found that the LPRN(tester)valve was plugged full of slivers of teflon seal ring material which resulted in the failure. The question is how would the seal ring material extrude from the seals of the joints? We were extremely fortunate to have depleted the zone at the time the DST was completed.Had the zone still had pressure,we could have been facing a very serious pressure control problem with very limited choices for adequately circulating the well. I doubt if this is an isolated incident of seal ring material ending up extruded into the bore of the tubing and I wonder how often this plugs gas lift mandrels,surface facilities,etc during production operations or if there have been other instances of surface or subsurface equipment that has had problems as a result of this type of failure.The seriousness of this incident certainly indicates that the use of or procedures for running mod-but connections should be carefully reviewed to avoid similar or additional problems. 1.1)Vietnam Experience We ended up drilling those wells subsequently using a"static underbalanced drilling"technique which relied largely on ECD while drilling,sufficient to control influx and minimize losses.Tripping was more difficult,necessitating a heavy slug in the annulus to maintain balance.However,we managed to drill 5 wells after the blowout this way without incident. We did not have a pressure transition problem there,just connectivity through a very large carbonate structure. 1.2)Formation Taking on Fluid The issue listed in Section 1 of the Appendix regarding wellbore breathing is indeed due to the formation taking fluid when applying an ECD and giving it back when the pump is shut off. The breathing phenomenon is well documented in high pressure wells-e.g.Elf s experiences on Elgin/Franklin (SPE/IADC 29428).It can also occur when using viscous muds which possess a very high ECD relative to the static mud weight,and also in very hot wells where thermal effects caused by circulating cooler mud can trigger a loss and gain problem. The most common cause of this phenomenon is due to the creation of drilling-induced tensile fractures in high pressure zones.(In fact,from the information given,I think that induced fracturing in the Shublik may be a possible cause to be considered for the losses and gains,rather than formation inflow and production from the Sag sand). Wellbore stability calculations can anticipate the occurrence of these events. Operational procedures have also been devised to differentiate between early indications of a kick and wellbore breathing. The attachment provides guidelines used by Texaco on Erskine(this information is listed in appendix section 3). BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date:8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ RP:The Shublik Phenomenon Page 7 of 13 Appendix 3: DS18-29C Shublik Well Control Incident Rig 7ES drilled into the Shublik on 18-29C with an 8.6 ppg Flo-pro mud and noticed the well flowing when they shut-down for a connection. The SIDPP was 270 psi and SICP was 350 psi calculating out to a 3.5 bbl influx. The well was shut-in and began circulating out x3 using the driller's method. After the first circulation, SIDPP: 390 psi and SICP: 390 psi. After the second circulation: SIDPP:470 psi and SICP:470 psi. After which the rig opened up the well and monitored for 15 mins. The well flowed 5 bbls and was shut-in. SIDPP: 320 psi and SICP: 390 psi. The third circulation was done with no back pressure on choke and CBU at 3 bpm with ICP: 770 psi and FCP: 730 psi. Shut down and opened rams with slight flow from well. Decided to continue to drill ahead without weighting up while CBU at every stand and monitored for gas cut mud,pit gains and losses. No significant gas flow after drilling the Shublik formation and continued to drill ahead using the same program. Mud loggers measured a maximum of 6000 units of gas which slowly tapered off while drill the hole section. The higher gas shows would be circulated down to under 1000 units. Eventually, only small amounts, < 1000 units, of gas were seen in the returns while drilling. Well continued to flow slightly(3bbls in 55 mins) After drilling build section, the rig attempted to POOH on elevators and saw a 19 bbl pit gain and shut down and monitored well. The well flowed back 7.4 bbls while the rig monitored the well. They ran back to bottom, circulated a BU and saw 100 bbls of gas cut mud. The decision was made to pump out of hole to eliminate swabbing. The decision was made to weight up at shoe to stop well from flowing. The well had to be weighted up to 9.0 ppg to keep well from flowing. Gas shows in mud continued to slow as they drilled the hole section. The mud weight was reduced for drilling back to an 8.6 ppg. On subsequent trips the mud was weighted up to 9.0 ppg and reduced back for drilling. Eventually, the gas flow tapered off enough to make trips with a 8.6 ppg mud weight. BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date: 8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ RP:The Shublik Phenomenon Page 8 of 13 DS18-29C Shublik Well control incident 6/18/2009 Shortly after drilling out the 7"shoe track,which was top set in the Sag River formation,and drilling into the at Shublik the driller noted that the well was flowing during a connection.The well was shut in and notifications app.4:15 made. Kill sheet calculations were made and prepared for well control operations using the Drillers method. Monitor well pressures Time Casing DP Time Casing DP Time Casing DP 4:20 260 0 4:40 320 210 5:00 350 270 4:25 290 0 4:45 350 250 5:05 350 280 4:30 320 10 4:50 350 260 4:35 350 50 4:55 350 260 Circulate out gas using drillers method(First Circulation) Pre-recorded KRP=900 PSI @ 3 BPM Strokes Casing DP Strokes Casing DP Strokes Casing DP 100 270 950 2250 510 1060 4400 430 1150 150 370 1000 2300 510 1060 4450 430 1150 200 420 1030 2350 510 1060 4500 430 1150 250 430 1030 2400 510 1060 4550 440 1150 300 440 1040 2450 520 1060 4600 480 1190 350 460 1050 2500 520 1060 4650 520 1230 400 450 1040 2550 520 1060 4700 480 1200 450 450 1030 2600 510 1050 4750 450 1170 500 460 1040 2650 490 1050 4800 440 1160 550 460 1040 2700 480 1040 4850 430 1150 600 460 1040 2750 470 1040 4900 430 1150 650 470 1040 2800 470 1040 4950 430 1150 700 490 1050 2850 470 1040 5000 430 1150 750 480 1040 2900 480 1040 5050 430 1150 800 460 1030 2950 350 1100 5100 430 1150 850 460 1030 3000 390 1140 5150 430 1150 900 470 1030 3050 400 1140 5200 430 1150 950 470 1030 3100 400 1140 5250 430 1150 1000 470 1030 3150 410 1150 5300 430 1150 1050 470 1030 3200 410 1150 5350 430 1150 1100 470 1030 3250 420 1150 5400 430 1160 1150 470 1030 3300 410 1150 5450 430 1150 1200 470 1040 3350 420 1150 5500 430 1160 1250 480 1030 3400 420 1150 5550 430 1160 1300 480 1030 3450 420 1150 5600 430 1150 1350 490 1050 3500 440 1170 5650 440 1150 1400 500 1050 3550 460 1180 5700 440 1150 1450 510 1050 3600 460 1190 5750 440 1160 1500 510 1050 3650 460 1190 5800 440 1160 1550 510 1060 3700 460 1190 5850 440 1160 1600 510 1060 3750 470 1190 5900 440 1150 1650 510 1060 3800 470 1190 5950 440 1160 1700 510 1060 3850 460 1190 6000 440 1160 1750 510 1060 3900 470 1190 6050 440 1160 1800 510 1060 3950 470 1190 6100 440 1150 1850 510 1060 4000 470 1160 6150 450 1150 1900 510 1060 4050 430 1100 6200 440 1150 1950 510 1060 4100 360 1130 6250 440 1160 2000 520 1060 4150 410 1140 6300 440 1150 2050 520 1060 4200 420 1140 6350 440 1160 2100 510 1060 4250 420 1140 6400 440 1150 2150 510 1060 4300 420 1140 6450 440 1150 2200 510 1060 4350 420 1150 6500 440 1150 BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date: 8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ RP:The Shublik Phenomenon Page 9 of 13 Strokes Casing DP Strokes Casing DP Strokes Casing DP 6550 440 1150 7400 470 1170 8250 470 1170 6600 440 1150 7450 470 1170 8300 470 1170 6650 440 1150 7500 470 1170 8350 470 1170 6700 440 1150 7550 470 1170 8400 470 1170 6750 460 1160 7600 470 1170 8450 470 1170 6800 460 1170 7650 470 1170 8500 470 1170 6850 470 1170 7700 470 1170 8550 470 1170 6900 470 1180 7750 470 1170 8600 470 1170 6950 470 1180 7800 470 1180 8650 470 1170 7000 470 1170 7850 470 1170 8700 470 1170 7050 470 1170 7900 470 1170 8750 470 1170 7100 470 1170 7950 470 1170 Pumps down 7150 470 1170 8000 470 1170 7200 470 1170 8050 470 1170 7250 470 1170 8100 470 1170 7300 470 1170 8150 470 1170 7350 470 1170 8200 470 1180 Pumps down to monitor well Time Casing DP Time Casing DP 8:30 50 290 8:50 370 350 8:35 240 250 8:55 380 370 8:40 310 280 9:00 390 390 8:45 350 320 Circulate out gas using drillers method(second circulation) Pumps on at 9:05 Strokes Casing DP Strokes Casing DP Strokes Casing DP 50 400 1100 1550 320 1020 3050 320 1010 100 240 980 1600 320 1020 3100 320 1010 150 240 960 1650 320 1020 3150 320 1010 200 250 970 1700 320 1020 3200 320 1010 250 290 1010 1750 320 1020 3250 320 1010 300 310 1030 1800 320 1020 3300 320 1010 350 320 1030 1850 320 1020 3350 320 1010 400 320 1030 1900 320 1020 3400 320 1010 450 320 1030 1950 320 1020 3450 320 1010 500 320 1030 2000 320 1020 3500 320 1010 550 320 1030 2050 320 1020 3550 320 1010 600 320 1030 2100 320 1020 3600 320 1010 650 320 1030 2150 320 1020 3650 320 1010 700 320 1030 2200 320 1020 3700 320 1010 750 320 1030 2250 320 1020 3750 320 1010 800 320 1030 2300 320 1020 3800 320 1010 850 320 1030 2350 320 1020 3850 320 1010 900 320 1030 2400 320 1010 3900 320 1010 950 320 1030 2450 320 1010 3950 320 1010 1000 320 1030 2500 320 1010 4000 320 1010 1050 320 1030 2550 320 1010 4050 340 1020 1100 320 1030 2600 320 1010 4100 360 1040 1150 320 1030 2650 320 1010 4150 360 1040 1200 320 1030 2700 320 1010 4200 370 1040 1250 320 1030 2750 320 1010 4250 370 1040 1300 320 1030 2800 320 1010 4300 370 1050 1350 320 1030 2850 320 1010 4350 370 1050 1400 320 1030 2900 320 1010 4400 370 1050 1450 320 1020 2950 320 1010 4450 370 1050 1500 320 1020 3000 320 1010 4500 370 1050 BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12, 2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date: 8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ S , RP:The Shublik Phenomenon Page 10 of 13 Strokes Casing DP Strokes Casing DP Strokes Casing DP 4550 370 1050 5550 370 1050 6550 370 1050 4600 370 1050 5600 370 1050 6600 370 1040 4650 370 1050 5650 370 1050 6650 370 1050 4700 370 1050 5700 370 1050 6700 370 1050 4750 370 1050 5750 370 1050 6750 370 1040 4800 370 1050 5800 370 1050 6800 370 1040 4850 370 1040 5850 370 1050 6850 370 1050 4900 370 1050 5900 370 1050 6900 370 1050 4950 370 1050 5950 370 1050 6950 370 1050 5000 370 1050 6000 370 1050 7000 370 1040 5050 370 1040 6050 370 1050 7050 370 1040 5100 370 1050 6100 370 1050 7100 370 1040 5150 370 1050 6150 370 1040 7142 370 1040 5200 370 1040 6200 370 1050 pumps off @ 11:23 5250 370 1050 6250 370 1050 5300 370 1050 6300 370 1040 This circulation was done at 3 BPM and the 5350 370 1040 6350 370 1050 hole took 4 bbls.Starting with 35 in the 5400 370 1050 6400 370 1050 5450 370 1050 6450 370 1050 active pit and ending with 31. 5500 370 1050 6500 370 1050 Pumps down to monitor well after second circulation Time Casing DP Time Casing DP 11:23 350 620 11:40 470 470 11:25 430 550 11:45 470 470 11:30 460 480 11:50 470 470 11:35 470 470 Circulate out gas using drillers method(Third circulation thru wide open choke) Pumps on at 12:55 Strokes Casing DP Strokes Casing DP Strokes Casing DP 100 330 810 2900 30 740 5700 30 740 200 50 770 3000 30 740 5800 30 740 300 30 770 3100 30 740 5900 30 740 400 30 770 3200 30 740 6000 20 740 500 30 750 3300 30 740 6100 20 740 600 30 740 3400 30 740 6200 20 740 700 30 740 3500 30 740 6300 30 740 800 30 740 3600 30 740 6400 20 740 900 30 740 3700 30 740 6500 30 730 1000 30 740 3800 30 740 6600 30 730 1100 30 740 3900 50 740 6700 30 730 1200 30 740 4000 30 740 6800 30 730 1300 30 740 4100 30 740 6900 30 730 1400 30 740 4200 30 740 7000 30 730 1500 30 740 4300 20 740 7100 30 730 1600 30 740 4400 30 740 7200 30 730 1700 30 740 4500 30 740 7300 30 730 1800 30 740 4600 30 740 7400 20 730 1900 30 740 4700 30 740 2000 30 740 4800 20 740 2100 30 740 4900 20 740 2200 30 740 5000 30 740 2300 30 740 5100 30 740 Gained 10.5bbls.During this circulation 2400 30 750 5200 30 740 2500 30 750 5300 30 740 2600 30 750 5400 20 740 2700 30 740 5500 20 740 2800 30 740 5600 20 740 BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12, 2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date: 8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ RP:The Shublik Phenomenon Page 11 of 13 After this circulation the well was bled to zero and the rams opened.A flow check was conducted to show the well was flowing slightly.A connection was made and drilling resumed.The initial bottoms up from the time drilling began showed gas cut mud with a maximum of 9700 units of gas.While drilling ahead with 250 GPM we showed slight losses up to 5247 strokes(-8 bbls.).We began seeing gas/oil with a slight increase in the flowline at 5300 and the shakers began to blank off.Mud was lost over the shakers and three water hoses and a pressure washer were used in an attempt to keep the mud on the screens.Lost a total of 55 bbls.Here so difficult to track gain/loss from this point. We continued to drill thru the basement of the Shublik and the remaining kelly down.There was no additional gas seen from the shublik as we drilled it. After drilling this stand down,and getting a bottoms up from the time we drilled out the bottom of the Shublik,a flow check was conducted showing the well flowing slightly with pumps off. Appendix 4: Diagram Used on Erskine to differentiate between a positive kick and ballooning. , Sind Well in Read&Record SIDPP,SIAP&Pit Cain 4 1 Calculate Annulus Friction Pressure(.AFP) Real (Positive Influx) Versus Ballooning While Drilling NO YES PROBABLE s NO • LOSSES Ll, YES SIAP FLOW I IDPP>AFP. BALLOONING 24 HRS WHILE -* >Slimp', --> IECLININC: -* RILLMIC? YES `•a i YES \0 YES 'd' POSSIBLE REAL(POSITIVE) \ 'L.OScrs IAS 24 HR'\\iine SLAP INFLUx-Circulate OMW for 1st nil[1N,(,! -, >SIDPP/ 0. Circulation,Maintain BHP w/Choke Check Influx(di Bottoms Up before I NO YES • Raising Mud Weight i SLAP NO POSSIBLY REAL(POSITIVE) >SI DPP' -* INFLUX-CAN USE W&W.BUT VERY LITTLE ADVANTAGE Circulate OM W for I st YES Circulation.Maintain BNP w/Choke Check Influx;a;Bottoms Up before Raising Mud Weight LIKELY REAL(POSITIVE) INFLUX-USE W&W The following has been extracted from the Erskine HPHT Well Control Manual 4.1 Ballooning or Flowback 4.2 Introduction Ballooning or flowback occurs when mud which was either lost to fractures in the formation or into the "ballooning"of the wellbore is given back when some of the excess pressure in the wellbore is relieved. At this time, either the fractures squeezes back some of the mud that entered or the "balloon" returns to its original size. The sequence of events is: BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number: UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date:8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ RP:The Shublik Phenomenon Page 12 of 13 1. Start pumps impose annular friction pressure on wellbore in addition to mud hydrostatic (note: the annular friction pressure is significant in the 8 1/2" hole amounting to 300 psi or more at drilling circulating rates) 2. Lose mud to formation 3. Turn pump off and take away annular friction pressure. 4. Get back some or all of the mud previously lost to the formation It will be the responsibility of BOTH the Driller and Mud Logger to keep accurate logs of the amount of mud lost to the formation and subsequently gained back. Accurate records are the key to successfully managing ballooning. THE DIFFICULTY IS IN TELLING THAT IT IS THE EXTRA MUD COMING BACK AND NOT A GENUINE KICK. UNLESS YOU ARE SURE THAT IT IS THE "LOST" MUD BEING RETURNED, THE GAIN WHEN THE PUMP IS TURNED OFF MUST BE TREATED AS AN INFLUX. The goal of this section is to set up a system to allow the difference between ballooning(or flowback)and a real kick to be evident. In this way,drilling can continue in a safe and effective manner. Note also the importance of attempting to avoid ballooning in the first place by keeping the wellbore pressure less than the fracture propagation pressure. This is discussed in Sections 2.2,2.3 and 2.4. 4.3 Definitions 1. Drainback is the volume of mud (in barrels) that will flow from the settling and mud processing pits into the active pits after the mud pump is turned off. Drainback will occur whether the formation is ballooning or not. It is a function of the layout of the mud processing system. 2. Flowback is the volume of mud (in barrels) that flows out of the top of the well when the pump is turned off. 4.4 Procedures and Guidelines Figure 2 shows the procedure that must be used while drilling in the 8 1/2" and smaller hole sections where "ballooning"or"flowback"could be a serious problem. It is essential that all operations are carried out in a consistent manner. In this respect, the Senior Foreman or Foreman(depending on who is on tour) is responsible for ensuring that sufficient information is relayed from one Driller to the Driller on the opposite tour. The mud loggers are responsible for making similar arrangements such that continuity of action and observation takes place. Comprehensive records must be kept such that loss/gain events can be accurately tracked. Fluid should not be bled from the well without first consulting with onshore management team. If consistent"flowback" is occurring,more general rules can be set up as to what volumes of fluid can be bled off without specific authorization from base operations. BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number:UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date:8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ 11111 RP:The Shublik Phenomenon Page 13 of 13 0/0 A DRII I.IM , ,11111) Loss/Gain While Drilling A osse'' IF IN DOUBT THE WELL MAY BE Deal with Losses before Yes y SHUT IN AT ANY TIME Resuming Drilling k.o No THE VOLUMES THAT CAN BE "R' ALLOWED BACK IN TO THE WELL Yes DEPEND ON KICK TOLERANCE Record losses on gain See Note I:Reducing Louse+ loss logbook. Beep update of NET loss NOTES: I.To avoid further losses action will be �ShutDown Pump required to reduce the ECD. (for flowcheck,connection etc..) Consider:Reducing flowrate,rotary Line Up Returns to Trip Tank speed or mudweight (if required-to assist detection) Adjusting mud rheology mn Monitor Flow Decay at Flowline&Trip Adding LCM to mud si,u,d,x,n Driller) Tank MAX 5 BARREL" Setting drilling liner or EST pr„d„wEers Compare aemrd. 2.Monitor the well very closely while the es flow dec . flowcheck gas is being circulated out. the sante or Circulate over the choke if any Indic- Record gains on gain/ quicker than last ations of a hydrocarbon influx. loss logbook. Keep ump shutdow Remember:Hydrocarbons may come update of NET loss No-SLOWF'.R back into the well with Yes DECAY some mud returns s the total ga NuIs this the FIRST Y <NET loss plus 3.Compare pressures with ECD,trapped rime? expected floss back pressure test,thermal effect test. "normal”pa Compare volumes lost/gained since the Yes well was last static Flush and fill the MGS loop with mud No SHUT WELL I N 4.A maximum of 30 barrels*total flow from the well is allowed without circ. &Record SIDPP&SIAP bottoms up.(i.e.10 barrels from the Yinitial flow plus 2 further 10 barrel Review Situation with Office flowbacks). THIS VOLUME MAY BE LIMITED FURTHER IF KICK TOLERANCE IS LOW uspect 'alloonuta Su rerchar-in_9 5.Circulating bottoms up may have to be Yes repeated if more than one bleed down Happened Before is performed _Open Up Well via choke es On the initial circulation of bottoms up: A to trip tank- Bleed off a)Circulate thru'choke&MGS at a rate up to max of 10 barrels' where losses are not experienced yNu b)Monitor the well very closely for any indications of hydrocarbons )oes flow decay'. c)To reduce the risk of differential Circulate Yes No sticking,the string can be rotated Bottoms Up Yes \o through the annular. Reduce the &!or go back ANI 'TOP? operating pressure of the annular to to Drill .:o A the minimum without leakage Shut Well In&Record d)If high levels of gas are seen at the SIDP' : SIAP surface it may be necessary to reduce the circulation rate 44:1I es No v Y 6. If the bleed down process has to be repeated,then the volume to bleed Follow On-Bottom down will be reviewed after the results Is the total gain No <NET loss? Well Control of the first circulation are known. Yes No Procedures Ye Is total mud bled *Numbers are for guidance only,actual values should be agreed ,ick<30 bar with Onshore Management Team as circumstances dictate. Figure 2 BP Confidential and©2009 BP America Inc. Control Tier: 4 Revision Date:August 12,2009 Document Number:UPS-US-AK-ADW-ROT-ADW-DOC-00042-4 Print Date:8/16/2012 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/hse/ rp A\ p TPLT1LV YI.._y aL� I !, „ _ �'i ,� f _ [ Q SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-37A BP Exploration (Alaska), Inc. Permit No: 212-092 Surface Location: 1647' FNL, 1922' FWL, SEC. 35, T12N, R12E, UM Bottomhole Location: 4772' FNL, 4334' FWL, SEC. 35, T12N, R12E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. 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 Commission 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 Commission 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 a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy 5. Foerster Chair DATED this - day of July, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALA;. OIL AND GAS CONSERVATION COM, JON RECEIVED PERMIT TO DRILL JUL 0 6 2012 20 AAC 25.005 1 a Type of work: 1 b.Proposed Well Class: ®Development Oil ' ❑Service-Wini ®Single Zone 1 c. SpAi"DIosed for. ❑ Drill CO Redrill ' 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone ❑Cal s Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG ❑Service-Disp ❑Shale Gas 2. Operator Name: 5.Bond: ®Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 - PBU S-37A ' 3. Address' 6 Proposed Depth. 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12275' - TVD 8586'ss . Prudhoe Bay/Prudhoe Bay . 4a. Location of Well(Governmental Section). 7. Property Designation(Lease Number) Surface: ADL 028257 1647'FNL, 1922' FWL, Sec. 35,T12N, R12E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date. 1974'FNL,3665'FWL, Sec. 35,T12N, R12E, UM September 1,2012 Total Depth. 9.Acres in Property. 14.Distance to Nearest Property. 4772'FNL,4334'FWL, Sec. 35,T12N, R12E, UM 2560 7085' 4b Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL. 69.30' feet 15.Distance to Nearest Well Open Surface x- 620084 y-5979855 - Zone- ASP4 GL Elevation above MSL• 35.64' feet to Same Pool. 225' 16 Deviated Wells. Kickoff Depth. 9145' feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 3265 ' Surface: 2385 ' 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole I Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/8" 3-1/2"x 3-1/4" 9.2#/6.6# L-80 STL/TCII 1220' 8880' 8379'ss 10100' 8609'ss 82 sx Class'G' 3-1/4" 2-3/8" 4.7# L-80 STL 2275' 10000' 8620' 12275' 8586'ss Uncemented 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): Effective Depth MD(ft): Effective Depth TVD(ft) Junk(measured) 9770' 9224' 9400' 9400' 8897' None Casing Length Size Cement Volume MD TVD Conductor/Structural 76' 20" 11 yds Arctic Set 76' 76' Surface 2887' 10-3/4" 1756 cu ft AS III, 500 cu ft AS I 36'-2923' 36'-2915' Intermediate 9074' 7-5/8" 1305 cu ft Class'G' 32'-9106' 32'-8642' Production Liner 876' 5-1/2" 157 cu ft Class'G' 8894'-9770' 8460'-9224' Perforation Depth MD(ft). 9115'-9426' Perforation Depth TVD(ft): 8649'-8919' 20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 1E120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date. 22. I hereby certify that the goin s true d correct. Con act Matt Ross,564-5782 Printed Name J c e Title Engineering Team Leader Prepared By Name/Number Si ature Phone 564-4711 Date 7 3 (Z Joe Lastufka,564-4091 Commission Use Only Permit To Drill API Number Permit Ap r val Date See cover letter for Number: �/7 1 7i- 50-029-22291-01-00 12� tri, other requirements Conditions of Approval. If box is checked,well may t be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: Other: 4 3 50 0 es,: 6 of I e_5+ Samples Req'd. ❑Yes "No Mud Log Req'd: ❑yes [3 No H2S Measures: 121/Yes 0 No Directional Survey Req'd Yes 0 No �PPROVED BY THE COMMISSION Date -7— 2-5—(Z L / ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the date of aper al(20 AAC 25.005(g)) Submit In uplicate� ,/ AL yz ?��z'7./7.I 2ORIGN To: Alaska Oil & Gas Conservation Commission From: Matthew Ross0 by CTD Engineer Date: June 28, 2012 Re: S-37A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well S-37. CTD Drill and Complete S-37A program: Rig Start Date: September 1st, 2012 Pre-Rig Work: (scheduled to begin August 15th, 2012) ' 1. F MIT- IA to 3,000 psi, MIT-OA to 2,000 psi). 2. W Cycle LDS; PPPOT- T to 5,000 psi. 3. S Drift for 4W x 5W thru-tubing whipstock. 4. E Set 4W x 5W thru-tubing whipstock at 9,145' md. 5. E Mill XN profile at 8,890' and to 3.80". 6. V PT MV, SV, WV. Bleed wellhead pressures down to zero. 7. 0 Bleed production flow and GL lines down to zero and blind flange. 8. 0 Remove wellhouse, level pad. 9. V Set TWC (4" 'H' profile) 24 hrs prior to rig arrival. Rig Work: (scheduled to begin September 1st, 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" single string high side window in 5-1/2" 17# 13Cr production liner from mechanical thru-tubing whipstock at 9,145' and and 10' of rathole. Swap the well to Power- Pro SF. 3. Drill build: 4.125" OH, 255' (30°/100 planned) with resistivity. 4. Drill lateral: 4.125" OH, 700' (12°/100 planned) with resistivity and land well in Sag River at 10,100' md. 5. Run & cement 3-1/4" TCII protection string leaving TOL at 8,880' md. 6. Drill lateral: 3.25" OH, 2,175' (30°/100 planned) with resistivity to a final TD at 12,275' md. 7. Run 2-3/8" slotted liner and drop inside 3-1/4" protection string. 8. Freeze protect well to 2200' TVD. 9. Set BPV. ND BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 10.RDMO Nordic Rig. Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set 4-1/2" KB liner top packer. 3. Generic GLV's. 4. RU well testers. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Power Pro for milling window and drilling (-670 psi overbalance). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" hole: 9,145' and - 10,100' and (S-37A Protection String Interval), 3.25" hole: 10,100' and - 12,275' and (S-37A Production String) Casing Program: S-37A Protection String Interval: • 3-1/2", L-80 9.2 lb/ft STL solid liner, S-37A Protection String 8,880' and - 9,130' and • 3-1/4", L-80 6.6 lb/ft TC-II solid liner, S-37A Protection String 9,130' and - 10,100' and • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. ■ This liner will be cemented in place. o A minimum of 17bbls of 15.8 ppg Class G cement will be used for protection liner cementing. (Assuming 4-1/4" hole size as specified above with 10% excess in open hole & 229' of 5-1/2" liner sump). o TOC planned at 9,000' md. S-37A Production String: • 2-3/8", L-80 4.7 lb/ft STL slotted liner, S-37A 10,000' and - 12,275' and ■ Not cemented. • The primary barrier for this operation: a minimum EMW of 8.4 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 100.1°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - • Distance to nearest property- 7,085'. • Distance to nearest well within pool - 225'. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL logs will be run. Anti-Collision Failures: • S-11A 186' (ctr— ctr distance) Status: Water injector currently injecting. o This well will be shut it prior to commencing drilling operations on well S-37A. Hazards • The maximum recorded H2S level on S pad was 500 ppm on well S-201 on 5/7/2005. • Lost circulation risk is considered low due to uncertainty in S-37A. Reservoir Pressure • The reservoir pressure on S-37 is expected to be 3,265 psi at 8,800' TVDSS. (7.2 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,385 psi. iviA5P • An EMW of 8.4 ppg for this well will provide 578 psi over-balance to the reservoir. 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A aTU1 IE MI 0 by Travelling Cylinder Report BAKER HUGHES INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well S-37 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PBS Pad MD Reference: 63:37 10/22/1992 00:00 @ 69.30ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: S-37 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore S-37A Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 4 Offset TVD Reference: Offset Datum Reference Plan 4 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,044.00 to 12,275.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,424.13ft Error Surface: Elliptical Conic Survey Tool Program Date 2/28/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 372.00 9,044.00 1:MWD-Standard(S-37) MWD MWD-Standard 9,044.00 12,275.00 Plan 4(S-37A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 12.275 00 8,585 95 2 7/8" 2.875 4.125 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB S Pad S-05-S-05-S-05 9,775.00 9,750.00 700.17 389.98 320.69 Pass-Major Risk S-05-S-05A-S-05A 9,657.91 9,500.00 807.55 411.87 455.35 Pass-Major Risk S-05-S-05APB1-S-05APB1 9,657.91 9,500.00 807.55 411.87 455.35 Pass-Major Risk S-08-S-08B-S-08B Out of range S-09-S-09-S-09 Out of range S-10-S-10-S-10 Out of range S-11-S-11-S-11 10,685.20 9,350.00 520.38 342.97 184.39 Pass-Major Risk S-11-S-11A-S-11A 11,332.94 10,200.00 186.11 442.37 -160.46 FAIL-Major Risk S-11-S-11 B-S-11 B 10,468.72 10,200.00 276.27 280.96 23.82 Pass-Major Risk S-12-S-12-S-12 Out of range S-12A-S-12A-S-12A 11,839.66 9,675.00 341.85 239.74 105.00 Pass-Major Risk S-13-S-13-S-13 12,263.41 8,825.00 1,396.63 806.09 1,218.86 Pass-Major Risk S-14-S-14-S-14 Out of range S-14-S-14A-S-14A Out of range S-24-S-24-S-24 Out of range S-30-S-30-S-30 Out of range S-37-S-37-S-37 9,150.00 9,150.00 0.02 5.43 -2.00 FAIL-Major Risk S-40-S-40-S-40 12,275.00 10,000.00 768.00 345.81 424.29 Pass-Major Risk S-40A-S-40A-S-40A 12,275.00 10,000.00 768.02 345.81 424.31 Pass-Major Risk S-43-S-43-S-43 9,052.25 9,625.00 1,099.10 223.71 875.92 Pass-Major Risk S-43L1-S-43L1-S-43L1 9,052.34 9,625.00 1,099.05 223.74 875.82 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/28/2012 4.56:31 PM Page 2 of 27 COMPASS 2003.16 Build 73 a -1. 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N, ‹..- 4.-.. 18,6:-..,A '''.....N... \''''''' 0. • gN2.5 - //, ,-- - 2 ,,II e ..- N / •., ' g / z /- • m20E . / , _ _ _ ra <, co 7/ / . - / /- 0 - /','----- ,-----, a ,--- w w 0 . . . . . . 0,,, ,,,, ---_--- . 0 ' R m w,_. _c ..-- , ,;',R 's,.. , E E ,,, ..-----7 - •,,Y C.) = - T , H g ' -- --- E - FA 1 09 g 0, 1 TREE= 4-1/16"5M CIW Si 'NOTES:CHROME TBG AND LNR WELLHEAD= 11"5M FMC S-37 ACTUATOR= OTIS KB.ELEV= 65' BF.ELEV= 32' KOP= 5654' Max Angle= 34 @ 7177' 11 2228' —14-1/2"OTIS SSSV NIP,ID=3.813" Datum MD= 9369' Datum TVD= 8800'SS 10-3/4"CSG,45.5#,NT-80, ID=9.953" —I 2923' , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT_ DATE L 6 3018 3009 1 CAMCO DOME BK ' 16 01/24/10 5 5104 5095 4 CAMCO DOME BK ' 16 01/24/10 4 6712 6624 29 CAMCO DOME BK ' 16 01/24/10 Minimum ID = 3.725" @ 8890' 3 7885 7612 33 CAMCO DOME BK ' 16 01/24/10 4-1/2" PARKER SWN NIPPLE 2 8333 7987 33 CAMCO DMY BK ' 0 01/24/10 1 8438 8075 33 CAMCO SO BK ' 24 01/24/10 ' ' 8777' —14-1/2"PKR SWS NIP,ID=3.813" 8837' —14-1/2" BKR PERM S-3 PKR, ID=3.875" ' , 8870' —14-1/2"PKR SWS NIP,ID=3.813" I 8890' —14-1/2"PKR SWN NIP,ID=3.725" TOP OF 5-1/2"LNR H 8894' M ill 4-1/2"TBG, 12.6#,NSCT 13CR, —I 8902' I \ - 8902' —14-1/2"WLEG,ID=3.958" .0152 bpf, ID=3.958" 8898' —I ELMD TT LOGGED 02/08/93 7-5/8"CSG,29.7#NT-95-HS, ID=6.875" --I 9108' I-44 k I I PERFORATION SUMMARY REF LOG:SWS SONIC ON 11/03/92 I ANGLE AT TOP PERF:31° @ 9115' Note:Refer to Production DB for historical perf data 9400' TOP OF CEMENT/SANDBACK SIZE SPF INTERVAL Opn/Sqz DATE �V�.�V�.�V0. 3-3/8" 6 9115-9148 0 07/26/09 3-3/8" 6 9255-9285 0 04/19/93 3-3/8" 4 9255-9360 0 02/10/93 _ 3-3/8" 4 9418-9426 C 02/10/93 PBTD 9692' /1......• 5-1/2"LNR, 17#,13CR FL4S, .0232 bpf, ID=4.892" —I 9770' 0•0•0•0•4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/06/92 ORIGINAL COMPLETION 09/29/09 RRD/SV ADPERF(07/26/09) WELL: S-37 03/09/01 SIS-MH CONVERTED TO CANVAS 02/04/10 DAV/PJC GLV 0/0(01/24/10) PERMIT No:'1920990 03/12/01 SIS-MD FINAL API No: 50-029-22291-00 09/07/01 RN/TP CORRECTIONS SEC 35,T12N,T12E, 1684'FNL&1929'FWL 06/03/03 MH/TLP GLV C/O(09/20/07) 07/09/09 HLS/SV TBG/LNR CORRECTIONS BP Exploration(Alaska) TREE= /16"5M CAW WELLHEAD= 11"5M FMC S m3 7 A S. .'NOTES:CHROME TBG AND LNR ACTUATOR= OTIS _- KB. ELEV= 65' proposed CTD sidetrack BF.ELEV= 32' KOP= 5654' Max Angle= 34 @ 7177' 2228' —14-1/2"OTIS SSSV NIP, ID=3.813" Datum MD= 9369' O Datum TVD= 8800'SS 10-3/4"CSG,45.5#,NT-80, ID=9.953" H 2923' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE I'l 6 3018 3009 1 CAMCO DOME BK s 16 01/24/10 5 5104 5095 4 CAMCO DOME BK r 16 01/24/10 4 6712 6624 29 CAMCO DOME BK ' 16 01/24/10 Minimum ID = 1.78" @ —10000' 3 7885 7612 33 CAMCO DOME BK r 16 01/24/10 2 8333 7987 33 CAMCO DMY BK ' 0 01/24/10 3" Deployment Sleeve 1 8438 8075 33 CAMCO SO BK r 24 01/24/10 TSGR = 9,106' MD ' , 877T —14-1/2"PKR SWS NIP, ID=3.813" R' 8837' —14-1/2" BKR PERM S-3 PKR, ID=3.875" r ' 8870' —14-1/2"PKR SWS NIP, ID=3.813" 3-1/2"Liner Top Packer -Top of:3-112' liner at-8,880' 32° I 8890' H4-1/2"PKR SWN NIP, ID= TOP OF 5-1/2"LNR H 8894' 4-1/2"TBG, 12.6#,NSCT 13CR, H 8902' / , 8902' —I4-1/2"WLEG, ID=3.958" .0152 bpf, ID=3.958" / 8898' -H UMD TT LOGGED 02/08/93 3-1/2"x 3-3/16"XO -- 7-5/8"CSG,29.7#NT-95-HS,ID=6.875" H 9108' r iimmunor Top of 2-3/8"slotted liner at-10,000' 4-1/2"x 5-1/2"TT whipstock at 9,145' _ i PERFORATION SUMMARY 31° I 2-3/8"slotted liner TD at 12,275' REF LOG: SWS SONIC ON 11/03/92 3-3/16"shoe at-10,100' ANGLE ATTOP IUZF: 31°@ 9115' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 9400' TOP OFCEMENT/SANDBACK 3-3/8" 6 9115-9148 0 07/26/09 �����.�1������1 3-3/8" 6 9255-9285 0 04/19/93 3-3/8" 4 9255-9360 0 02/10/93 3-3/8" 4 9418-9426 02/10/93 - PBTD —I 9692' /*/..... 5-1/2"LNR, 17#,13CR FL4S, .0232 bpf,ID=4.892" —1 9770' ...'vv'v....•..y, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/06/92 ORIGINAL COMPLETION 09/29/09 RRD/SV ADPERF(07/26/09) WELL: S-37A 03/09/01 SIS-MH CONVERTED TO CANVAS 02/04/10 DAV/PJC GLV C/O(01/24/10) PERMIT No: 1920990 03/12/01 SIS-MD FINAL :2/29/12 WJH proposed CTD sidetrack AR No: 50-029-22291-00 - 09/07/01 RN/TP CORRECTIONS SEC 35,T12N,T12E, 1684'FNL&1929'FWL 06/03/03 MH/TLP GLV C/O(09/20/07) 07/09/09 HLS/SV TBG/LNR CORRECTIONS BP Exploration(Alaska) • :I; m C __ J Mad .... .. 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C It 0 Z111 1 CO �� E I I I I 0� Nill Mill 1ti n, 187 a• a x x OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME 411°`? , 719 PTD# Z-(7_, 2%- Development Service Exploratory Stratigraphic Test Non-C nventional Well FIELD: ✓e-<-- --/j�e' — 26POOL: ``EL-e- / Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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