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Home My WebLink About202-066MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-212 PRUDHOE BAY UN POL W-212 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/23/2025 W-212 50-029-23078-00-00 202-066-0 W SPT 5090 2020660 1500 1513 1514 1513 1511 131 371 368 374 4YRTST P Sully Sullivan 8/16/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL W-212 Inspection Date: Tubing OA Packer Depth 301 2419 2277 2271IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250816153848 BBL Pumped:1.3 BBL Returned:1.3 Tuesday, September 23, 2025 Page 1 of 1          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y Anne Prysunka at 1:10 pm, Nov 23, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV RBDMS JSB 112522 WCB 11-29-2024 DSR-11/23/22 From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: PBU W-212 (PTD# 202-066) Request for Administrative Approval Date:Monday, January 24, 2022 3:22:57 PM From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Monday, January 24, 2022 3:10 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: PBU W-212 (PTD# 202-066) Request for Administrative Approval Oliver, Sorry for the delay. In the application to allow the W-212 well to inject MI you indicate that the W- 17A well does not have cement coverage above the Polaris Oil Pool and you propose three mitigations to address this. These are: 1. Monthly TIO plots for W-17A. 2. WFL and temp log run in W-17A after 6 months of injection. 3. WFL and temp log run in W-17A every two years thereafter. We’re not sure how these mitigations will actually provide an effective means of determining if the W-17A wellbore is allowing MI to escape the Polaris Oil Pool. There’s a couple issues in particular that we need more information on. First, the well files for the W-17 well indicate that when the well was initially completed they pumped a cement plug down the OA to cover the surface casing shoe. Since the W-17A well kicked off nearly 2,500’ below the surface casing shoe and was completed with a liner that was set about 2,000’ below the casing shoe having a plug in the OA of the W-17 well would mask any potential signs of MI moving out of the Polaris Oil pool through the W-17A OA. Please provide more information on why you think TIO plots would be an effective means of detecting MI escaping the Polaris Oil Pool. Second, we’re unclear how a water flow log would be able to detect if MI is moving behind pipe in the W-17A well. Since a WFL works by activating oxygen in water we’re not sure how a WFL would detect MI. Please provide more information on how a WFL would be an effective means to detect MI moving behind pipe. Regards, Dave Roby (907)793-1232 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: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, December 16, 2021 11:59 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: FW: [EXTERNAL] RE: PBU W-212 (PTD# 202-066) Request for Administrative Approval Chris, Dave, Looks like the attached Polaris AA request for W-212 MI service is also yet to be received. It was submitted on the same day as S-216. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, August 18, 2021 2:00 PM To: Abbie Barker <Abbie.Barker@hilcorp.com> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: [EXTERNAL] RE: PBU W-212 (PTD# 202-066) Request for Administrative Approval Received, thank you! From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Wednesday, August 18, 2021 1:56 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: PBU W-212 (PTD# 202-066) Request for Administrative Approval Hello, Please find the attached Administrative Approval request to allow the injection of enriched hydrocarbon gas into injection well PBU W-212 (PTD# 202-066). If you have any questions, please contact Oliver Sternicki at (907) 564-4891 or oliver.sternicki@hilcorp.com. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 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. Hilcorp North Slope, LLC Stan Golis, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 12/01/22 Commissioner Jessie Chmielowski and Commissioner Greg Wilson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: AIO 25A.018 Results of Polymer Injection Trial Prudhoe Bay Unit Polaris Oil Pool W-212 (PTD# 202-066), W-213 (PTD# 207-051) and W-216 (PTD# 207-168) Dear Commissioner Chmielowski and Commissioner Wilson, On August 2, 2021, the Alaska Oil and Gas Commission (AOGCC) granted Hilcorp North Slope, LLC (HNS) administrative approval with Area Injection Order (AIO) 25A.018 to allow for a polymer injection trial into Prudhoe Bay Unit- Polaris Oil Pool (Polaris) wells W-212, W-213 and W-216. Prior to the AIO, polymers were not approved for enhanced oil recovery (EOR) injection into the Polaris Oil Pool under Area Injection Order (AIO) 25A. HNS initiated the Polymer Injection trial in W-213 starting on January 26, 2022. Next, polymer injection began in W-212 on March 31, 2022. Finally, polymer injection commenced in W-216 on April 3, 2022. Polymer injection continued in all three wells until the trial was ended on November 2, 2022. 10-404 sundry reports were submitted to the AOGCC for each affected well on November 23, 2022. Additionally, AIO 25A.018 required a “summary of the results of the injectivity test” be submitted to the AOGCC within 30 days of the completion of the trial. This summary of results of the trial is attached. If you have any questions, please call me at 907-564-5231 or Natalie Brent at 907-564-4313. Sincerely, Stan Golis PBW Operations Manager Attachment: Injection Trial Results Wellbore Schematics Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2022.12.01 16:14:32 -09'00' Stan Golis (880) Polymer Injection Trial Results 12/01/22 Scope of Work: Execute long term polymer injection trial into Polaris oil pool wells W-212 (PTD# 202066), W-213 (PTD# 207051) and W-216 (PTD# 207168) for up to 18 months. Injection Trial Results: Hilcorp has completed a polymer injectivity trial on the Prudhoe Bay Unit – Polaris pool wells W- 212, W-213, and W-216 as of November 2, 2022. The polymer injectivity trial concluded that: x We can successfully inject polymer into the Oba, Obc, and Obd Schrader Bluff layers. x The injectivity dropped by 45% while injecting polymer as compared to produced water after just ~10 weeks of injection. The goal of polymer is to increase the viscosity of the injected water to improve the mobility ratio. The improved mobility ratio results in increased sweep efficiency and higher ultimate recovery within the given pattern. Based on the results of the polymer injection pilot the increase in recovery efficiency does not overcome the loss in injectivity. Since the Schrader Bluff waterflood is relatively immature the drop in total volume being injected will directly impact the offset producer’s oil rate. This would also result in an increase in the processing time for patterns delaying the recovery of that oil. At this time Hilcorp has decided to stop the polymer injectivity trial and return the wells to WAG injectors. MEMORANDUM TO: Jim Regg/'Cu� 72 P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC W-212 PRUDHOE BAY UN POL W-212 Sre: Inspector Reviewed By: P.I. Supry " Comm Well Name PRUDHOE BAY UN POL W-212 API Well Number 50-029-23078-00-00 Inspector Name: Jeff Jones Permit Number: 202-066-0 Inspection Date: 7/21/2021 Insp Num: mitJJ210810202328 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well w-z1z Type Inj N . TVD 4456 Tubing 31 32 30 28 ' - - PTD 2020660 T e TQSt' SPT, Test psi Type 1500 IA 49 2004 '� 1886 - 1872 ' --- - — — — - - - - - -- BBL Pumped: 1.2 BBL Returned. T 1 OA o o 0 0 �. ---I— ... --1- Interval OTHERP/F P - Notes: Pre injection MIT per sundry #321-218 well inspected, no exceptions noted. Wednesday, August 11, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg �. �l z,Z,1 P.I. Supervisor r\� FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 5, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC W-212 PRUDHOE BAY UN POL W-212 Src: Inspector Reviewed By.�!��r P.I.Supry �Jr" Comm Well Name PRUDHOE BAY UN POL W-212 API Well Number 50-029-23078-00-00 Permit Number: 202-066-0 Insp Num: mitBDB210803133741 Rel Insp Num: Inspector Name: Brian Bixby Inspection Date: 8/3/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W -2I �--- Type Inj W' TVD 4456 Tubing 1611 - 16u - 16n 1611 PTD 2020660 Type Test SPT' Test psi 1500 IA 759 2324 2271 - 2264 - _ BBL Pumped: 1 - IBBL Returned: 1 OA 0 - 99 — — 99 - 99 Interval - INITAL P/F P ✓� Notes: Thursday, August 5, 2021 Page I of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:202-066 6.50-029-23078-00-00 PRUDHOE BAY, POLARIS OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 6330 6073 5280 None 6073 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 3376 9-5/8" 35 - 3411 35 - 3164 5750 3090 Intermediate Production 6288 7" 32 - 6320 32 - 5501 7240 5410 Perforation Depth: Measured depth: 5904 - 6060 feet True vertical depth:5131 - 5268 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L80 30 - 6085 30 - 5290 Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Packers Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 650250510 428 800 1650 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing 5 GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured5510 Sundry Number or N/A if C.O. Exempt: 321-218 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028263 PBU W-212 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Install Regulated Injection Completion 5021, 5857, 5939, 6024 4418, 5090, 5161, 5236 5021, 5857, 5939, 6024 4418, 5090, 5161, 5236 By Samantha Carlisle at 3:18 pm, Aug 04, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.04 14:49:14 -08'00' Stan Golis (880) RBDMS HEW 8/5/2021 DSR-8/4/21MGR04AUG2021 ACTIVITY DATE SUMMARY 3/22/2021 T/I/O = SSV/200/0. Temp = SI. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (300 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled void to 0 psi. Pumped through void, good returns. Did not function LDS. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA & OA = OTG. 14:00 3/31/2021 T/I/O = 180/120/10. Temp = SI. TBG FL (Pre RWO). TBG FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:50 4/7/2021 T/I/O = 180/120/10. Temp = SI. T FL (pre RWO). T FL @ surface (WHPs & T FL unchanged since monitor on 3-31-21). SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:50 5/17/2021 T/I/O = SSV/115/10. Temp = SI. OA Integrity Test to 1200 psi PASSED (Pre rig). OA FL @ near surface. Used 2.1 bbls Diesel to pressure OA to 1200 psi. IAP increased 8 psi. OAP decreased 43 psi during the 5 min test. No sign of leaks anywhere on the surface kit. Bled OAP to 0 psi (0.7 bbls). Hung tags. Final WHPs = SSV/115/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:45 6/27/2021 ***WELL SI ON ARRIVAL*** BRUSH & FLUSHED TBG DWN TO TBG TAIL @ 5127' MD w/ FULL BORE BRUSH, 3.5" G-RING T-BIRD PUMPED 105 bbls DIESEL DURING BRUSH & FLUSH TO LOAD TBG SET 3.81" PXN PLUG w/ FILL EXT IN XN NIP @ 5114' MD (plug body= 45" oal, prong= 96" oal, 1.75" fn) SET 4-1/2" WHIDDON CATCHER ON TOP OF P-PRONG @ 5078' SLM PULLED BK-DGLV IN GLM @ 4982' MD (pocket empty) PULLED 4-1/2" WHIDDON CATCHER @ 5078' SLM PERFORMED CMIT-TxIA TO 2500 PSI **PASS** (see data tab) ***JOB COMPLETE, WELL LEFT SI, DSO NOTIFIED OF STATUS*** Surface and Tubing costs added. 6/27/2021 T/I/O=140/100/100 ASSIST SLICKLINE (PRE RWO) PUMPED 105 BBLS AMB* DIESEL TO LOAD TUBING. PUMPED 5.8 BBLS OF AMB* DIESEL TO ACHIEVE TEST PRESSURE. CMIT-TxIA TO 2610 PSI PASSED. TAGS HUNG ON MV/IA FWHP=500/500/100 IA/OA= OTG SLICKLINE IN CONTROL OF WELL UPON DEPARTURE. 6/30/2021 T/I/O=520/370/50 Circ-Out (RWO) Pump 50 bbls 1% kcl/Barakleen, 240 bbls 1% kcl down TBG taking returns up IA to W-56 flowline. Pump 75 bbls diesel down IA taking returns up TBG to W-56 flowline. U-tube TxIA for 1 HR. FWHPs=400/400/0 7/2/2021 Cost Placeholder for seven 1 1/2" dummy GLV's w/RK latches and repair of shear valve. Daily Report of Well Operations PBU W-212 Daily Report of Well Operations PBU W-212 7/3/2021 T/I/O=0/0/0 AOGCC CMIT TxIA PASSED to 2500 psi (RWO) (Witnessed by Lou Laubenstein) Pumped 1.8 bbls diesel down IA to pressure up TxIA to 2539/2538 psi. T/IA lost 62/64 psi 1st 15 min & 18/18 psi 2nd 15 min. Bled back 1.8 bbls FWHPs=0/0/0 7/3/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(rwo expense, tubing cut) CORRELATE TO TUBING TALLY RECORD DATED 11-APR-2002. FIRE MID-STRING SHOT AT 5068'. CCL TO TOP SHOT OFFSET: 5.7'. CCL STOP DEPTH: 5062.3'. CUT TUBING AT 5066'. CCL TO CUTTER OFFSET: 12.2'. CCL STOP DEPTH: 5053.8'. MOVED CUT DEPTH 2' HIGHER TO ACCOMODATE CHEM CUTTER UPPER ANCHOR PLACEMENT(out of collar at 5060'). ***WELL LEFT S/I, SECURED ON DEPARTURE. TURNED OVER TO DSO*** 7/4/2021 T/I/O = 30/30/0+. Temp = SI. Bleed WHPs to 0 psi (pre RWO). Wellhouse & flowline disconnected. IA FL @ surface. OA FL near surface. Bled OAP to BT to 0 psi in <1 min (all gas). Held open bleed for 3 hrs. Bled IAP to BT to 0 psi in 2 hrs (0.1 bbl). TP went on VAC. Held open bleed for 1 hr. Monitored for 30 min. WHPs unchanged. Final WHPs = VAC/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:59 7/5/2021 T/I/O=0/0/0. Pre-RWO ND Tree / NU BOP Wellhead Tech Set 4" CTS H plug with dry rod. Verified 0 psi on THA void. Pulled 4" Cameron tree with THA. Wellhead Tech made up 4-1/2" NSCT test sub into tubing hanger 8 turns hand tight, 8-1/2 turns pipe wrench tight and tested 4" H CTS plug to 4000 psi for 5 minutes with 0 psi loss. Passed. Removed test sub. Functioned all tubing hanger LDS to OUT measurement of 4-5/8". All LDS functioned smoothly. Torqued LDS and gland nuts to 550 ft/lbs. Installed new RX-54. Installed 11" 5K x 13 5/8" cross over. Torqued to spec. Installed new BX-160. Installed BOPs. Torqued to spec. RU 2" intergal on I/A and O/A. Torqued to spec. Job Complete. 7/6/2021 T/I/O=BPV/0/0. Pre RWO. ND Shooting flange from BOP, ND BOP for transport to 07- 05, Leave 11" x 13 5/8" DSA on Wellhead. NU shooting flange with 6" CIW valve to DSA and torque to API spec. ***Job Complete*** Final WHP's BPV/0/0 7/8/2021 T/I/O=0/0/0. RD 6" Cameron temp valve #46 with THA. RU BOPs for Tbird rig. Torqued to spec. Job Complete. 7/10/2021 TBird-1 Job Scope: Pull TBG/Mill PKR & Push to PBTD MIRU Preform BOPE testing pre Sundry requirements. 250 psi Low / 3000 psi on Rams & vavles. 250 Low / 2500 High on Annular Preformed passing draw down AOGCC rep; Adam Earl, waived witness. ,,,Continue WSR on 7/11/2021... Daily Report of Well Operations PBU W-212 7/11/2021 TBird-1 Job Scope: Pull TBG/Mill PKR & Push to PBTD ...Continue WSR from 7/10/2021...Preform BOPE testing pre Sundry requirements. 250 psi Low / 3000 psi on Rams & vavles. 250 Low / 2500 High on Annular Preformed passing draw down AOGCC rep; Adam Earl, waived witness. Test all gas senors on location. Pass. RU landing joint and screw in to hanger 8 1/2 turns. Brake out lock down screws and pulled hanger free. Pulled up 20 k over with no sign of TBG releasing a cut. Continued up to 45k over with again no sign of TBG releasing. Worked completion for one hour with no luck. Called eline to cut TBG again. Start circluating well with 1 %KCL through empty pocket in GLM at 4982' Eline made three attempt at cutting the TBG just above the PKR. On the third trip the RCT cut the TBG @ 5069' MD. MU Landing joint 8 1/2 Turns pull completion up to 100K and start workin pipe a dozen times then pull up to 115k and pipe released. Hanging weight @ 61k Start pulling 4 1/" TBG ...Continue WSR on 7/12/2021... 7/12/2021 TBird-1 Job Scope: Pull TBG/Mill PKR and Psuh to PBTD ...Continue WSR from 7/11/2021... Pulled old 4 !/2" completing 5069', Loaded 2 7/8" PH6 work string, changed ram inserts to 2 7/8" pipe. Set test plug in hangerTest 2 7/8" rams to 3000 psi (Pass) MIT 7" CSG psit RCT to 2690 psi for 30 min test with a toltal loss of 20 psi.(Good) MU Baker Oil Tools PKR Milling BHA TIH with 150 joints of 2/8" PH6 tag PKR @ 5055' MD start milling process per BOT Rep. ...continue WSR 7/12/2021... 7/13/2021 TBird-1 Job Scope TBG Swap/Mill/Fish/FCO ....Continue WSR from... 7/12/2021 Mill making progress on PKR. Finally seen PKR cut lose and fall. Stared seeing a increase in flow rate to pits shut bag then closed choke. Monitor stand pipe pressure staying at Zero. Backside at 25 psi. Preform slow circ and shut down to make sure no gas in work string. Monitor stand pipe for 10 min no change, no checks in BHA. CSG pressure at 25 psi. Call OE; Brian Glasheen, let him know we planned to preform Bullhead kiill Calculated volume 38 bbls below PKR Line up down backside, pump and kill well. Final calculated hydrostatic pressure at top of perfs 2204 psi. Well is closed and Tubing pressure rose to 30 psi. Bled a Barrel and pressure rose to 90psi. Line up to pump down Tubing and Annulus at the same time with Pump at 5 BPM with Pump pressure at 1200psi After discussion with Town Team an agreement was made to order 9.1ppg KWF. Pump 240 bbls of 9.1 ppg well killed. TIH looking for top of PKR and push to bottom. Dress off inside to optimize getting spear to penetrat and recover. Pump bottoms up to clean well then TOH. ...Continue WSR on 7/14/2021... 7/14/2021 TBird-1 Job Scope: TBG Swap/Mill/Fish/FCO ...Continue WSR from... 7/13/2021 TOH with PKR Mill. TIH w/ 4-3/4" Itco Spear w/ 3.885 series grapple, bumper sub, oil jar. 353' 3-1/2" OD spiral DC's, Accel., (BHA 407') Up Wt 51K, SO Wt 42K, Tag fish @ 5972'. POOH with Fish. LD Fishing BHA, PKR and Tailpipe assembly. Continue WSR on 7/15/2021... Daily Report of Well Operations PBU W-212 7/15/2021 TBird-1 Job Scope: TBG Swap/Mill/Fish/FCO ...Continue WSR from... 7/14/2021- Continue LD 4-1/2" Tailpipe assembly. Clean & Clear Rig floor. PU/MU clean out BHA- 6-1/8" Junk Mill, (2) Boot Basket. 5-3/8" Casing scraper, 6-1/8" string mill, 4- 3/4" bumper sub and oil Jar, (11) DC's . - OAL BHA - 381.78'. TIH with clean out BHA on 2-7/8" PH6 stands from derrick. Attempt to mill past obstruction @ 5945'. No progress. Attempt to rotate past obstruction. Stack 10K. 40K over to pull free. TOH for tapered milling assy to prevent casing damage. MU Junk mill & string mill assembly, bumper sub, oil jars & 11 DC's- OAL- 371.01' TIH on stands from derrick. MU power swivel and stripper head. Job Continues on 7/16 WSR 7/16/2021 TBird-1 Job Scope: TBG Swap/Mill/Fish/FCO ...Continue WSR from... 7/15/2021 - Cont making up stripper head and Power swivel. RIH , Slack off from 5936' md, 52 K PUW, 41K SOW Tag up at 5,953' with 10k down. Pumps on at 3 bpm. 550 psi, ROT 60 rpm1.5K FT. Mill tight spot from 5947' to 5955' md. WT fell off at 5,955' continue reaming down to 5970'. Ream tight spot x 3 until clean. Wash down from 5,970. to 6091ft (6111ft corrected). POOH laying down workstring. Pull Wear ring & set test plug. Install 2-7/8 X 5-1/2" VBRs and Test to 250 low, 3000 psi high (per sundry) 3- 1/2" & 4-1/2" Test Joints. Pull Test plug. RU GBR casing equipment. Prep completion jewlery for 3-1/2" / 4-1/2" WFRM completion. Continue WSR on 7/17 7/17/2021 TBird-1 Job Scope: TBG Swap/WFRM Recomplete ...Continue WSR from... 7/16/2021 - MU & run 3-1/2" / 4-1/2" WFRM completion. Run new 3-1/2" L-80 Vam Top 9.2# x 4-1/2" L-80 Vam Top 12.6# completion, torque turned to spec. Land completion at 6085.75ft. 70K PUW, 58K SOW. RU & run e-line GR/CCL to confirm sapceout. Confirmed with Town engineer on correct spacing. No space out pups required. RD Eline & GBR Casing. Rig up to pump Packer Fluids. Continue WSR on 7/18..... 7/18/2021 Installed THA, Installed Tree, Leak tested against TWC (Pass). Pulled TWC. RDMO. ***Job Complete*** 7/18/2021 TBird-1 Job Scope: TBG Swap/WFRM Recomplete ...Continue WSR from... 7/17/202.- Finish rigging down casing equipment and RU for Packer fluids. Reverse in 94 bbls of 9.1 brine with 1% Baracore + 0.1% Oxygone. Chase with 25 bbls of 9.1 Brine. Drop Ball & Rod and set Packer per HES procedure. MIT-T & IA per the sundry, MIT -T by pressuring up tubing to 3160psi. 15 minute pressure was 3115psi and 30 minute pressure was 3100psi. Bled Tbg pressure to 2000psi. MIT - IA initial pressure was 2890psi, 15 minute pressure was 2855psi and 30 minute pressure was 2845psi. Bleed Tbg pressure to shear out DCK valve in GLM. Verify circulation. Well not freeze protected. AOGCC Notice given. 7-17 07:00, witness waived by Guy Cook. Set 4" 'H' TWC. Job Complete 7/18/2021 T/I/O=0/0/0 SI Freeze Protect Post Rig (RWO EXPENSE) Pumped 85 BBL's of DSL down the IA while taking returns to an open top tank from TBG. U-Tube for 1 Hr. Pad Op/WSL notified Tags hung on MV/IA Valve positions=SV SSV WV MV closed CVs OTG Hardline SI FWHP=520/540/10 Daily Report of Well Operations PBU W-212 7/20/2021 ***WELL S/I ON ARRIVAL***(post rwo) MADE UNSUCCESSFUL ATTEMPT TO PULL B&R, SD @ 6,046' SLM (sticky) MADE 2 RUNS W/ 10' x 2.25" PUMP BAILER FROM 6,050' SLM TO 6,054' SLM (recovered 3gal thick schmoo) ***CONT WSR ON 7/21/21*** 7/21/2021 ***CONT WSR FROM 7/20/21*** (rwo expense) MADE 2 BAILER RUNS W/ 10' x 2.25" PUMP BAILER to 6051' SLM.(recovered 3 gallons of thick schmoo) PULLED BALL & ROD FROM RHC BODY @ 6072' MD. PULLED BEK-DCK & SET BK-DGLV IN ST#8 @ 4888' MD PULLED RK-DGLV & SET RK-AL-WFR (600 bwpd) IN ST#4 @ 5910' MD PULLED RK-DGLV & SET RK-AL-WFR (996bwpd) IN ST#2 @ 5998' MD MADE 5 RUNS W/ 2.50" PUMP BAILER FROM 6,054' TO 6,056' SLM (recovered 4gal thick schmoo) PULLED 3 1/2" RHC FROM 6,056' SLM RAN 3 1/2" BRUSH, 2.50" GAUGE RING, BEGIN TO SD IN SCHMOO @ 6,067' SLM ***CONT WSR ON 7/22/21*** 7/21/2021 T/I/O= 31/49/0. Temp= SI. LRS unit 72 AOGCC (witnessed by Jeff Jones) MIT-IA to 1800 psi *PASSED* at 1872 psi. (2000 psi max applied pressure). IA lost 118 psi during the first 15 minutes and 14 psi during the second 15 minutes. IA lost 132 psi during the 30 minute test. Pumped 1.2 bbls to achieve test pressure. Bled back 1 bbl to final T/I/O= 26/6/0. 7/22/2021 ***CONT WSR FROM 7/21/21*** (rwo expense) SET 3 1/2" RMX PLUG BODY @ 6,072' MD (verified w/ checkset) SET RMX-AL-WFR (204 bwpd) IN RMX SUB @ 6,072' MD ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 8/2/2021 T/I/O = 1660/830/90. Temp = 126°. IA FL (pre AOGCC). IA FL @ surface. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:30 8/3/2021 T/I/O=1611/759/0 AOGCC MIT IA PASSED to 2100 (Max applied 2375) (Witnessed by Brian Bixby) Pumped 1 bbl 100* diesel down IA to 2374 psi. IAP lost 103 psi 1st 15 min & 7 psi 2nd 15 min. Bled back ~1 bbl to 760 psi. Continued bleed to 500 psi FWHPs=1610/500/60 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Thursday, July 22, 2021 6:29 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Aras Worthington; Oliver Sternicki Subject: OPERABLE: Injector W-212 (PTD #2020660) Tubing cut for RWO Mr. Wallace, Injector W-212 (PTD #2020660) RWO is complete with passing MIT -T and MIT -IA on 07/18/21. AOGCC MIT -IA pre injection passed on 07/21/21 per sundry #321-218. The well is now classified as OPERABLE and can be put on injection. Post initial injection AOGCC MIT -IA is required after injection has stabilized. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan. Holt@ Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, July 4, 20213:58 PM To: Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2Field LO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2- WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-Wellpad LV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-Wellpad MN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-Wellpad RJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW-GC2- Well padS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2-WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2-WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: Injector W-212 (PTD #2020660) Tubing cut for RWO W Injector W-212 (PTD #2020660) had the tubing cut in preparation for an upcoming Rig Workover. The well is now classified as NOT OPERABLE until the primary barrier has been restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC FLr'-2 �kw -zjz ro zou66 Regg, James B (CED) From: Alaska NS - PB - RWO WSS <PBRWOWSS@hilcorp.com> Sent: Tuesday, July 13, 2021 1:23 PM To: DOA AOGCC Prudhoe Bay beef -71j 3 f 7tY Cc: Alaska NS - PB - RWO WSS Subject: AOGCC Notice Attachments: AOGCC Industry Guidance Bulletin No. 10-003.docx Please Contact us with any questions or concerns. Thank You and Best Regards, Jay Murphy PBRWOWSS@hilcorp.com (907) 444-7218 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 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. BOPE Use to Prevent the Flow of Fluids from a Well On the morning of July 13, 2021 at 01:39 am Thunderbird Rig #1 was in the process of milling a Packer on Well W-212 for Hilcorp North Slope, LLC when the Packer was milled free. A notice of increased return rate by the crew on tour at 01:41 was when the pump was shut down and the swivel was stopped. The f Annular Preventer was closed to secure the well against the Choke HCR and Swivel Kellv Valve. After the Well is killed with Kill Weight Fluid and the current string is pulled from the Well, we will install a Test Plug and pick up the 2-7/8" Test Joint and Test the Annular Preventer, Choke HCR and the Kelly Valve. 07/13/2021 at 01:41, The BOPE was closed W-212, Greater Prudhoe Bay, PTD: 2020660 Thunderbird #1 " Jay Murphy/ Daniel Scarpella/ Matt Ross 13-5/8" BOPE test was conducted for the initial test for Well W-212 was completed on 07/11/2021 v�� MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2� f ' DATE: July 3, 2021 P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Section: 21 12E Township.- ownship:Drilling DrillingRig: NA 36 Rig Elevation: 6330 ft MD Operator Rep: OA 7 7 Nick Frazer N/A P&A: N/A Casing/Tubing Data (depths are MD): Conductor: 20 0. D. Shoe@ Surface: 9-5/8" 0. D. Shoe@ Intermediate: Csg Cut@ O.D. Shoe@ Production 7" 0. D. Shoe@ Liner: Csg Cut@ 0. D. Shoe@ Tubing: 4-1/2" - 0. D. Tail@ Plugging Data: Test Data SUBJECT: Plug Verification PBU W-212 Hilcorp North Slope LLC PTD 2020660; Sundry 321-218 ' 11N Range: 12E Meridian: Umiat Ventied Tubing 36 Total Depth: 6330 ft MD Lease No.: 28263 OA 7 7 Suspend: N/A P&A: N/A Casing Removal: 116 Feet Csg Cut@ Feet 3411 - Feet Csg Cut@ Feet Feet Csg Cut@ Feet 6320 ' Feet Csg Cut@ Feet Feet Csg Cut@ Feet 5127 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth Top MW Above Ventied Tubing Retainer 5144 ft MD 5144 ft MD N/A ' OA 7 7 7 Initial 15 min 30 min 45 min Result Tubing 2539 2477 2459 IA 2538 2474 2456 P OA 7 7 7 Tubing IA OA Initial 15 min 30 min 45 min Result Remarks: I witnessed a pre -rig MIT of the Tubing/IA after the tubing was cut @ 5067 ft for an upcoming rig workover. The test passed without issue. Attachments: none rev. 11-28-18 2021-0703_Plug_Verification_PBU_W-212_11 Wallace, Chris D (CED) From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Wednesday, May 12, 2021 4:07 PM To: Rixse, Melvin G (CED) Cc: Wallace, Chris D (CED) Subject: RE: [EXTERNAL] PTD 202-066, W-212, Sundry 321-218 - AOGCC Questions for SB WAG injector recomplete Attachments: W-212 MD Log_5in.pdf Mel, Thanks for chatting over the phone earlier. Per geo Attached is a 5" MD triple combo log of W-212 with tubing tail depth and formation tops annotated. I highlighted on the log where the upper confining interval is located as defined by the Polaris Oil Pool rules. Confining interval depth is 5,455'— 5,474' MD in W-212. Additional comments below: Thanks Brian Glasheen Operations Engineer 907-545-1144 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Wednesday, May 12, 202111:26 AM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: [EXTERNAL] PTD 202-066, W-212, Sundry 321-218 - AOGCC Questions for SB WAG injector recomplete Brian, 20 AAC 25.412 (b) suggests a packer be place within 200' of top of perforations. Why propose a 580' difference from regulations? I would like to set my VO packer above any possible sharp edges that the previous packer might have left. This make sure I don't scrap any of my sealing elements and I get a good seal. 2. 20 AAC 25.412 (d) suggests a CBL to demonstrate isolation of injected fluids to approved interval. - What is the lower depth of the confining zones for the upper most perforation at 5840' MD? Log attached. - Will there ever be perforations above 5127' MD? Per Geo: No. there will never be perfs above 5,127' MD. Top of Schrader Bluff in W-212 is 5,559' MD. - The new proposal will not allow a monitorable annulus for an area where AOGCC does not have a cement evaluation log, i.e., from 5040' MD to 5127' MD. The cement evaluation log run 12-10-2002 was run and showed good cement to the existing tubing tail at 5127' MD. - Was a CBL was not run on the 7" casing to the existing packer setting depth at 5070' MD? I saw a CBL to the existing TT only. That is correct only to the TT. If your confining zone is above the existing TT, how do you know you have injection isolation? It is not above. A monitorable IA should be constructed to below the top of the confining zones and the top of cement external to the 7" casing. (This does not appear to be the 'CBL confirmed' case in the existing completion, sadly.) AOGCC needs confirmation that good quality cement exists external to the 7" casing from 5840' MD to within the confining zones. (We may have that when you confirm confining zones.) Log attached shows good cement past confining zones. 3. Hilcorp is cutting tubing at 5068' MD which will run the risk of damaging 7" casing. No integrity test is planned on 7" casing at 5068' MD after the cut, as your new packer will be at 5040' MD. When injection is initiated at from WFRM at 5882' MD how do you confirm you are not injecting at 5068'MD? Also, do you have a CBL at 5068' MD to confirm cement above? HC will CMIT-TXIA post cut to 1000 psi to ensure no injection at 5068'MD. We only have a CBL to TT at 5127MD as the SCMT was run post rig and can not eval cement through 2 strings of pipe. 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.Rov). cc. Chris Wallace The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified 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 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. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:202-066 6.API Number:50-029-23078-00-00 PRUDHOE BAY, POLARIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028263 Property Designation (Lease Number):10. 8. PBU W-212 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Install Regulated Injecti Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 6330 Effective Depth MD: L-80 11. Commission Representative: 15. Suspended Contact Name: Brian Glasheen Contact Email: Brian.Glasheen@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 5510 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 5070, 4456 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 35 - 3411 35 - 3164 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 5904 - 6060 5131 - 5268 4-1/2" 12.6#30 - 5127 Production 6212 5404 None 6075 36 - 116 470 9-5/8" Contact Phone:907.564.5277 Date: 80 149020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3376 5750 Intermediate 6288 7" 32 - 6320 32 - 5501 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 1606 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 5/6/21 By Samantha Carlisle at 1:06 pm, Apr 28, 2021 321-218 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.26 12:31:04 -08'00' Stan Golis (880) MGR12MAY21 DSR-4/29/21 10-404X DLB04/28/2021 *Variance to 20 AAC 25.412(b) approved. Confining zones confirmed they are fully cemented above upper most existing perforations. *BOPE test to 3000 psi. Annular to 2500psi. *CMIT- TxIA to 2500psi post Eline tubing cut, prior to milling packer. 24 hour notice to AOGCC. * *Witnessed MIT-IA prior to injection and 5 days after stabilized injection. dts 5/13/2021 JLC 5/13/2021 5/13/2021Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.13 12:58:43 -08'00' RBDMS HEW 5/13/2021 RWO W-212 PTD:202-066 Well Name:W-212 API Number:50-029-23078-00 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:06/10/2021 Estimated Duration:6 Days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:202-066 First Call Engineer:Brian Glasheen 907-545-1144 Second Call Engineer:Brodie Wages 713-380-9836 AFE Number:215-01186 Current Bottom Hole Pressure:2,106 psi @ 5,000’ TVD 8.4 PPGE (+0.3 SF)| FL Shot 4/7/21 Max. Anticipated Surface Pressure:1,606 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:180 psi (Taken on 04/7/21) Min ID:3.725” ID @ 5,114’ MD Max Angle:41 Deg @ 4,491’ MD Brief Well Summary: W-212 is an unregulated Polaris Oba, Obc, Obd and Obe injector. In 2014, W-212 formed an Oba MBE with W- 200. This MBE prevents matrix injection into Obc and Obd sands. Evidence for the MBE includes two failed red dye tests and a simultaneous increase in W-212 injectivity and W-200 water production. This RWO will regulate the W-212’s injection and reinstate the high value Obc and Obd waterfloods. Additionally, this RWO will allow for W-212 to go on MI injection for the first time. Objective: Pull the existing 4 ½” L80 tubing out of the well, washer over baker S-3 packer. Replace tubing with a WFRM competition. Achieve a passing MIT-IA & MIT-T. Pre RWO work: DHD OA Integrity test Cycle LDS’s SL/FB Pull Station 1 GLV and replace with flow sleeve. Set PXN Plug with oval junk ports and fill extension at 5,144’ MD Circulate out well with 228 (1.2 *Total volume) bbls of 8.5 ppg 1 percent KCL or Seawater down the IA while taking returns up the TBG at max rate but not to exceed 2,500 psi. a. Tubing Volume to packer is .01522 bbls/ft*5,070 ft=77 bbls b. Annular volume to GLM is .0186 bbls/ft * 4,982 ft=93 bbls c. Total volume to GLM1 is 169 bbls d. Rig up to neighboring producer FL or take returns to tanks. CMIT-TXIA 2,500 psi Freeze Protect well. Pump 75 bbls of diesel down the IA while taking returns up the TBG. Rig up jumper from IA to tubing to allow freeze protect to swap. Base of confining zone above upper most injection identified at 5,474' MD. Confirmed cement across confining zone by CBL. RWO W-212 PTD:202-066 EL Cut tubing@ ~ 5,068’ MD (2’ above packer) DHD Bleed WHP’s to 0 Valve Shop Set and test TWC Nipple Down Tree and tubing head adapter. Inspect lift threads. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4-½” and 2-7/8” test joints. Test the Annular preventer with a 2-7/8” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. 4. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~64K 5. Pull 4 1/2” tubing to floor. 6. Wash over Baker S3 packer at 5,070’ MD 7. Run 4.5’’/3.5” tubing with stacker packers and waterflood regulator mandrels detailed on proposed schematic 8. Land Hanger and reverse in corrosion inhibited 8.5ppg 1%KCl 9. Drop ball and rod and set packer with 3,500psi pump pressure. 10. Perform MIT-T to 2,750 psi and MIT-IA to 2,750 psi for 30 charted minutes. Give the AOGCC 24hrs notice to witness MIT-IA test. Document on State of Alaska form 10-426 11. Shear valve in GLM. 12. Freeze protect to ~2,000ft with diesel 13. Set TWC 14. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC. Lay down the same. Recover packer/TT and lay down. /FB CMIT- TxIA to 2500 psi to confirm IC integrity after tubing cut. 24 hour notice for AOGCC to witness. mgr/AOGCC RWO W-212 PTD:202-066 Post rig: SL Spot Slickline unit and RU. Pressure test lubricator to 300psi low and 2,800psi high. Pull Ball and rod Pull RHC profile Pull Shear Valve set DMY. RDMO POI to water. DHD MIT-IA to 2750 psi after well is on stabilized injection. Give the AOGCC 24hrs notice to witness MIT-IA test. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. RWO Sundry Change Form RWO W-212 PTD:202-066 Current Wellbore Schematic: RWO W-212 PTD:202-066 Proposed Wellbore Schematic: RWO W-212 PTD:202-066 RWO BOPs: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: April 22, 2021Subject: Changes to Approved Sundry Procedure for Well W-212Sundry #: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 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:202-066 6.API Number:50-029-23078-00-00 PRUDHOE BAY, POLARIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028263 Property Designation (Lease Number):10. 8. PBU W-212 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Polymer Injection Trial Op Shutdown GAS 5 GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 6330 Effective Depth MD: L-80 11. 7/1/21 Commission Representative: 15. Suspended Contact Name: Brian Glasheen Contact Email: Brian.Glasheen@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 5510 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 5070, 4456 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 3411 35 - 3164 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 4-1/2" 12.6#30 - 5127 Production 6212 5404 None 6075 36 - 116 470 9-5/8" Contact Phone:907.564.5277 Date: 80 149020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3376 5750 Intermediate 6288 7" 32 - 6320 32 - 5501 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 5904 - 6060 5131 - 5268 1955 By Samantha Carlisle at 11:24 am, Apr 26, 2021 321-213 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.26 10:44:21 -08'00' Stan Golis (880) DSR-4/26/21MGR27APR21 X 10-404 DLB04/26/2021 Polymer injection cannot begin until AIO 25 is amended to authorize this polymer injection trial. Yes n Required? Comm 4/28/21 dts 4/28/2021 JLC 4/28/2021 RBDMS HEW 4/29/2021 Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 Job Scope: Polaris Polymer Injection Trial Reg.Approval Req’d? Yes Regulatory Contact: Abbie Barker First Call Engineer: Brian Glasheen Second Call Engineer: Brodie Wages AFE Number: 215-00773 Well Name: W-212 Permit to Drill Number: 202066 Well Type PWI API Number: 50-029-23078-00 Current Status: Operable, Online Date Reg. Approval Rec’vd: TBD Estimated Start Date: 7/1/2021 Estimated Duration: 18 months Well Name: W-213 Permit to Drill Number: 207051 Well Type WAG API Number: 50-029-23354-00 Current Status: Operable, Online Date Reg. Approval Rec’vd: TBD Estimated Start Date: 7/1/2021 Estimated Duration: 18 months Well Name: W-216 Permit to Drill Number: 207168 Well Type WAG API Number: 50-029-23379-00 Current Status: Operable, Online Date Reg. Approval Rec’vd: TBD Estimated Start Date: 7/1/2021 Estimated Duration: 18 months Scope of Work: Execute long term polymer injection trial into Polaris oil pool wells W-212 (PTD# 202066), W-213 (PTD# 207051) and W-216 (PTD# 207168) for up to 18 months. Procedure: 1. Prep Work: a. Ensure well is set up for injection pending waterflood regulator valve testing b. Workover W-212 to install WFRVs (workover sundry to be submitted separately) c. Construct required polymer facilities 2. Inject Polymer into W-213, W-212, and W-216 for ~two months. 3. Inject MI into W-213, and keep W-212 and W-216 on Polymer injection for ~one month 4. Inject Polymer into W-213, W-212, and W-216 for ~two months. 5. Repeat steps 2-4 as needed, timeframes may vary from initial trial period based on performance. 6. Slickline Post Polymer flood work a. Return well to water injection if desired Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 WELL LOG TRANSMITTAL #905065471 To: Alaska Oil and Gas Conservation Comm. February 11, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: W-212 Run Date: 8/13/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 W-212 Digital Data (LAS), Digital Log file RECEIVED 1 CD Rom 50-029-23078-00 FEB 19 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@%halllliburton.com and GANCPDC@USAANC.hou. Date: [tet �� Signed: 20206 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, February 12, 2019 P.I. Supervisor—Y yJ I SUBJECT: Mechanical Integrity Tests t BP EXPLORATION (ALASKA) INC. W-212 FROM: Lou Laubensteln PRUDHOE BAY ON POL W-212 Petroleum Inspector See: Inspector Reviewed By: rp P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-212 API Well Number 50-029-23078-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL190204154549 Permit Number: 202-066-0 - Inspection Date: 2/4/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min PTD!,Type T - - Well W-212 T eInj sr TVD 4456 -',Tubing) 8n a77 " s77 877 T- — Type J --- -- 2020660 yp —I (Test psi 1500 IA I 298 2501 2441 2432 �. BBL Pumped: i 6 L3 O 140 i 393 384 9BBL Returned — Interval 4YRTST P/F P— Notes: Tuesday, February 12, 2019 Page 1 of I • � 2-0Z^o�Gv 2-Co WELL LOG TRANSMITTAL#903000411 To: Alaska Oil and Gas Conservation Comm. January 15, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED DATA LOGGED Z./5/2014) Anchorage, Alaska 99501 K BENDER JAN 2 0 201ti RE: Injection Profile: W-212 AOGCC Run Date: 12/18/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 W-212 Digital Log file 1 CD Rom 50-029-23078-00 Production Profile (Final Field Print) SCANNED f h= 1 Color Log 50-029-23078-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: D�✓� u /`�A�'�"' t STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMISAN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other:MBE Treatment 13 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-066 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-23078-00-00 7. Property Designation(Lease Number): ADL 0028263 8. Well Name and Number: PLRS W-212 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,POLARIS OIL .a tE11.Present Well Condition Summary: il'-- VY' 0 Total Depth: measured 6330 feet Plugs measured feet true vertical 5510 feet Junk measured 6075 feet '! 1 6 2'.,,15 Effective Depth: measured 6212 feet Packer measured 5071 feet true vertical 5404 feet Packer true vertical 4456 feet ('? CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface 3376 9-5/8"40#L-80 35-3411 35-3164 5750 3090 Intermediate Production 6288 7"26#L-80 32-6320 32-5501 7240 5410 Liner Perforation Depth: Measured depth: 5820-5842 feet 5904-5924 feet 5962-5982 feet 5982-6002 feet 6040-6060 feet True vertical depth: 5058-5077 feet 5131-5148 feet 5182-5199 feet 5199-5217 feet 5250-5268 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 30-5127 30-4500 Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 5820-5842EU ; Treatment descriptions including volumes used and final pressure: Two Treatments: 8/31/15:15 bbls 15.8 ppg Class G Acid Soluble Cement,900 psi. 9/10/15:15 bbls 15.8 ppg Class G Acid Soluble Cement,1195 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 668 240 1119 Subsequent to operation: 990 340 1332 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service m Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-383 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature filLjwifi(/ ,1 _ Phone +1 907 564 4424 Date 11/16/15 Form 10-404 Revised 5/2015 1/77--- RQDMS Nf•v 2015 Submit Original Only • • v E 3 -p 4) t C TD o c U co o u) E m � - � � Q. c � •� � oo •a) U) ao e- O U C -o ` s co CN -n L0 -,-,-4 0` U a° a)) co p Y W " 0_ co •C tO C 0_00 C II Cn „� 15 30 m m 3 = = cOn a) a) '7) E ce Q p N L a _ C J t a o E . 0 a s Oo 73 N � 2 � mZn •c a o � 0. o CD U -Ti N co N O OO M 3 N m `� V 0 O a) O to CO N a) a) O O X U 1 cis ` N � = C44'... to C7)a° •N �� Q) � p O a !pA OTii coo O p� U E U) 03 U as C p a`... .- O c O _o I, O 0 O = C a) F2 C = O N c 0 Q E c a) O co ++ co D _ a) coLOU) ©Cn O E a to U N co a C O O " .0 II O 0 N U N s . a) Lr) p a) 5 O N H 2 j coOO co a) c° C a•10 E - C O O .c N0O O = C O co O) as a) O co 3 a) U 0 N " CO �+ c N .. to 4-' coo us 3 CA 7 O C �,, -a O c .. -0 -... 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O2 : UOCrU U .. : HCL LL U2 u) : U2ZNcn OQ U > : to cn in 1 ci ci O O O O 0 (NI cV N N N O (NI CO CA a) r .- r O) 618 O O r r • • a" as E E � a Cl) 5 L_ C a) E m 0 a) 0 0 U CD a (00 a) U Q OO tl) _ C C U) ) J m (0 0 c0tu -0 o_-Ne QY cu N N O O Lf) 'U 0 c .0 N (n LLLO (O fn 0- CO13 CO w,Nr CO r M CD M co" N o�0 r r r r !ME= 4-1/16'CAN WELLNEAD= 11'FMC • W—212 silk NOTES: •ACTUATOR= BAKER KB.BEV= 85.87' BF.ELEV= 50' KOP= 700' Max Angle= 41° 4491' —i 1014' 1—9-5/8'TAM PORT COLLAR Datum MD= 5857 Datum fvb; 1 , 2196' H4-1/2"FEES X NIP,ID=3,813" 9-5/8"CSG,40#,L-80, =8.835' —1 3411' —A GAS LFT MANDRELS Minimum ID = 3.725" @ 5114' ST MD TVD DEV TYPE VLV LATCH FORT DATE 4-1/2" HES XN NIPPLE 1 4982 4388 40 KGB-2 DMY BK 0 04/26/03 I I 6049' —14-1/2'HES X NP,13=3.813" 5070' H4-1/2"X 7-5/8'BKR S-3 PKR =3.875' I I 5093' H4-1/T HES X NP,13=3.813' 1 I , 6114' H4-1/2"FES XN N13, =3.725" 4-1/2'TBG,12.6a,L-80,TCI, — 5127' 6127' —14-1/2' 3.958' .0152 bpf,ID=3.958' 512T H ELMD TT LOGGED 12/10/02 FERFORATTON SUMUARY REY LOG: SWS SCMT ON 12/10/02 ANGLE AT TOP PERF: 31°@ 5820' kite:Refer to Production DB for historical pert data 5733' H7PUP JT W RA TAG SIZE SPF ZONE INTERVAL Opn/Sqz DATE 2-7/8' 2 OBa 5820-5842 0 04/29/03 2-7/8' 2 OBc 5904-5924 0 04/29/03 2-7/8" 6 OBd 5962-5982 0 03/25/03 2-7/8' 2 "' 5982-6002 0 04/29/03 2-7/8" 2 OBe 6040-6060 0 04/29/03 6075'CTM HFISH 3-3/8'BKR FB(10/19/15) FBID H 6212' 7'CSG,26#,L-80 BTC,0383 bpi, D=6.276' — 6320' DATE REV BY COMIENTS DA TE REV BY COMMENTS POLARIS UNIT 04/13/02 D-14 ORIGINAL COMPLETION 11/16/15 JTC/JMD FOD/IBP NOW RSH(10/19/15) W13_L: W-212 01/20/04 TIACILH GLV CORRECTION PERAK No: 2020660 02/17/08 TW/PJC DRMATIG CORRECTIONS AR No: 50-029-23078-00 10/11/10 MD/SV MAX ANGLE UPDATE SEC 21,T11N,R12E,906'FM.&1185 FEL 06/26/11 SREY PJC SET BP(06/16/11) 09/09/15 TR/34) SANUPLDGIAI3ETREATTIANT BP Bcploration(Alaska) t7) .fir, :' - `�` Loepp, Victoria T (DOA) From: Loepp, Victoria T(DOA) Sent: Friday, July 17, 2015 9:48 AM To: 'Zoesch, Eric' Subject: RE:W-212 Sundry#315-383: MBE Cement Sqz Remediation (PTD#202-066) Follow Up Flag: Follow up Flag Status: Flagged Eric, This change is approved. Please include this email approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 SCANNED AUG 1 3 2015 Work: (907)793-1247 Victoria.Loeopealaska.qov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Zoesch, Eric [mailto:zoese0©BP.com] Sent: Friday, July 17, 2015 9:43 AM To: Loepp, Victoria T(DOA) Subject: RE: W-212 Sundry # 315-383: MBE Cement Sqz Remediation (PTD #202-066) Here you go. Eric Zoesch Aurora & Polaris Field PE West Base Mgmt. Team BP Exploration Alaska Inc. 907-564-4695(0) 406-270-9837(C) From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Friday, July 17, 2015 9:38 AM To: Zoesch, Eric Subject: RE: W-212 MBE Cement Sqz Remediation 1 Please include PTD#and Sundry# in Subject line From: Zoesch, Eric [mailto:zoese0@BP.com] Sent: Friday, July 17, 2015 9:29 AM To: Loepp, Victoria T(DOA) Cc: Derrick, Laurie R; Brown, Matt (Northern Solutions) Subject: W-212 MBE Cement Sqz Remediation Hi Victoria, We've decided to pump the W-212 Cement Squeeze for MBE remediation using coiled tubing instead of fullbore.This will allow for more accurate placement of the cement at the perfs and reduce the chance of leaving cement in the hole. The intent of the job remains the same—we're just changing the delivery method. Will we need to submit a revised 403 request or does this notification suffice? Thanks, Eric Zoesch Aurora & Polaris Field PE West Base Mgmt. Team BP Exploration Alaska Inc. 907-564-4695(0) 406-270-9837(C) 2 r, ..}„ _7.4, ��, cv THESTATE Alaska Oil and Gas �M ofA T Q rA Conservation Commission ii "i ;_ __ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 vil Main: 907.279.1433 (4,ALis. ''P Fax 907.276.7542 www aogcc alaska.gov Eric Zoesch �D JULU I ,.iY% _ O 60b Li Production Engineer Sato" 0 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PLRS W-212 Sundry Number: 315-383 Dear Mr. Zoesch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 ,,D. ,,,,,,,,6„____ Cathy P. oerster Chair DATED this day of June, 2015 Encl. STATE OF ALASKA JUN 18 2UI ALASKA OIL AND GAS CONSERVATION COMMISSION 07S Ci 1-1 }t-S APPLICATION FOR SUNDRY APPROVALS ).C.11-Ci .=M_ 20 AAC 25.280 1.Type of Request. Abandon❑ Plug PerforationsE Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well ❑ Other MBE Treatment E ' 2.Operator Name: 4.Current Well Class 5.Permit to Drill Number -50h-b'C BP Exploration(Alaska),Inc Exploratory ❑ Development EJ 202-066• et' 3.Address: Stratigraphic ❑ Service E• 6.API Number P O.Box 196612,Anchorage,AK 99519-6612 50-029-23078-00-00• 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PLRS W-212. Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0028263 ' PRUDHOE BAY, POLARIS OIL_ ' _ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft). Effective Depth ND(ft). Plugs(measured): Junk(measured): 6330 • 5510 • 6006 5220 6006 None Casing Length Size MD TVD Burst Collapse Structural 1 Conductor 80 20"91.5#H-40 35.76-115.76 35 76-115.76 Surface 3376 9-5/8"40#L-80 35.26-3410 94 35.26-3163 55 5750 3090 Intermediate None None None None None None Production 6288 7"26#L-80 32.38-6319.9 32.38-5501 31 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft)• Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 30.38-5127 14 Packers and SSSV Type. 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft). 5070 55,4456 48 No SSSV Installed No SSSV Installed 12 Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Cl BOP Sketch ❑ Exploratory ❑ Stratigraphic El Development❑ Service 0 • 14 Estimated Date for 15.Well Status after proposed work. Commencing Operations: OIL ❑ WINJ 0 • WDSPL El Suspended ❑ 16.Verbal Approval. Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Eric Zoesch Email Eric.Zoesch@BP.Com Printed Name Eric Zoesch Title Production Engineer Signature Phone 564-4695 Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative may witness Sundry Number: 13 ), 3-Z3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required /(r) — 4 c 4- 6-;:k.' APPROVED BY Approved by. • (7y„_ COMMISSIONER THE COMMISSION Date: -30 _ j �Tt_ �/23/r5" ORIGINAL ., g6 6.z Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Submit Foand Attachments in Duplicate RBDMSc JUN 3 0 2015 Perforation Attachment 202-066 Well Date Perf Code MD Top MD Base TVD Top TVD Base W-212 4/29/03 PER 5820 5842 5058 5077 W-212 4/29/03 PER 5904 5924 5131 - 5148 W-212 3/23/03 PER - 5962 5982 5182 5199 W-212 4/29/03 PER 5982 6002 5199 - 5217 W-212 6/16/11 BPS 6040 6060 5250 5268 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF by To: AOGCC Date: June 15, 2015 From: Eric Zoesch, Polaris PE 907-564-4695 Subject: W-212 MBE Treatment Step Unit Operation 1 FB Bullhead acid soluble cement down W-212. WOC 2 days. 2 FB Post treatment injectivity test (1) 3 D Shoot IA and tubing fluid levels in W-200. Load W-200 if necessary and hold minimal pressure during stage 2 cementing 4 FB Bullhead acid soluble cement down W-212. WOC 2 days 5 FB Post treatment injectivity test (2) HISTORY W-212 is an unregulated Schrader Bluff injector that supports W-200 in the southwest portion of Polaris. The well injects into the OBa, OBc, and OBd zones, and the majority of the injection is known to be entering the OBa zone. Offset producer W-200 showed a distinct gross fluid rate increase of about 400 bfpd in February 2014 and an associated WC increase of -6%. WC in W-200 has been flat at 63% for the past two ASRC tests, about 15 months apart. Since W-212 is the only unregulated injector supporting W-200, this well was the likely culprit for the sudden change in fluid rate. A Red- Dye test completed in May 2015 found the transit time of water in-reservoir to be less than two hours, _ confirming the MBE. (PROF data in W-212 and PPROF's in W-200indicate that the OBa is the offending zone, consistent with historical MBE trends in the Schrader. Several successful two-stage cement MBE remediation jobs have been pumped in Milne Point, so this job is designed to closely follow the procedure from prior successful jobs. OBJECTIVE The objective of this job is to remediate the MBE from W-212 to W-200 by pumping a two-stage acid- soluble cement job in W-212. CRITICAL ISSUES • Shut in offset producers and injectors to allow reservoir conditions to stabilize • Use acid-soluble cement so the well can be restored in case injectivity is lost completely • Ensure cleanliness of pump equipment and hard line (pre and post job) • Properly dispose of remnant fluid per guidance from the Environmental Team PROCEDURE 1. Shut in offset producer and injectors 3 days prior to pumping treatment. 2. Bullhead HEC lead spacer pill followed by acid soluble cement. Chase with HEC displacement pill and foam ball per Fullbore cementing RP. Freeze protect with Diesel. 3. Perform post-treatment injectivity test 48 hours after cementing. 4. Shoot FL on W-200 and liquid pack with dead crude if needed. Pump at minimum rate required to sustain WHP while step 5 is being executed. SD pumps once cement squeeze is complete. 5. Perform second stage of acid-soluble cement squeeze with HEC spacer and displacement stages as before. Chase with foam ball and FP as before. 6. Perform post-treatment injectivity test 48 hours after cementing. Inject with non-freezable fluid until comfortable the well will not lock up. If injectivity cannot be achieved, increase pressure to 1500 psi and perform quick bleed-backs to tanks if necessary. ATTACHMENTS A. W-212 Well Bore Schematic • Attachment A: W-212 Wellbore Schematic 1-I 4-1/16"CIW WELLHEAD- 11"FMCSAFETY NOTES: ACTUATOR- BAKER W-2 1 2 KB an/- 85 87. BF ELEV 50 KOP= 706 Max Angle= 41°@ 4491 —I 1014' I—9-5/8"TAM RDRT COLLAR Datum ND= 5852' Datum TVD 5000'SS 1111 2196' —4-112-FES X NIP. 3.813 9-5/8"CSG.400 L-80. =8 835" --I 3411' GAS L r klANDHELS ST MD TVD DEV rY FE V LV LATCH PORT DA TE Minimum ID =3.725"@ 51 14 tI1 4982 4388 443 KGB-2 CIMY BK 0 04.2E43 4-1/2" HES XN NIPPLE 5049' H4-112"HES X MP. =3.817 I .5070' —14-lir X 7-5/17 BKR S-3 FKR. ,5 5 I I 5093' —4-1/2"HES X he 0=3.817 I I 5114' I—4 !27 FES XN MP,ri=3 725' TBG.12.6N.L-80.TCII, —I 51Zr I---/ I 5127' H4 '/27 WLEG. =3 95W I 14.0152 b(.0=395r 5127' I— E_ rr LOGGED 12/10/02 I PE4FORA114I4 SUMMARY REF LOG: SWS$CUT ON 1210'82 ANGL E A T TOP PERF 31' 582(7I 5733' H r PUP.IT W/RA rAG Note:Refer to Production LEI hoc histacal pert data S E SPF ZONE INTERVAL Opn/Sqz DA rE 2-718" 2 OB. 5820-5842 0 64,29A.13 2-7/8" 2 013c 5904-5924 0 04'29/03 2-718" 6 OBd 5962-5982 0 031.25./03 2-7/8" 2 " 5982-6002 0 0429/03 2-7/8 2 0134 6040-6060 0 0429/(3 I 6006' H3-3/8"BKR IPB DISCONNECT(,06.16/11 I, 1.1141.--.41111111 PBTD 6212 4'49.1491‘9,414V 4%.4404.40,4.1 pr. C_ 2 .1-80 BIC.0383 bpf -b276" H 6320' DA IE REV BY COMMENTS E REV BY COMMENT S POLARIS UNIT 04/13/02, D-14 ORIGINAL COMPLETION 01,20704 12i7TL H GLV CORRECT ON WELL W-212 12/08/02 JM/ILH DLV CVO Lt2;17705 PA0F'JC DRAWING CORREMONS PERMT No:1'2020660 12/10102 CAO/KK ELMO rrLOGGED '0;17,10 MO;57.; MAX ANGLE UPDA TE AR No:50-029-23078-00 03125/63 11WE/KK PERES I/5725,11 SRL1 PJC SET!BP 106/16/11) SEC 21.T1 1ri R12E.906'R4L.8 1165'FEL 04110;03 D1-15/1 P !V DWI)CORREC TONS 04129/03 BJ11d111LH A DPE1-0! BP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,March 05,2015 Jim Regg P.I.Supervisor el 1 3Ib li c SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC W-212 FROM: John Crisp PRUDHOE BAY UN POL W-212 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j !-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-212 API Well Number 50-029-23078-00-00 Inspector Name: John Crisp Permit Number: 202-066-0 Inspection Date: 2/28/2015 Insp Num: mitJCr 1 50303132422 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-212 Type Inj T W T-TVD— 4456 'Tubing 890 -7--- - 890 - 888 888 - PTDI 2020660 'I Type Test]SPT Test pd1 1500 IA 684 2503 2453 F 2447 Interval4YRTST 240ISP . 1 447 aaa aao Notes: I bil pumped for test SCANNED Thursday,March 05,2015 Page 1 of 1 ) } Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 092. - olòfo Well History File Identifier Organizing (done) o Two-sided 1111111111I11111111 o Rescan Needed r ~ RESCAN DIGITAL DATA \4Óiskettes, No. I o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: BY: Helen ~I o Other:: : ,I ~ Date: Lf d {P 05 /5/ m" . NOTES: Project Proofing Scanning Preparation ~~. x 30 = &'D + Date: If ~ DS 151 ~P , , = "(OTAL PAGES &0 (Count c..o~_"9I i~clude cover sheet)Y\lJp Date: ~ aJo. O!S /5/ I t ~ I BY: Helen CMaria ) BY: HelenÇ Maria) Production Scanning Stage 1 Page Count from Scanned File: f£J I (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO I I~~,:J Helene("" Maria.) Date: '-f, J.fo, OS /5/ f Y f; If NO in stage 1 page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: /s/ III I I Scanning is complete at this point unless rescanning is required. ReScanned 11I1111 /I II BY: Helen Maria Date: Is/ Comments about this file: Quality Checked 11I1111111111111111 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ] _/(::)( DATE: Thursday, April 28, 2011 lm P R p ervisor `'� &e: if SUBJECT: Mechanical Integrity Tests .1. ( BP EXPLORATION (ALASKA) INC W -212 FROM: Jeff Jones PRUDHOE BAY UN POL W -212 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry `.1�` NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN POL W -212 API Well Number: 50- 029 - 23078 -00 -00 Inspector Name: Jeff Jones Insp Num: mitJJ 110427120016 Permit Number: 202 -066 -0 Inspection Date: 4/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well , W -212 ' Type Inj. 1 W TVD 4456 • 1 IA 460 —[ 2540 ' 2480 1 2470 - 1 SP P.T.D _ J T ypeTest , T est ps i 1500 � OA 260 � 2020660 510 500 500 I Interval 4YRTST P/F P ' } Tubing 1120 - 1175 , 1175 11 Notes: 1.3 BBLS methanol pumped 1 well inspected; no exceptions noted. • - ,.r 1 4 Lt)) Thursday, April 28, 2011 Page 1 of 1 ~---~e 11~~~Y~ii~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~*~ ~; Anchorage, AK 99503-2838 ; ._ ~ ~~''` x,-c.~'....4.. Y~ -. AITN: Beth Well Job # Log Description Date 08/27/09 NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT ~- 07/26/09 1 1 L2-O6 ANHY-00101 PRODUCTION PROFILE ~-1 ~ ~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK < 07/i6/09 1 1 M-06A AZCM-00034 PRODUCTION LOG j' - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (p 07/21/09 1 1 02-11 A AYS4-00084 LDL j 07/20/09 1 1 W-212 63SQ-00011 INJ PROFILE W/WFL ' - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL p- 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -(SC L 07/24/09 1 1 H-29A AYQQ-00027 RST 05/19/09 1 03-28 B14B-00067 RST (- L.( 07/17/09 1 1 B-27A AXBD-00029 MCNL G OW12/09 1 1 C-15A AWJI-00038 MCNL - O6/25/09 1 1 Q-04A B1JJ-00023 MCNL ~ ' 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/08 1 1 07-06B AWJI-00042 MCNL 07/21/09 1 1 02-336 09AKA0149 OH MWD/LWD EDIT C O6/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT 05/12/09 1 1 H-19B B2WY-00004 MCNL (REPLACEMENT) L "' 05/07/09 1 PLtASt AGKNUWLtUCit FitGtIY I I3Y SIGNINCi ANU Fitl UMIVINCi UIVt GUYY tAGFi I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i • a~ lVlt:1VIU RAN U U M . State of Alaska Alaska Oil and Gas Conservation comm. DATE: Thursday, May 03,2007 TO: Jim Regg P.I. Supervisor ....--; :;"~ ¡ /~! (; "} ; ¡/ r//d ') I -I \ - r \'\~v¡ , l SlJBJECT: Mechanical fntegnty Tests BP EXPLOK'\ TION ('\LASKA) 10íC FROM: Jeff Jones Petroleum Inspector PRUDHOE BAY LN POL W-212 I) .; 0 tJo ~or Reviewed By: P.I. Suprv .5Eý Comm W-212 Src: Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN POL W-212 Insp Num: mitfJ070502111143 ReI Insp N urn: API Well Number: 50-029-23078-00-00 Permit Number: 202-066-0 Inspector Name: Jeff Jones Inspection Date: 5/1/2007 Packer Depth Pretest Initial 15 Min. 2520 2445 I 290 280 ¡ 1400 , 1380 i 30 Min. 45 Min. 60 Min. -~'_.'._---_. -- ~_.'-- ----~.. Well W-212 ¡Type Inj. ¡wi TVD I 4456 IA 500 ~- ¡ ;- I ¡ -~--~_.- ~DI 2020660 _!T~peTest ! SPT! Test psi I _ 150~~ OA .1-. 180 i Interval 4YRTST PIF P í/ Tubing i 1450 : --='----.------- --_._---------------~- Notes: 2385 i 2380 __L~-----L-__ 250 240 j ---¡--.-.- _._____~_~8~...L._1440 ! sCANNED MAY 0 9 2007 TIlursday, May 03, 2007 Page I of 1 . . Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well P.T.D. Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / W Pad 05/01/07 Andrea Hughes Jeff Jones W Packer Depth TVD 4,456' Test psi 1114 Well P.T.D. Notes: Well P.T.D. Notes: Tubing Casing OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 J./J d-:-' 0 fÞh 4 P /ff!"r^-- s { ~ TYPE TEST Codes M ::; Annulus Monitoring P = Standard Pressure Test R ::; Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D::; Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T ::; Test during Workover 0= Other (describe in notes) sCANNEDMAY 0'12007 MIT PBU W·212 05-01·07.xls Scblunlllerger {oCo ,..0 çp?J <v J.v 06/21/06 NO. 3862 Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth .;1. ë~jI.'''''J-ì} ~\,¡nß'>I """" ~ ,(~ ) Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Well Job # Log Description Date 6L Color CD S-111 11216189 MEMORY INJECTION PROFILE 04115/06 1 S-114A 10572082 RST UPFLOW WFL 03/01/03 1 V-105 10663005 INJECTION PROFILE 03112104 1 E·103 10560276 TEMPERATURE WARMBACK 06/22103 1 V-214 11162720 UBI 11/24/05 1 V-213 11076450 INJECTION PROFILE 07/01/05 1 V·216 11076451 INJECTION PROFILE 07/02105 1 V-221 11058523 INJECTION PROFILE 07/03/05 1 L·103 NlA INJECTION PROFILE 07/18/09 1 W·209 11076461 INJECTION PROFILE 08/20/05 1 W-207 10980589 INJECTION PROFILE 07/20/05 1 W-212 N/A INJECTION PROFILE 07/19/05 1 e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: c,~t Schlumberger·DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Received by: e RECEIVED JUN 2 3 2006 AJa(a Cil & Gas Cons. Commission Anchorage I;;). -- e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl1e\CvrPgs _ Inserts\Microfil~ Marker.doc Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well E-i02 ¿t v ,...., ~ \.. E-i02 J,,(,. '¡ -i~i¿. V-i05 .2 (¡ ~ - ¡ 3l W-2i2 :~Ù..L..... ~l't W-207)Ò{)~. {,(r., 10708040 10672378 10687690 10679053 10703968 Job# SBHP SURVEY PPROF WIDEFT/GHOST INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE 08/30105 NO. 3462 aD~---OCo~ Company: Alaska Oil & Gas Cons Comm Aftn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Field: Borealis Midnight Sun Polaris Date BL Color CD 12/10103 1 -' 05/01/08 1 06/26/04 1 'J i ¿, 01/28104 1 i.,;\ic.., 01/26/04 1 u¡c. - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrolechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered' ) t~ '~~ \ Schlumberger-DCS 2525 Gambel! St, Suile 400 Anchorage, AK 99503-2838 ! ATTN Beth Df / ((")/ I I Received by ~.~ UIIWt;v/ '- F,-:i 2 0 n¡ Jì~ SC.4NNEC SEP 0 '- ~OvJ. L/ tt, ~ ~ API No. 50-029-23078-00-00 8 ). 1- IJ.p J- ~ \- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2020660 Well Name/No. PRUDHOE BAY UN POL W-212 Operator BP EXPLORATION (ALASKA) INC MD 6330 ,-" TVD 5510 /' Completion Date 3/25/2003 r Current Status 1WINJ Completion Status 1WINJ _._---~-~-- ----~-~- REQUIRED INFORMATION Mud log No Samples No Directional Survey Ves ---------- ------ ----~--------_.- DATA INFORMATION Types Electric or Other Logs Run: RES/AIT, DT/BHC, CNl, lDl, GR, Caliper, SP, MRES, MWD, DIR, G Well Log Information: (data taken from logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Log Log Run Interval OHI ;~~d/Frmt Number Name Scale Media No Start Stop CH Received Comments ~otes 5 BS 1 0 1052 Open 5/14/2002 Platform Express Triple I Combo ~- LIS Verification 109 6294 Open 8/23/2002 . --' ~ ,W C See Notes 109 6330 Case 11/7/2002 Digital Data: Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity ¡ED v6 LJ<>976 ~~8 Vcrifi~atï.on ,~ £w~4. eMV' s\....~ I{ aJd 109 6294 Open 8/23/2002 I ~ron ¡ lag-- 5 BS 0 1052 Open 5/14/2002 Platform Express ~ cmduction/Resistivity 5 BS 0 1052 Open 5/14/2002 PEX ¡~ cçet1íent Evaluation 5 Col 4950 6194 Case 1/21/2003 Jewelry log with Press 1 Temp 1 SCMT 1 Press 1 -Temp 1 GR 1 CCl ~ ~ic 25 BS 0 1052 Open 5/14/2002 I irc ~ Induction/Resistivity 70 1052 Open 5/14/2002 PEX AIT BHC Data ~ ~ 5 BS 0 1052 Open 5/14/2002 Platform Express !~ ~duction 125 Blu 0 6040 Case 5/30/2003 Production log - Oilphase Sample, Gradio, Pressure, Temperature ,------ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~7 --- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2020660 Well Name/No. PRUDHOE BAY UN POL W-212 Operator BP EXPLORATION (ALASKA) INC MD 6330 TVD 5510 Completion Date 3/25/2003 Completion Status 1WINJ ADDITIONAL INFORM~RON Well Cored? Y ), ijJ Daily History Received? Chips Received? ~ Formation Tops Analysis Received? ·.....v IN --- Comments: --~---- ~ ------ Compliance Reviewed By: API No. 50-029-23078-00-00 Current Status 1WINJ ~N &N Date: UIC Y -' .;< 0 a, ~)-- "- Schlumbel'ger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well S-215 r~FÑ'" \ 5L...\ W-212 ~("')~ -nl n{ " Job# Log Description PRODUCTION LOG PRODUCTION LOG PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED MAY 30 2003 AlasKa u¡·¡ & Gas Cons. Cuti¡ffi~ Anchorage Date 04/23/03 04/24/03 5/15/2003 NO. 2787 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis BL Color CD ~. 1 1 ,---/ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received ~\~~\) Ö-~j\¡^,- ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich ¡¿J<.J1<B/,» DATE: May 6, 2003 Commissioner \ ~ -:7 0\ ,(X\Ù SUBJECT: Mechanical Integrity Tests THRU: Jim Regg ~ Jl\q BPX P.I. Supervisor \~1 \ PBU WOA-EOA FROM: John Crisp Prudhoe Bay Petroleum Inspector Prudhoe Bay Unit NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well A-27A Type Inj. G T.V.D. 8317 Tubing 820 850 850 850 Interval P.TD. 1982350 Type test P Test psi 3500 Casing 0 3510 3500 3500 P/F Notes: OA increased F/ 0 to 100 psi. during test. This test is prior to MI being injected. 8 BBL. Pumped. Well W-212 Type Inj. N TV.D. 4556 Tubing 0 0 0 0 Interval P.TD. 2020660 Type test P Test psi 1500 Casing 280 1610 1525 1485 P/F Notes: OA remained @ 280 psi during test. 7 BBL's pumped for test. Well W-35 Type Inj. G T.V.D. 8339 Tubing 2770 2780 2780 2710 Interval P.T.D. 1880330 Type test P Test psi 3510 Casing 600 3510 3525 3540 P/F Notes: OA remained 0 during test. Gauge was removed F/OA & 0 Positive was confirmed. Well Type Inj. TV.D. Tubing P.T.D. Type test Test psi Casing Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING o f ,/ I f /' I f / Interval P/F Type Inj. Type test TV.D. Test psi Tubing Casing Interval P/F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details M.I.T.ls performed: -ª Attachments: Number of Failures: º Total Time during tests: 8 hrs. cc: MIT report form 5/12/00 L.G. MIT BPX PBU 05-06-03 JC.xls 5/12/2003 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us , 1"7 ~~~ ' OPERATOR: V) FIELD I UNIT I PAD: () ¡?A~\ DATE: \L.><V\ OPERATOR REP: AOGCC REP: Well W-212 P{[;Q:2020660 Notes: Well P.T.D. Notes: Well P.T.D. Notes : Well P.T.D. Notes: Well P.T.D. Notes: SP Exploration (Alaska) Inc. Prudhoe Say I PBU I W 05/06/03 JOHN CUSSON JOHN CRISP Type Inj. S Type test P Type Inj. Type test Type Inj. Type test Type Inj. Type test Type Inj. Type test Test Details: Initial MITIA post injection start-up. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. MDIND 5,070' 4,456' Tubing 0 0 0 0 Interva I Test psi 1500 Casing 280 1610 1525 1485 P/F P MDIND Tubing Interva Test psi Casing P/F MDIND Tubing Interva Test psi Casing P/F MDIND Tubing Interva Test psi Casing P/F MDIND Tubing Interva Test psi Casing P/F TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT POL W-212 05-06-03.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) Revised: 05/06/03, Add Perfs & Corrections 1. Status of Well o Oil 0 Gas 0 Suspended 0 Abandoned I8J SelVice 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 906' SNL, 1185' WEL, SEC, 21, T11 N, R12E, UM At top of productive intelVal 4898' NSL, 4102' WEL, SEC. 22, T11 N, R12E, UM At total depth 4965' NSL, 3875' WEL, SEC. 22, T11 N, R12E, UM X = 614628, Y = 5959981 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 85.87' ADL 028263 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/4/2002 4/11/2002 3/25/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional SUlVey 6330 5510 FT 6212 5404 FT I8J Yes 0 No 22. Type Electric or Other Logs Run RES I AIT, DT / BHC, CNL, LDL, GR, X = 612049, Y = 5959351 Classification of SelVice Well Water Injection 7. Permit Number 202-066 8. API Number 50- 029-23078-00 9. Unit or Lease Name Prudhoe Bay Unit X = 614403, Y = 5959911 10. Well Number W-212i 11. Field and Pool Prudhoe Bay Field I Polaris Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2196 MD 1900' (Approx.) 23. CASING SIZE 20" 9-5/8" WT. PER FT. 91.5# 40# 26# GRADE H-40 L-80 L-80 Caliper, SP, MRES, MWD , DIR , GYRO, DEN, DGR , EWR , NEU CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 30" 35' 3411' 12-1/4" 32' 6320' 8-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 653 sx AS III Lite, 245 sx Class 'G' 355 sx Class 'G' AMOUNT PULLED 7" 24. Perforations open to Production (MD+ TVD of Top and Bottom and intelVal, size and number) 25. 2-7/8" Gun Diameter, 6 spf MD TVD 5962' - 5982' 5182' - 5199' 2-7/8" Gun Diameter, 2 spf MD TVD 5820' - 5842' 5058' - 5077' 5904' - 5924' 5131' - 5148' 5982' - 6002' 5199' - 5217' 6040' - 6060' 5250' - 5268' SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 5127' PACKER SET (MD) 5070' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL.USED Freeze Protected with 135 Bbls of Diesel 27. Date First Production May 5, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL TEST PERIOD CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Dt::CEi\/E~~ Brief description of lithology, porosity, fractures, apparent WR~œ~ce of oil, gas or water. Submit core ~ .í '" ~ \i' _ l..) ~'¡œ~1!~~Î No core samples were taken. ;':'..', ',c '. ~;;r ~'. MAY 0 6 ~~C: ( .~ / ~ ."/: .,.. 't~~ "u~~~.,'j- , L\\Hi':.t,.~)_ci~ Aia:3h8 ~.;:;\; !3,;,~~ ~;X,t. ·..>.ì¡;;::~~~~D;t RBDMS BFl ~4Y . _~..____' Ar~~t~r~:;~r "" 71nn~. .... ............ .'-' .~MU'iJ &/':: OIL-BBL GAs-McF WATER-BBL OIL GRAVITy-API (CORR) Form 10-407 Rev. 07-01-80 O,~,G N"Ä_ Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ma Mb1 Mb2 Mc Na Nb Nc OA OBa OBb OBc OBd OBe OBf o BCBase 5264' 5327' 5375' 5477' 5559' 5593' 5643' 5754' 5818' 5863' 5903' 5960' 6041' 6089' 6144' 4606' 4656' 4693' 4774' 4840' 4868' 4909' 5002' 5056' 5095' 5130' 5180' 5251' 5294' 5343' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~AAi.R 1 t1u~ Title Technical Assistant Date [) S-'" 0<0 ·O~ W-212i 202-066 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Walter Quay, 564-4178 Permit No. I Approval No. 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 , . ) ) Well: Field: API: Permit: W-212i Prudhoe Bay Unit 50-029-23078-00 202-066 Rig Accept: Rig Spud: Rig Release: Drilling Rig: 04/04/02 04/04/02 04/13/02 Doyon 14 POST RIG WORK 12/08/02 VERIFIED BPV STILL IN PLACE. PULLED BPV. PULLED BALL & ROD FROM XN PLUG @ 5088' SLM. ATTEMPT TO PULL RP VALVE FROM GLM # 1 (RAN KICKOVER TOOL WI 1 5/8" PULLING TOOL AND WOULDN'T LATCH GLV, PULLING TOOL HAS MARKS ON EACH SIDE INDICATING POSSIBLY 1" GLV). 12/09/02 PULL 1" BK RP SHEAR VALVE FROM GLM # 1. SET 1" BK, DGLV IN GLM # 1. PULL 4-1/2" RHC PLUG BODY DRIFTTBG & TAG FILL WI 12' LONG 3.5 DMY GN & SB @ 6184' WLMD. WELL TO REMAIN SHUT IN. 12/10/02 RIH WI SCMT, PSP. TAGGED TD 6205', LOGGED JEWELRY, SCMT AND REPEAT PASSES FROM TD UP TO 4950'. POOH. FOUND FAIR TO GOOD CEMENT FROM TD UP TO TUBING TAIL @ 5127'. NO MICRO ANNULUS SUSPECTED, PRESSI TEMP ADDED TO LOGS FOR FUTURE PERF. BHP=2752 PSI, BHT =91.1 DEG F, SHUT IN. 03/09/03 WELL SHUT IN ON ARRIVAL. DRIFT WI 20' 2.80 GUN. 03/10/03 DRIFT TO TD WI 20' 2.805 DG, 6190 SLM. PULL DGL STA # 1 @ 4967 SLM. STA #1 @ 4967 SLM IS LEFT OPEN TO UNLOAD WELL. NOTIFY PAD OP, LEFT WELL SHUT IN. 03/14/03 FOUND WELL SHUT IN ON ARRIVAL. BEGIN RIGGING UP. 03/15/03 RAN 4-1/2" XN CATCHER SUB. SET @ 5096' SLM. RAN 4-1/2" OK-6 & 1" DV (BK) TO STA 1 @ 4967' SLM & SET. PULLED 4-1/2" XN CATCHER FROM 5096' SLM. RIG DOWN. NOTIFIED DSO OF WELL STATUS. WELL LEFT SHUT IN. 03/22/03 T/1/0=400/430/10 MONITOR WHP'S. TBG FL AT 4750'. IA FL AT 4950'. IA HAS 2" HARDLlNE TEE AND IA COMPANION VALVE. 03/23/03 T/lIO = 400/440180. PRESSURE TBG TO 1100 PSI. (PREP FOR PERF JOB, E-LlNE). TBG FL @ 4950'. TIED INTO AL JUMPER LINE FROM ADJACENT WELL TO PRESSURE TBG THROUGHT TREE CAP. PRESSURED TBG TO 1100 PSI IN 45 MIN. MONITORED FOR 15 MIN. FINAL WHP'S = 1100/450/80. 03/25/03 PERFORATED FROM 5962-5982' MD WI 2-7/8" X 20' 6-SPF PJ-2906 HSD GUN. TIED INTO SWS SCMT LOG DATED 10-DEC-02. NO PROBLEMS RIH OR POOH. TAGGED TD @ 6214' MD. WHP = 1100 PSI BEFORE FIRING AND AFTER TOOL AT SURFACE. LEFT WELL SHUT IN. 04/22/03 T/I/O=1420/500/120 BLEED TBG (PREP FOR E-LlNE) TBG FL @ 4982' (ST # 1). BLED TBG FROM 1420 PSI TO 440 PSI IN 1.5 HRS. TBG FL ROSE TO 3000'. MONITORED TP FOR 30 MINS, TP STAYED THE SAME. FINAL WHP'S 440/500/120. W-212, Post Drill Work Summary Page 2 ) ) 04/24/03 COLLECT OIL PHASE SAMPLE @ 4600' MD. SBHPS. CORRELATE TO SWS SCMT LOG DATED 10-DEC-02. LOG FROM SURFACE TO 6040' @ 120 FPM. GAS TO 3170', WATER 4915'. STOP COUNTS @ 6000' MD, PRESSURE=2140.0 PSI, TEMPERATURE=97.5 DEGF. STOP @4600' FOR OILPHASE SAMPLE. WELL SHUT IN. 04/26/03 PULL 1" DGLV FROM STA # 1. SET DGLV IN STA # 1, LITTLE RED MITIA (PASSED), UNABLE TO GET DOWN TO CATCHER SUB DUE TO HYDRATES @ 2782' SLM (NO PUMP TRUCK AVAILABLE). RDMO. WELL LEFT SHUT IN. 4 1/2" WHIDDON CATCHER LEFT IN HOLE @ 5087'SLM. 04/27/03 HYDRATES IN TUBING. PUMPED 10 BBLS NEAT MEOH, 90 BBLS CRUDE @ 180°,20 BBLS NEAT MEOH. PULLED 4 1/2 WHIDDON CATCHER SUB FROM 5087' SLM. LEFT WELL SHUT IN. 04/29/03 PERFORATED 6040'-6060', 5982'-6002', 5904'-5924' AND 5820'·5842'. CORRELATE TO SWS SCMT LOG DATED 10-DEC-2002. GUN SIZE 2 7/8,2 SPF 180 DEGREES, POWERJET 2906, CHARGE DATA: EH 0.32", PENE 28.1", ORIENTED +1- 90 DEGREES FROM BOTTOM OF HOLE. WELL SHUT IN. 05/04/03 SBHPS WI PETREDAT GAUGES & TWO MRT'S. 10 MIN LUB STOP TEST GAUGE 400#. 40 MIN STOP @ 5852' ELM 5000' TVD. 20 MIN STOP @ 5752' ELM 4914' TVD. 20 MIN STOP @ 5652' ELM 4830' TVD. 20 MIN STOP @ 5752' ELM 4914' TVD. 10 MIN LUB STOP TEST GAUGE 390#. TOP MRT 104 DEG I BTM MRT 100 DEG. TAG TD @ 6175' CORR TO ELM. GOOD DATA. PRESSURES WILL BE ADDED LATER. WELL TO BE PLACED ON INJECTION. 05/05/03 TIIIO = 12201400/280, IA FL @ 150' PREP FOR AOGCC WITNESSED TEST. ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well o Oil 0 Gas 0 Suspended 0 Abandoned IB1 Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-066 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23078-00 4. Location of well at surface 9. Unit or Lease Name 906' SNL, 1185' WEL, SEC, 21, T11 N, R12E, UM X = 612049, Y = 5959351 Prudhoe Bay Unit .,.LÄt top of productive interval t:r~17' NSL, 4034' WEL, SEC. 22, T11 N, R12E, UM X = 614470, Y = 5959931 '10. Well Number L~L At total depth ~15 ß,P L.) .A95zrNSI, 3921' WEL, SEC. 22, T11 N, R12E, UM X = 614628, Y = 5959981 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKB = 85.87' ADL 028263 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/4/2002 4/11/2002 3/25/2003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 6330 5510 FT 6212 5404 FT IB1 Yes 0 No 22. Type Electric or Other Logs Run RES I AIT, DT I BHC, CNL, LDL, GR, W-212i 11. Field and Pool Prudhoe Bay Field I Polaris Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2196 MD 1900' (Approx.) 23. CASING SIZE WT. PER FT. GRADE 20" 91.5# H-40 9-5/8" 40# L-80 7" 26# L-80 Caliper, SP, MRES, MWD, DIR, GYRO, DEN, DGR, EWR, NEU CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 30" 35' 3411' 12-1/4" 32' 6320' 8-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 653 sx AS III Lite, 245 sx Class 'G' 355 sx Class 'G' AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 spf MD TVD MD TVD 5962' - 5982' 5182' - 5199' SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 5127' PACKER SET (MD) 5070' 25. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 135 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl TEST PERIOD Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE ~8. Brief description of lithology, porosity, fractures, apparent dips a~~;~~~:: of oil, gas or water. Submit core ch6E C E IV[ D 27. Date First Production April 12, 2003 Date of Test Hours Tested CHOKE SIZE GAS-Oil RATIO No core samples were taken. APR 3 0 2003 BIAS BFL MAY '~. ..",.":..rvr\¥'V......~,3t. .' ;Jtœ.~~~~ ;1!I~,1 1 21\1 ,.~, ..' . '··-'l. ~&~,__'1:' 1" . . "';:1. . " ; ~ :~.:.. ,,_' II J;, ,,'-1 .. ,"",""..".-', .:" ~',,:, .'...,.:..... ....,''"\...,.~ .."'I'" ., .', .. . , '·0' ; ; ø3' ~_¿L¿..s:. .- .. : .. ..··/tj/i2·· .". : ;~t-_'d ,: Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 " , r'tNAL u ~,.< ¡ 0 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Ma Mb1 Mb2 Mc Na Nb Nc OA OBa OBb OBc OBd OBe OBf OBCBase 5264' 5327' 5375' 5477' 5559' 5593' 5643' 5754' 5818' 5863' 5903' 5960' 6041' 6089' 6144' 4606' 4656' 4693' 4774' 4840' 4868' 4909' 5002' 5056' 5095' 5130' 5180' 5251' 5294' 5343' RECEIVED APR 3 0 2003 0·, & Gas Cons. Commission A\aska , Anchorage 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble --rc;.N\.Í.JL t:lu ß-6e( Title Technical Assistant Date fi..f.;;t 9· 03 W-212i 202-066 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Walter Quay, 564-4178 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. 17EM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 U,-<,G'~\!AL Legal Name: W-212i Common Name: W-212i Test Date 4/10/2002 Test Type FIT Test Depth (TMD) 3,440.0 (ft) ......B...........p.........................E................~....................................p..............~....t..........··..·.........0......·..............................RA.......·.·.............................................:tr-...................I.......(1).............................N...........................................................................;......................................... ._n ".". _ _. _._"0 .. I..t:tak~Offi··.JeS~SºITlITlªry Test Depth(TVD) 3,171.0 (ft) AMW 9.30 (ppg) Surface Pl'eSSutê leakÖffPre$Sure·C$HÞ} 450 (psi) 1,982 (psi) EMW 12.03 (ppg) ---. .~ Printed: 4/15/2002 8:47: 15 AM ) ) BP'I=X'PL()RJ.\TION Operation~ Summa.-yRèpórt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-212i W-212i DRILL +COMPLETE DOYON DOYON 14 lDaté Frol11- To Hours ~c~ivity Cödé· NPT P~åse 4/3/2002 03:00 - 08:00 5.00 MOB P PRE 08:00 - 23:00 15.00 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 4/4/2002 00:00 - 02:00 2.00 MOB P PRE 02:00 - 03:00 1.00 RIGU P PRE 03:00 - 08:00 5.00 RIGU P PRE 4/5/2002 08:00 - 12:00 4.00 RIGU P PRE 12:00 - 13:30 1.50 RIGU P PRE 13:30 - 17:30 4.00 RIGU P PRE 17:30 - 19:00 1.50 RIGU P PRE 19:00 - 20:00 1.00 RIGU P PRE 20:00 - 20:30 0.50 RIGU P PRE 20:30 - 21 :30 1.00 DRILL P SURF 21 :30 - 22:00 0.50 DRILL P SURF 22:00 - 00:00 2.00 DRILL P SURF 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 03:00 1.00 DRILL P SURF 03:00 - 12:00 9.00 DRILL P SURF 12:00 - 00:00 12.00 DRILL P SURF 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 02:00 1.50 DRILL P SURF 4/6/2002 02:00 - 12:00 10.00 DRILL P SURF 12:00 - 14:00 2.00 DRILL P SURF 14:00 - 14:30 0.50 DRILL P SURF 14:30 - 16:00 1.50 DRILL P SURF 16:00 - 18:00 2.00 DRILL P SURF 18:00 - 19:30 1.50 DRILL P SURF 19:30 - 21 :30 2.00 DRILL P SURF 21 :30 - 22:00 0.50 DRILL P SURF 22:00 - 22:30 0.50 DRILL P SURF 22:30 - 00:00 1.50 DRILL P SURF 41712002 00:00 - 00:30 0.50 DRILL P SURF Start: 4/3/2002 Rig Release: 4/13/2002 Rig Number: 14 Spud Date: 4/4/2002 End: 4/13/2002 De$criþtiÇ)n' qf·.··Op~rati9ns Prepare rig for move, install booster wheels Move rig from NWE 4-01 to W212i Spot rig over well center Spot rig over conductor, center and level rig. PJSM, cantilever derrick to position. Rig accepted at 02:00 hrs, April 4, 2002 Rig up to spud MU diverter to knife spool, set on conductor, MU diverter line Modify riser, add 8" to top, due to excessive gravel lift on location Load pipe shed wI HWDP, DP, BHA, strap same Install turn buckles on riser, change jaws in top drive PU 105 jts 5" DP, rack in derrick PU 20 jts 5" HWDP, jars, rack in derrick Function test diverter, koomey unit AOGCC waived witness Fill diverter wI mud, check for leaks Drill 121/4" surface wellbore from 34' to 110', frozen fluids, formation from 110' to 183' Trip out, lay down BHA # 1 PU, MU, directional BHA # 2 Drill 12 1/4 hole from 183 to 332. RU for gryo survey, survey at 233' Directional drill 12 1/4" wellbore from 332' to 923' AST 1.75, ART 5.12, ADT 6.87 Directional drill 12 1/4" wellbore from 923' to 2000' AST 4.58, ART 5.20, ADT 9.78 Circulate bottoms up, flow check Short trip from 2000' to 780', wellbore in good condition, proper fill up, Two slightly sticky spots on trip in, no wash or ream needed Directional drill 12 1/4" surface wellbore from 2000' to 3273' AST 2.37, ART 4.62, ADT 6.99 Directional drill wellbore from 3273' to 3420', TD surface wellbore AST 0.16, ART 1.09, ADT 1.24 Circulate bottoms up, flow check Short trip from 3420' to 1850', wellbore in good condition Circulate sweep from surface to surface, allow shakers to clean up, Drop ESS tool for JORPS survey Trip out, wellbore in good condition Flush tools, rack back NMDCs, LD ESS tool, LD MWD, LD BHA Clear rig floor PJSM, RU wireline unit, RIH wI logs Logs unable to pass by 1060' wI PEX I BHCS, POOH wI logs, reconfigure tool setup, RIH wI PEX, again unable to pass by 1060' Reconfigure logging tools, drop off BHCS tool Printed: 4/15/2002 8:47:23 AM ) ) BPEXPLQRATIO~ ·Pagè2'of!ii "Oþé'rå,~iOIÎ$ Sutr'l'mitry:Réport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-212i W-212i DRILL +COMPLETE DOYON DOYON 14 Start: 4/3/2002 Rig Release: 4/13/2002 Rig Number: 14 Spud Date: 4/4/2002 End: 4/13/2002 Date .. Frorn - To Hours Activity Code NPT··· Phase' De$èripti~nof Oþerat,iÒns 4/7/2002 00:30 - 01 :00 0.50 DRILL P SURF Run logs to 1055', unable to pass by, log w/ PEX to surface 01 :00 - 03:00 2.00 DRILL P SURF LD logging tools, nuclear sources, wireline sheeves 03:00 - 03:30 0.50 DRILL P SURF Clear rig floor 03:30 - 05:30 2.00 DRILL P SURF Rig up to run 9 5/8" casing 05:30 - 08:00 2.50 DRILL P SURF PJSM, run 95/8" casing to 1025', 26 jts 08:00 - 10:00 2.00 DRILL P SURF Work casing, pump at 6 bpm to 320 psi, PU 90,000, sow 90,000 Unable to circulate by 1025'. Lots of wood and small gravel seen at shakers. 10:00 - 15:30 5.50 DRILL N DPRB SURF Pull casing and LD same to pipe shed 15:30 - 16:30 1.00 DRILL N DPRB SURF Clear rig floor, LD casing equipment, Franks tool, C/O bales 16:30 - 18:30 2.00 DRILL N DPRB SURF Pu, MU directional BHA 18:30 - 19:00 0.50 DRILL N DPRB SURF Trip in to 980', tag obstruction, break circulation, orient tool face 19:00 - 21 :00 2.00 DRILL N DPRB SURF Wash, ream from 1000' to 1356.' 21 :00 - 22:30 1.50 DRILL N DPRB SURF Wiper trip back to 973', trip in to 1356'. 22:30 - 00:00 1.50 DRILL N DPRB SURF Wash, ream from 1356' to 2600', able to trip in with out pump or rotation for some periods of time, others needed pump and rotation, indications of wellbore that the bit is chasing an object down hole 4/8/2002 00:00 - 01 :30 1.50 DRILL N DPRB SURF Wash, ream to bottom, 3420' 01 :30 - 04:00 2.50 DRILL N DPRB SURF Circulate wellbore clean with 2ea., 40 bbl. sweeps. No significant increase in cuttings after initial bottoms up. 04:00 - 08:30 4.50 DRILL N DPRB SURF POOH, at 2975' pump and backream out to 2311' w/ 14 bpm at 1480 psi at 60 rpm, pump out from 2311' to 1257' at 720 psi at 9.5 bpm, POOH from 1257' to 780'. (short trip from 900 to 1200 on trip out--no sign of downward resistance) 08:30 - 10:00 1.50 DRILL N DPRB SURF Rack back HWDP, LD probe, rack NMDCs, flush tools, LD stab, pony DC, motor, bit 10:00 - 10:30 0.50 DRILL N DPRB SURF Clear rig floor 10:30 - 13:00 2.50 DRILL N DPRB SURF Rig up to run 9 5/8" casing 13:00 - 13:30 0.50 DRILL N DPRB SURF PJSM, MU casing shoe and float collar, check same 13:30 - 15:00 1.50 DRILL N DPRB SURF Run 26 jts casing to 1025' 15:00 - 18:30 3.50 DRILL P SURF Run casing to 2500', break circulation, circulate and work casing down, 83 jts total run, set at 3409' 18:30 - 19:00 0.50 DRILL P SURF MU landing jt, land casing, 19:00 - 20:00 1.00 DRILL P SURF Circulate and condition mud properties for cementing, P JSM w/ cementers 20:00 - 21 :00 1.00 DRILL P SURF RD Franks tool, MU cement head, break circulation Loading of plugs witnessed by BP rep 21 :00 - 23:30 2.50 DRILL P SURF Cement as per program, approx 180 bbls of cement to surface 23:30 - 00:00 0.50 DRILL P SURF Check floats, RD cement head, LD cement tools 4/9/2002 00:00 - 02:00 2.00 DRILL P SURF LD cement head, LD landing jt, casing tools Flush diverter 02:00 - 04:00 2.00 DRILL P SURF Nipple down diverter 04:00 - 04:30 0.50 DRILL P INT1 Nipple up starting head, tubing spool, pressure test to 1000 psi for 10 minutes 04:30 - 07:30 3.00 DRILL P INT1 Nipple up BOPE 07:30 - 08:00 0.50 DRILL P INT1 Rig up to pressure test BOPE Printed: 4/15/2002 8:47:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ]Jàte ) ) BP EXPLORJ.\TIQNJ C1perå,tió;l1s Sum:.ru~rÿtlR:f!þo,rt, 4.50 DRILL P 0.50 DRILL P 1.00 DRILL P 4.00 DRILL P 0.50 DRILL P 2.00 DRILL P 1.50 DRILL P 1.00 DRILL P 1.00 DRILL P 1.00 DRILL P 0.50 DRILL P 0.50 DRILL P 10.00 DRILL P 0.50 DRILL P 1.00 DRILL P 1.00 DRILL P 1.50 DRILL P 2.50 DRILL N 1.50 DRILL N 3.00 DRILL N 1.00 DRILL N 1.50 DRILL N 0.50 DRILL P 2.50 DRILL N 0.50 DRILL N 7.00 DRILL P 1.50 DRILL P 0.50 DRILL P 2.50 DRILL P 0.50 DRILL P 1.00 DRILL P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INn INT1 INT1 INT1 INT1 INn INT1 DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 DFAL INn INT1 RREP INT1 DFAL INT1 INT1 INT1 INn INT1 INT1 INT1 Start: 4/3/2002 Rig Release: 4/13/2002 Rig Number: 14 Spud Date: 4/4/2002 End: 4/13/2002 W-212i W-212i DRILL +COMPLETE DOYON DOYON 14 4/9/2002 08:00 - 12:30 Front~Tó ,Holjrs Activity <Code NPT Phase? 12:30 - 13:00 13:00 -14:00 14:00 - 18:00 18:00 - 18:30 18:30 - 20:30 20:30 - 22:00 4/10/2002 22:00 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:00 02:00 - 12:00 12:00 - 12:30 12:30 - 13:30 13:30 - 14:30 14:30 - 16:00 16:00 - 18:30 18:30 - 20:00 20:00 - 23:00 4/11/2002 23:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 04:30 04:30 - 05:00 05:00 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 16:30 16:30 - 17:00 17:00 - 18:00 £:>escription,:ófOþera~i9ns Pressure test BOPE as per AOGCC / BP regulations Witness waived by AOGCC rep Jeff Jones Pull test plug, run wear bushing Pressure test casing to 3000 psi to confirm TAM collar closed PU bales, blow down choke / kill lines Take on new mud PU, MU, BHA, PJSM, load sources in MWD, RIH HWDP, surface test MWD, 2 hours testing and uploading MWD Single in, rotate through TAM collar, pressure test casing to 3000 psi, confirm TAM collar closed Single in, wash down from 3310' to 3320' Rig service, slip / cut drilling line, double cut, service top drive Pressure test casing to 4000 psi for 30 minutes, charted Drill cement from float collar 3324' to 3404' Drill out float shoe, directional drill from 3420' to 3440' Circulate bottoms up, mud in / out 9.3 ppg FIT to 12 ppg, surface pressure 450 psi Directional drill 8 3/4" wellbore from 3440' to 5020' AST 0.85, ART 5.27, ADT 6.12 Directional drill from 5020' to 5129' Circulate sweep, survey, SPRs, flow check Wiper trip from 5129' to 3396' Wellbore in good condition Directional drill from 5129' to 5160' AST 0, ART 0.49, ADT 0.49 MWD failure Flow check, POOH 5 stds, flow check, pump dry job, POOH to shoe, flow check, POOH HWDP, flow check PJSM, remove sources, download MWD, C/O MWD probe, check bit Program MWD, shallow test MWD, PJSM, load sources, RIH BHA Trip in to 2160' Trip in from 2160' to 3402', fill pipe, test MWD Rig service, IBOP not functioning correct Rig repair, IBOP, electrical connections repaired Trip in from 3402' to 5160' Wellbore in good condition Directional drill 83/4" wellbore from 5160' to 5895' AST 0.91, ART 3.59, ADT 4.5 Directional drill from 5895' to 6085' H2S alarm, secure well, evacuate rig, all hands reported to muster area, all levels of rig checked w/ gas detectors, no H2s detected Directional drill from 6085' to 6330' TD AST 0.48, ART 2, ADT 2.48 Pump sweep on the fly Circulate sweep, circulate untill shakers clean Wiper trip from 6330' to 5033' Wellbore in good condition Printed: 4/15/2002 8:47:23 AM ) ) BP'EXPL.:ORATION Qperations S;ummarY: Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-212i W-212i DRILL +COMPLETE DOYON DOYON 14 Date From - To Houl"sActivity Code NPT Phase 4/11/2002 18:00 - 20:00 2.00 DRILL P INT1 20:00 - 00:00 4.00 DRILL P INT1 4/12/2002 00:00 - 03:00 3.00 DRILL P 03:00 - 03:30 0.50 DRILL P 03:30 - 04:00 0.50 CASE P 04:00 - 05:30 1.50 CASE P 05:30 - 10:00 4.50 CASE P 10:00 - 10:30 0.50 CASE P 10:30 - 13:30 3.00 CASE P 13:30 -14:00 0.50 CASE P 14:00 - 15:00 1.00 CEMT P 15:00 - 17:00 2.00 CEMT P 17:00 - 17:30 0.50 CEMT P 17:30 - 18:30 1.00 CASE P 18:30 - 19:30 1.00 CASE P 19:30 - 23:30 4.00 CASE P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INn INT1 INT1 INT1 INT1 4/13/2002 23:30 - 00:00 00:00 - 01 :00 01 :00 - 10:00 0.50 RUNCOIVP 1.00 RUNCOIVP 9.00 RUNCOIVP COMP COMP COMP 10:00 - 11 :00 1.00 RUNCOIVP COMP 11 :00 - 12:00 1.00 RUNCOIVP COMP 12:00 - 13:30 1.50 RUNCOIVP COMP 13:30 - 14:00 0.50 RUNCOIVP COMP 14:00 - 15:00 1.00 RUNCOIVP COMP 15:00 - 17:00 2.00 RUNCOIVP COMP Start: 4/3/2002 Rig Release: 4/13/2002 Rig Number: 14 Spud Date: 4/4/2002 End: 4/13/2002 Des¢rjp~jÞn ofOperatjón~ Circulate sweep, circulate untill shakers clean, drop ESS for JORPS survey, flow check, pump dry job Trip out, 10 stands flow check, POOH, 15 stands flow check, POOH LOOP Flow check at shoe LD HWDP, jars, flush tools, PJSM, remove sources, retieve ESS, rack stand of NMDCs in derrick, download MWD, LD MWD, probe, motor, bit Clear rig floor Pull wear bushing Rig up to run 7" casing Run 7", 26 #, L-80, BTC, to casing shoe, 3410' Break circulation, circulate at 9 bpm at 1060 psi, no losses Run 7" casing to 6319' Break circulation, circ at 8 bpm at 920 psi, stage up to 9 bpm at 1 060 psi No losses Rig down Franks tool, rig up cement head, circulate casing PJSM wI cementers, batch cement Cement 7" casing as per program Did not bump plug at proper displacement Floats held Rig down cement head, landing joint PU running tool, set pack off, pressure test to 5000 psi for 10 minutes LD casing equipment, CO bales Rig up slickline, run in to tag cement plug at 6212', rig down slickline Freeze protect outer annlus wI 60 bbls diesel Pump diesel at 2 bpm at 1060 psi Rig up to run 4 1/2" completion string Rig up to run 4 1/2" completion string Run 4 1/2", 12.6 #, L-80, TC 11 tubing as per program Torque turn chart on each connection Some threads on pin end, some collars slight damage, These threads and collars repaired in pipe shed and floor M/U tubing hanger, landing jt, land tubing, torque up LOS Tubing, 110K up, 95K down Rig up test manifold Circulate seawater wI corexit Drop ball wI rod, set packer at 2500 psi, pressure test tubing to 4000 psi for 30 minutes, bled tubing to 1500 psi, pressure test annlus to 4000 psi for 30 minutes, bled tubing down, shear RP Rig down landing jt, install TWC, pressure test from below to 1000 psi, 10 minutes Nipple down BOPE, circulating lines, pressure test equipment C/O saver sub, service loop on top drive off critical path Dress tubing hanger, install SBMS, N/U tree, pressure test to 5000 psi and 250 psi each for 10 minutes Printed: 4/15/2002 8:47:23 AM ) ') BP EXPLO.RATIQN OperatiônsSuri'lm':êlry·Re.þort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .~.. bate 4/13/2002 W-212i W-212i DRILL +COMPLETE DOYON DOYON 14 From'- To :HOUrs: ActiVitY Code' NPT Phase' 17:00 - 18:00 1.00 RUNCOM> COMP 18:00 - 18:30 0.50 RUNCOM> COMP 18:30 - 20:30 2.00 RUNCOM> COMP 20:30 - 22:00 1.50 RUNCOM> COMP 22:00 - 23:00 1.00 WHSUR P COMP 23:00 - 00:00 1.00 RIGD P COMP Page 5 öf.5 Start: 4/3/2002 Rig Release: 4/13/2002 Rig Number: 14 Spud Date: 4/4/2002 End: 4/13/2002 p~$Criptionof 'Operations RIU DSM, pull TWC, RID DSM RIU hard lines to freeze protect Freeze protect wI Little Red, pump 75 bbls at 2.5 bpm, 1550 psi, Allow wellbore to U tube Install BPV, pressure test to 1000 psi for 10 minutes, RID hard lines and manifold Secure wellhead, remove all fluids from mud tanks, clean tanks Police area of all debris, clean out cellar, prepare to move Printed: 4/1512002 8:47:23 AM ) ') Well: Field: API: Permit: W-212i Prudhoe Bay Unit 50-029-23078-00 202-066 Rig Accept: Rig Spud: Rig Release: Drilling Rig: 04/04/02 04/04/02 04/13/02 Doyon 14 POST RIG WORK 12/08/02 VERIFIED BPV STILL IN PLACE. PULLED BPV. PULLED BALL & ROD FROM XN PLUG @ 50881 SLM. ATTEMPT TO PULL RP VALVE FROM GLM # 1 (RAN KICKOVER TOOL WI 1 5/8" PULLING TOOL AND WOULDNT LATCH GLV, PULLING TOOL HAS MARKS ON EACH SIDE INDICATING POSSIBLY 1" GLV). 12/09/02 PULL 1" BK RP SHEAR VALVE FROM GLM # 1. SET 1" BK, DGLV IN GLM # 1. PULL 4-1/2" RHC PLUG BODY DRIFT TBG & TAG FILL WI 121 LONG 3.5 DMY GN & SB @ 61841 WLMD. WELL TO REMAIN SHUT IN. 12/10/02 RIH WI SCMT, PSP. TAGGED TD 6205'. LOGGED JEWELRY, SCMT AND REPEAT PASSES FROM TD UP TO 49501. POOH. FOUND FAIR TO GOOD CEMENT FROM TD UP TO TUBING TAIL @ 5121'. NO MICRO ANNULUS SUSPECTED, PRESSI TEMP ADDED TO LOGS FOR FUTURE PERF. BHP=2752 PSI, BHT =91.1 DEG F, SHUT IN. 03/09/03 WELL SHUT IN ON ARRIVAL. DRIFT WI 2012.80 GUN. 03/10/03 DRIFT TO TD WI 2012.805 DG, 6190 SLM. PULL DGL STA # 1 @ 4967 SLM. STA #1 @ 4967 SLM IS LEFT OPEN TO UNLOAD WELL. NOTIFY PAD OP, LEFTWELL SHUT IN. 03/14/03 FOUND WELL SHUT IN ON ARRIVAL. BEGIN RIGGING UP. 03/15/03 RAN 4-1/2" XN CATCHER SUB. SET @ 50961 SLM. RAN 4-1/2" OK-6 & 1" DV (BK) TO STA 1 @ 4961' SLM & SET. PULLED 4-1/2" XN CATCHER FROM 50961 SLM. RIG DOWN. NOTIFIED DSO OF WELL STATUS. WELL LEFT SHUT IN. 03/22/03 T/I/O=400/430/10 MONITOR WHpIS. TBG FL AT 4750'. IA FL AT 49501. IA HAS 2" HARDLlNE TEE AND IA COMPANION VALVE. 03/23/03 T/l/O = 400/440/80. PRESSURE TBG TO 1100 PSI. (PREP FOR PERF JOB, E-LlNE). TBG FL @ 49501. TIED INTO AL JUMPER LINE FROM ADJACENT WELL TO PRESSURE TBG THROUGHT TREE CAP. PRESSURED TBG TO 1100 PSI IN 45 MIN. MONITORED FOR 15 MIN. FINAL WHplS = 1100/450/80. 03/25/03 PERFORATED FROM 5962-59821 MD WI 2-7/8" X 201 6-SPF PJ-2906 HSD GUN. TIED INTO SWS SCMT LOG DATED 10-DEC-02. NO PROBLEMS RIH OR POOH. TAGGED TD @ 62141 MD. WHP = 1100 PSI BEFORE FIRING AND AFTER TOOL AT SURFACE. LEFT WELL SHUT IN. ~ad.. 0'00 19-Apr-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well W-212 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD (if applicable) 6,330.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ,. s:) 2 (., ,.,002 /-.:" 0 L. AJaalœœ&GasCons.CommiaIon And10rage North Slope Alaska BPXA PBU_WOA W Pad, Slot W-212 W-212 Job No. AKMW22060, Surveyed: 11 April, 2002 SURVEY REPORT 19 April, 2002 DEFINITIVE Your Ref: API # 500292307800 Surface Coordinates: 5959350.99 N, 612049.03 E (70017' 52.4088" N, 149005' 33.3395" W) Kelly Bushing: 85.87ft above Mean Sea Level ~ ......\1-......, DRILLING ....VICs. A Halliburton Company ~~.-' Survey Ref: svy11176 Sperry-Sun Drilling Services DEF/N~"TIVE . Survey Report for W..212 Your Ref: API # 500292fó1800 Job No. AKMW22060, Surveyed: 11 April, 2002 BPXA North Slope Alaska PBU_WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100tt) 0.00 0.000 0.000 -85.87 0.00 0.00 N 0.00 E 5959350.99 N 612049.03 E 0.00 MWD Magnetic 168.37 0.460 355.000 82.50 168.37 0.67 N O.06W 5959351.66 N 612048.96 E 0.273 0.09 223.00 0.200 280.000 137.13 223.00 0.91 N 0.17W 5959351.90 N 612048.84 E 0.827 0.03 347.89 0.650 295.800 262.01 347.88 1.25 N 1.02W 5959352.23 N 612047.99 E 0.369 -0.72 436.70 0.570 274.850 350.82 436.69 1.51 N 1.92W 5959352.47 N 612047.09 E 0.265 -1.53 525.93 0.540 17.030 440.05 525.92 1.95 N 2.24W 5959352.91 N 612046.76 E 0.968 -1.75 614.88 1.830 78.350 528.98 614.85 2.64N O.72W 5959353.62 N 612048.27 E 1.845 -0.12 703.76 2.680 77.070 617.79 703.66 3.39N 2.69E 5959354.42 N 612051.67 E 0.958 3.38 799.30 3.430 81.340 713.19 799.06 4.32 N 7.69E 5959355.42 N 612056.66 E 0.820 8.46 898.44 3.570 88.900 812.15 898.02 4.83N 13.71 E 5959356.02 N 612062.67 E 0.486 14.44 993.88 3.090 102.660 907.43 993.30 4.32N 19.19 E 5959355.59 N 612068.16 E 0.973 19.67 1089.29 3.970 102.060 1002.66 1088.53 3.07N 24.93 E 5959354.43 N 612073.91 E 0.923 24.99 1185.62 4.970 96.190 1098.69 1184.56 1.92 N 32.34 E 5959353.39 N 612081.34 E 1.140 31.96 1281.66 6.170 96.090 1194.28 1280.15 0.92 N 41.61 E 5959352.53 N 612090.62 E 1 .250 40.77 1376.69 8.450 93.980 1288.53 1374.40 0.105 53.66 E 5959351.69 N 612102.68 E 2.415 52.28 1472.85 9.600 88.060 1383.50 1469.37 0.325 68.72 E 5959351.69 N 612117.74 E 1.536 66.92 1568.75 10.900 87.440 1477.87 1563.74 0.35 N 85.77 E 5959352.62 N 612134.78 E 1.360 83.69 1664.35 11 .790 87.360 1571.60 1657.47 1.21 N 104.56 E 5959353.76 N 612153.56 E 0.931 102.20 1760.23 12.970 89.420 1665.25 1751.12 1.77 N 125.10 E 5959354.62 N 612174.09 E 1.314 122.35 1856.36 15.630 90.710 1758.39 1844.26 1.72 N 148.84 E 5959354.92 N 612197.83 E 2.787 145.48 1951.46 16.020 89.110 1849.89 1935.76 1.76 N 174.77 E 5959355.36 N 612223.76 E 0.615 170.77 2047.30 17.530 86.260 1941.65 2027.52 2.91 N 202.40 E 5959356.91 N 612251.36 E 1.794 197.96 2142.46 19.520 86.060 2031.87 2117.74 4.93N 232.56 E 5959359.39 N 612281.49 E 2.092 227.82 2238.42 23.760 83.570 2121.05 2206.92 8.20N 267.78 E 5959363.18 N 612316.66 E 4.520 262.88 2334.28 28.150 81.210 2207.22 2293.09 13.82 N 309.34 E 5959369.42 N 612358.13 E 4.704 304.65 2430.06 32.380 78.250 2289.93 2375.80 22.50 N 356.80 E 5959378.81 N 612405.46 E 4.682 352.85 2526.23 34.160 76.570 2370.34 2456.21 34.02 N 408.28 E 5959391.09 N 612456.76 E 2.084 405.60 2621.77 35.750 77.700 2448.64 2534.51 46.20 N 461.65 E 5959404.06 N 612509.94 E 1.797 460.34 2717.16 35.950 76.710 2525.96 2611.83 58.57 N 516.12 E 5959417.25 N 612564.22 E 0.643 516.20 2813.69 35.990 77.700 2604.09 2689.96 71.13 N 571.41 E 5959430.63 N 612619.32 E 0.604 572.90 ------------- 19 April, 2002 - 16:57 Page 20f5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for W-212 Your Ref: API # 500292307800 Job No. AKMW22060, Surveyed: 11 April, 2002 BPXA North Slope Alaska PBU_WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2908.86 37.260 76.190 2680.47 2766.34 83.96 N 626.71 E 5959444.28 N 612674.42 E 1.636 629.67 3004.57 37.260 73.710 2756.64 2842.51 99.00 N 682.66 E 5959460.16 N 612730.14 E 1.569 687.56 3100.68 37.610 73.130 2832.96 2918.83 115.68 N 738.65 E 5959477.67 N 612785.88 E 0.517 745.86 - 3197.11 37.590 73.440 2909.36 2995.23 132.60 N 795.00 E 5959495.43 N 612841.97 E 0.197 804.57 3294.21 38.460 73.870 2985.85 3071.72 149.43 N 852.40 E 5959513.11 N 612899.11 E 0.937 864.27 3347.33 38.210 73.790 3027.52 3113.39 158.60 N 884.04 E 5959522.76 N 612930.61 E 0.480 897.16 3469.20 37.210 74.720 3123.93 3209.80 178.84 N 955.79 E 5959544.06 N 613002.04 E 0.944 971.61 3530.76 37.040 74.740 3173.01 3258.88 188.62 N 991.63 E 5959554.38 N 613037.74 E 0.277 1008.73 3627.84 36.670 74.120 3250.69 3336.56 204.25 N 1047.72 E 5959570.84 N 613093.59 E 0.540 1066.89 3723.61 35.730 73.820 3327.97 3413.84 219.87 N 1102.08 E 5959587.26 N 613147.71 E 0.999 1123.37 3818.83 36.500 76.380 3404.90 3490.77 234.28 N 1156.31 E 5959602.49 N 613201.72 E 1.779 1179.45 3914.70 38.280 76.860 3481.07 3566.94 247.75 N 1212.95 E 5959616.80 N 613258.15 E 1.881 1237.66 4011.12 37.820 77.080 3557.00 3642.87 261.15 N 1270.84 E 5959631.06 N 613315.84 E 0.497 1297.09 4107.09 37.100 77 .150 3633.17 3719.04 274.17 N 1327.74 E 5959644.92 N 613372.54 E 0.752 1355.46 4202.86 39.500 78.230 3708.33 3794.20 286.81 N 1385.73 E 5959658.42 N 613430.33 E 2.602 1414.80 4299.10 39.700 78.950 3782.48 3868.35 298.94 N 1445.86 E 5959671.45 N 613490.28 E 0.520 1476.13 4394.71 39.470 78.460 3856.17 3942.04 310.87 N 1505.61 E 5959684.28 N 613549.84 E 0.406 1537.03 4490.71 41.330 77.830 3929.27 4015.14 323.66 N 1566.50 E 5959697.97 N 613610.53 E 1.984 1599.23 4585.15 40.960 79.000 4000.39 4086.26 336.14 N 1627.37 E 5959711.36 N 613671.20 E 0.904 1661.36 4682.61 40.980 76.150 4073.98 4159.85 349.89 N 1689.76 E 5959726.03 N 613733.38 E 1.917 1725.24 .~ 4778.41 40.380 76.440 4146.64 4232.51 364.68 N 1750.42 E 5959741.73 N 613793.82 E 0.657 1787.68 4874.12 39.960 76.680 4219.77 4305.64 379.03 N 1810.47 E 5959756.97 N 613853.65 E 0.468 1849.41 4969.94 39.860 76.700 4293.27 4379.14 393.19 N 1870.30 E 5959772.02 N 613913.26 E 0.105 1910.89 5066.54 39.680 77.500 4367.52 4453.39 406.98 N 1930.53 E 5959786.71 N 613973.28 E 0.562 1972.68 5161.41 39.470 77.240 4440.64 4526.51 420.20 N 1989.51 E 5959800.80 N 614032.05 E 0.282 2033.12 5257.03 38.750 75.580 4514.84 4600.71 434.36 N 2048.13 E 5959815.84 N 614090.46 E 1.329 2093.43 5353.12 38.060 74.630 4590.14 4676.01 449.70 N 2105.82 E 5959832.04 N 614147.91 E 0.945 2153.09 5449.16 36.990 73.360 4666.31 4752.18 465.82 N 2162.05 E 5959849.00 N 614203.90 E 1.375 2211.49 5544.81 36.660 73.430 4742.87 4828.74 482.21 N 2216.99 E 5959866.20 N 614258.58 E 0.348 2268.70 5641.20 34. 160 73.380 4821 .43 4907.30 498.16 N 2270.51 E 5959882.94 N 614311.86 E 2.594 2324.43 ----------- ---- 19 April, 2002 - 16:57 Page 3 of 5 Drill Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W-212 Your Rei: API # 500292307800 Job No. AKMW22060, Surveyed: 11 April, 2002 . BPXA North Slope Alaska PBU_WOA W Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Ea8tlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5737.71 32.420 73.900 4902.10 4987.97 513.08 N 2321.33 E 5959898.63 N 614362.46 E 1.827 2377.30 5833.04 30.760 73.960 4983.30 5069.17 526.91 N 2369.32 E 5959913.16 N 614410.23 E 1.742 2427.16 5929.50 28.500 73.470 5067.14 5153.01 540.27 N 2415.09 E 5959927.21 N 614455.80 E 2.356 2474.76 -' 6023.21 28.430 72.890 5149.52 5235.39 553.19 N 2457.85 E 5959940.77 N 614498.35 E 0.304 2519.32 6119.76 26.330 74.130 5235.25 5321.12 565.81 N 2500.41 E 5959954.02 N 614540.73 E 2.254 2563.63 6215.32 25.830 74.170 5321.08 5406.95 577.29 N 2540.83 E . 5959966.10 N 614580.97 E 0.524 2605.58 6268.13 25.450 73.060 5368.69 5454.56 583.73 N 2562.75 E 5959972.87 N 614602.79 E 1.160 2628.39 6330.00 25.450 73.060 5424.56 5510.43 591.48 N 2588.18 E 5959980.99 N 614628.11 E 0.000 2654.91 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.150° (11-Apr-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 77.130° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6330.0Oft., The Bottom Hole Displacement is 2654.91ft., in the Direction of 77.127° (True). ----------_.- 19 April, 2002 - 16:57 Page 4 of5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for W·212 Your Ref: API # 500292307800 Job No. AKMW22060, Surveyed: 11 April, 2002 . North Slope Alaska BPXA PBU_WOA W Pad Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment -- 6330.00 5510.43 591.48 N 2588.18 E Projected Survey Survey tool program for W-212 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 6330.00 5510.43 MWD Magnetic >~/ -~--------_.- 19 Aprif, 2002 - 16:57 Page 5 of5 Drll/Quest 2.00.08.005 ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I Polaris I W Pad 04/26/03 Clark Olsen Packer Depths (ft.) Well W-212 Type Inj. N MD/lVD 5,070' 4,456' P.T.D. 2020660 Type test P Test psi 1500 Notes: Pre-produced injector, DGLV's have been set, pre-injection start. Well Type Inj. MD/lVD P.T.D. Type test Test psi Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 Type Inj. Type test Type Inj. Type test Type Inj. Type test MD/lVD T est psi MD/lVD Test psi M D/lVD Test psi TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Pretest Initial 15 Min. 30 Min. Tubing 1800 1800 1800 1800 Interva I Casing 900 1500 1440 1405 P/F P Tubing Interva Casing P/F Tubing Interva Casing P/F Tubing Interva Casing P/F Tubing Interva Casing P/F INTERVAL Codes I = I nitial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT POL W-212 04-26-03.xls 1/15/2003 Schlumberger NO. 2809 Alaska Data and Consulting Services Company: Alaska Oil & Gas Cons Comm 3940 Arctic Blvd, Suite 300 Attn: Lisa Weepie Anchorage, AK 99503-5711 333 West 7th Ave, Suite 100 A TTN: Sherrie Anchorage, AK 99501 Field: Borealis ,- Well Job# Log Description Date BL Color CD W-212 aO.:l....{) Co ID 23001 SCMT 12/10/02 2 V-113 ~Od-d(o 22538 OH EDIT GR & ROP5 DATA 12/14/02 V -113 ~ 22538 MD IMPULSE-GR 12/14/02 1 V-113 22538 TVD IMPULSE-GR 12/14/02 1 L-110 a 0 I-I rl ~ 22400 RST-SIGMA 07/24/02 1 V-113 ðOri- dllc 22537 OH EDIT PEX,AIT,BHC LOG 12/15/02 V-113 -, 22537 PEX-AIT 12/15/02 1 V-113 22537 PEX-DEN/NEUTRON 12/15/02 1 V-113 22537 PEX- TRIPLE COMBO 12/15102 1 V-113 22537 PEX-BOREHOLE PROFILE 12/15/02 1 V-113 '-/' 22537 BHC 12/15/02 1 V-109 ao~-~o~ 22500 OH EDIT MWD GRJRESISTIVITY/DEN/NEUTRON 11/06/02 V-109 22500 MD VISION RESISTIVITY 11/06/02 1 V-109 22500 TVD VISION RESISTIVITY 11/06/02 1 V -109 22500 MD VISION DEN/NEUTRON 11/06/02 1 ,---, V-109 22500 MD VISION RESISTIVITY BOREHOLE PROFILE 11/06/02 1 V-109 V 22500 MD VISION SERVICE BOREHOLE PROFILE 11/06/02 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Re~:~IJ)¿or~ Date Delivered: JAN 21 2003 ~latka or. & Gas Cons. Coo1miseion Anaø~~ ) ') é)7B. ~o~~ J { aep't WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 15, 2002 RE: MWD Formation Evaluation Logs: W -212 POLARIS, AK-MW-22060 W-212 Polaris: Digital Log Images: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~~t'~O~~ RECEIVED NOV 07 2002 Alaska Oi~ & Gas Co An ns. Commi8aion chorage ) ) a 0 ð- Otol.o I O'1Î Ço WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 l\nchorage,Alaska August 15,2002 RE: MWD Formation Evaluation Logs W-212, AK-MW-22060 1 LDWG formatted Disc with verification listing. API#: 50-029-23078-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: I Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical :Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~~ RECEIVED J. , 1"",\ hlJ0 2 J 2002 AJaMa n; VlI&GasCons C ' Anctl(r. 01Tll11i8ttion ScblunJ_.pgep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie ,~.......... Well Job # Log Description W-212 dœ -0"" W-212 W-212 W-212 W-212 V W-200 I q 7- d. Jt.j 8-104 a{)n - 1<1 L, 22184 PEX AIT SHC 22184 PEX-AIT 22184 PEX-DENlNEUTRON 22184 PEX-TRIPLE COMBO 22184 SHC PRODUCTION PROFILE SBHP SURVEY ,..-, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED Date Delivered: ,\~ ,1...\( 1 ! 2002 ì ií\. '""( A181ka0i!&GasCons.CamInIiOn AncJmrage Date 04/06/02 04/06/02 04/06/02 04/06/02 04/06/02 04/29/02 04/11/02 05/09/02 NO. 2061 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Color Sepia CD BL Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received~~~ ~~~~E ~ ) F !A~!A~~~] \ ~ TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Sr. Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit W-212i BP Exploration (Alaska), Inc. Permit No: 202-066 Sur. Loc. 906' SNL, 1185' WEL, Sec. 21, TIIN, RI2E, UM Btmhole Loc. 4954' NSL, 3924' WEL, Sec. 22, TIIN, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit W-212i. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Cd Th,,~ (ltL~ ·1--t.-/ Cammy bbchsli Taylo¡L) Chair BY ORDER ~MHE COMMISSION DATED this ay of March, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA ( STATE OF ALASKA )AND GAS CONSERVATION COMMI )ON PERMIT TO DRILL 20 AAC 25.005 1b. Type of well ¥tt/~1 0 Exploratory 0 Stratigraphic Test Jevelopment Oil ~ervke 0 Development Gas 0 Single Zone L.J Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 84.1' Prudhoe Bay Field I Polaris 6. Property Designation Pool (Undefined) ADL 028263 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / W-212i 9. Approximate spud d,te 04/01/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 6248' MD I 5433' TVD o 17. Anticipated pressure {s,e 20 AAC 25.035 (e) (2)} 39 Maximum surface 1825" pSig, At total depth (TVD) 53501 I 2360 psig Setting Depth TaD Bottom MD TVD MD TVD Surface Surface 80' 80' Surface Surface 3468' 3203' Surface Surface 6248' 5433' (¿JCrA- -s t t .~ If) 'L ~(I,-\ '\. 1 a. Type of work 1m Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 906' SNL, 1185' WEL, SEC, 21, T11N, R12E, UM At top of productive interval 4907' NSL, 4132" WEL, SEC. 22, T11 N, R12E, UM At total depth 4954' NSL, 3924' WEL, SEC. 22, T11 N, R12E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 047451,3924' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 1000' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casino Weight Grade COUDlino 20" 91.5# H-40 Weld 9-5/8" 40# L-80 BTC-M 7" 26# L-80 BTC-M Hole 3011 12-1/411 8-3/411 Lenath 801 3468' 62481 Quantitv of Cement (include staoe data) 260 sx Arctic Set (Approx.) 544 sx AS III Lite, 253 sx Class 'GI 86 sx D-79, 307 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Su rface Intermediate Production Liner Length Size Cemented MD TVD Perforation depth: measured L\lask2 ( ,.1, true vertical 1m Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 1m Drilling Program 1m Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Walt~t Quay, 564-4178 Prepared By Name/Number: Terrie Hubble, 564-4628 21. ~:~::y ~:~; ;::(;t:S:;ïZ::t to the b~S~::: Engineer Date 3 _11_ oJ- Permit Number API Number .., ~ 0 7 t7 Approval Date See cover letter Z ð < - 0 6 b 50- 0 2.. 9 - ..,&.. ~ 0 for other requirements Conditions of Approval: Samples Required 0 Yes ø No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes BI No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other; .4Qç¿() \>~>. \Sa~~~ \-\ \\~ CJ¿~~-\-Q\,)CJ.\\-\\ \...c~ Urlglnal :)Igned tsy by order of Approved By r.;:¡mmy O~('h~li Commissioner the commission Form 10-401 Rev. 12-01-85 20. Attachments Date , '; \..,,) ¡ ,'''~t f r I: \ ~'"t I f J l~.j ! ~ r ~ ,~ ,., I ~,: ¿'-~\,." Submit In Triplicate Wl¿L NAME: 1t)-212i Well Plan Summary Type of Well (producer or injector): I Schrader Bluff Injector Surface Location: 906' FNL 1185' FEL, T11 N, R12E, S21 X = 612,049.03 E, Y = 5,959,350.99 N Target Location: #1 4907' F8L, 4132' FEL, T11 N, R12E, S22 X = 614,372 E, Y = 5,959,921 N Bottom Hole Location: 4954' FSL, 3924' FEL, T11N, R12E, 822 X = 614,579 E, Y = 5,959,970 N I AFE Number: I Estimated Start Date: MD: 6248' 15M1028 I 4/1/02 TVD: / I Rig: I Doyon 14 ./ I Operating days to complete: 112 5433 84.1'/53.1' RKB/Surface Elevation (a.m.sJ) *as staked Ultra-slimhole directional well. Kick-off in the Permafrost building to 17° tangent angle then building up to 38° in the SV6 - 8V2 fromations. A drop in angle is planned from the Schrader Bluff to TD, with the final angle being 27° at TD +/-200' below the base of the Schrader Bluff Obf Well Design (conventional, slimhole, etc.): I Objective: I Injector well to provide pressure support for W-200, W-211 & W-216 wells. Formation Markers MD TVD Comments (SS) 1950 1975 2095 2500 2700 3020 3400 3440 3800 4520 4575 4625 4685 4745 4770 4810 4900 4945 4995 5030 5080 5150 5190 5240 5350 Formation Tops Base Permafrost SV5 SV4 SV3 SV2 SV1 UG4 UG4A UG3 Top Schrader Bluff/Ma Mb1 Mb2 Mc Na Nb Nc OA OBa OBb OBc OBd OBe OBf " OBf_Base TD W -212i Drillling Permit.doc 2056 2082 2208 2672 2929 3340 3827 3879 4341 5265 5336 5400 5476 5551 5581 5630 5737 5790 5848 5888 5945 6024 6069 6125 6248 3/11/2002 Page 1 of 7 ) ,CasinQlTubin$l Proaram: Ultra-Slimhole Desian Hole Size Csgl WtlFt Grade Conn Length Top Tbg O.D. MDITVD 20" 91.5# H40 WELD 80' Surface 9 5/8" 40# L-80 BTCM 3468' Surface 7" 26# L-80 BTCM 6248' Surface 4-1/2" 12.6# L-80 TCII 5190' Surface ) 30" 12 %" 8%" Tubing 8tm MDITVD 80'/80' 3468'/ 3203' 6248'/5433' 5190'/4545' .,/" Mud Program: Initial below Permafrost interval TO SUI"face Interval Mud Properties: Density Viscosity 8.5 - 8.6 300 9.0 - 9.5* / 250-300 9.6 max. 250-300 Spud Mud Fluid Yield Point GPM tauO 50 - 70 < 550 > 9 45 - 70 600 - 650 > 7 45 - 70 650 > 6 12 % " hole API FL 15 - 20 <10 <8 pH 8.5 - 9.5 8.5-9.5 8.5 - 9.5 Production Interval Mud Properties: LSND 8 % " hole Initial Density Plastic . Viscosity 9.3 - 9.SV' 8 -15 Yield GPM tauO Gel Point 18 - 25 550 - 600 3 - 7 1 0 - 18 API Filtrate 6-8 pH 8.5- 9.5 Directional KOP: ± 1000 MD - 1.5°/100' build. 1500' MD -- 2.5°/100' build. 2200' MD -- 4°/100' build. ~/ ± 39.0° - Build, Hold & Drop All wells pass BP Close Approach guidelines. The nearest close approach well is W-15, which is 70' well-to-well at 392' MD. MWD Surveys from surface to TO. ESS to be dropped Gyro may be needed for surface hole. Maximum Hole Angle: Close Approach Well: Survey Program: Cement Calculations: Casing Size 19-5/8" Surface - 1 Stage 1 Basis: Lead: Based on 280q/of open hole from surface to 2800' MD + 250 % excess across the permafrost. Lead TOC: Surface Tail: Based on 500' MD open hole volume + 82' shoe track volume + 30% excess. Tail TOC: At -2800' MD .,/ / Total Cement Volume: Lead 544 bbl /2414 ft;; / 544 sks of Dowell ASIII Lite at 10.7 ppg and 4.44 cf/sk. / Tail 53 bbl / 296 ft;; / 253 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. ./ If logs indicate the UG4 does not contain significant hydrocarbons, the program will be amended to provide cement above the top of the Schrader only. (Lead slurry will be eliminated.) Casing Size 17" Intermediate I Basis: Lead: Based on 1000' of open hole (to 500' MD above top UG4) with *50% excess. Lead TOC: At -3427' MD (-3171' TVD). Tail: Based on 82' shoe track volume and 1750' of open hole with 30% excess. / Tail TOC: At -4,500' MD./ / I Total Cement Volume: Lead 37 bbl I 208ft;; I 86 sks of Dowell 0-79 Slurry 12.0 ppg at 2.41 cf/sk Tail 64 bbl I 359 fe I 307 sks of Dowell Premium 'G' at 15.8 ppg and 1.17,// cf/sk. / W -212i Drillling Permit.doc 3/11/2002 Page 2 of 7 ) ,LoQQinQ ProQram LWD Logging: 121A" Hole 8 %" Hole Open Hole Logs (eline): 12 'IA" Hole 8 %" Hole Cased Hole Logs (eline): W -212i Drillling Permit.doc MWD directional / GR MWD directional / GR / Res / CNL / Den No Logs needed / USIT in Production Interval / 3/11/2002 ) Page 3 of 7 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surfac7pressures. Based upon casing test pressure, the BOP equipment will be tested to 4000 psi. ') ) Diverter, BOPE, and drilling fluid system schematics are on file with the AOGCC. Production Interval- · Maximum anticipated BHP: ~,360psi @ 5350' TVDss - Base Of Schrader (8.5 ppg) · Maximum surface pressure: 1,825 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4000 psi / 8.5 ppg sea water / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · W Pad is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. DRilliNG CLOSE APPROACH: · All wells pass close approach guidelines. Disposal: · No annular injection in this well. / · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at D8-04. Any metal cuttings will be sent to the North 810pe Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to D8-04 for injection. Haul all Class I wastes to Pad 3 for disposal. W -212i Drillling Permit.doc 3/11/2002 Page 4 of 7 DRILL AND C{,I~PLETE PROCEDUR~ JUMMARY Pre-Rig Work: The 20" conductor is set. 1. Weld an FMC landing ring for the FMC Gen. V Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Doyon 14. /' 2. Nipple up and function test 21-1/4" diverter system. PU 5" DP as required and stand back in derrick. 3. MU 12 "IA" drilling assembly and drill surface hole to to planned KOP at approximately 1000' MD. Build angle initially at 1.5°/100' increasing to 4°/100' reaching a tangent angle of 39° by 2700' MD and TD the surface hole at approximately 3470' MD will be -100' below the top of the SV1 sands. 4. Run and cement the 9 5/8", 40#, L-80, BTCM casing to surface. /' 5. ND diverter system and NU casing / tubing head. NU BOPE and test to 4000 psi./ 6. MU 8 %" drilling assembly and RIH to float collar. Test the 95/8" casing to 4000 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.3 ppg LSND fluid. Drill new formation to 20' below 9 5/8" shoe and perform FIT 8. Drill ahead to TD of this section; -6248'MD /5433' TVD. POOH. 9. Run and cement the 7", 26# intermediate casing /' 10. Run 4-1/2",12.6#, L-80 completion. Test tubing to 4000 psi for 30 min. See attached completion schematic for details. 11. Install two-way check. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Pull two-way check and freeze protect the well to -2000' TVD. Set packer. Test to 4000 psi. 12. Install BPV. Secure the well and rig down / move rig. Estimated Spud Date: 04/1/02 Walter Quay Alaska Drilling and Wells Operations Drilling Engineer, 564-4178 W -212i Drillling Permit.doc 3/11/2002 Page 5 of 7 Job 1: MIRU ) ') Hazards and Contingencies: > The adjacent well, W-15, is approximately 70' from the W-212i conductor. No wells are required to be shut in. oWmll:lllmlll.'__II.'I._I_" n-'lllllm--- _m_---_I!I!II!I"I!"_ .1,10.'),1,11;111:'1:"\: Job 2: Drill 12U," Surface Hole Hazards and Contingencies: > At W-Pad, no significant surface hole drilling problems have been identified. Minor tight hole has been encountered in the clay sections below the permafrost, some lost circulation thought to be in conjunction with the tight hole, possible packing off has been encountered. 1::11111111::. _"II--'lm,mllll!l~m:!01:1nlm:I"lli'nl':m_ _m'mml'_mlll_I!I':II'ln:I':I':I:llmllm~I1I':I_ _lm":m1lImrmml'Ilmmml_I'.m_lll_ :,::"lnW.:'I,:.,m:ln---;II--:ln:lf:I:I:I:::I::lm,n:lllmm-m:m::\,:m:I"-II"I~':mmmlllllm""!I1 "I":IT----llnl':'I'III~I':'l!lml!lml· Job3: Install Surface Casinø Hazards and Contingencies: > At W-Pad, Lost circulation has been experienced while running and cementing surface casing. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing. Once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. > It is critical that cement is circulated to surface for well integrity. 2500/0 excess cement is planned through the permafrost zone and 30% excess is planned below the permafrost. As a contingency, a 9-5/8" port collar will be positioned at +/-1000' MD to allow a secondary circulation point as required. Job 4: Drill/Core 8%" Production Hole ? ~<::)C-O~ Ç> \:..,.\'--~ Hazards and Contingencies: > Gas cut mud/well flowing has been observed in the Ugnu (3,490' TVDss). This will be controlled with appropriate mud weights. A minimum of 9.3 ppg is recommended. > Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. > The kick tolerance for the 8-3/4" open hole section would be 61.8 bbls assuming an influx from / the Schrader Bluff interval at -5260' MD. This is a worst case scenario based on a 9.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 9-5/8" shoe, and 9.3 ppg mud in the hole. > The well path in not expected to cross any faults. There is a fault 480' east fo the Top Oba target. Job 6: Install 7" Production CasinQ Hazards and Contingencies: > Tight hole, packing off and lost circulation have been experienced while running casing though this interval. Good hole cleaning and mud conditioning are required for running this string. W -212i Drillling Permit.doc 3/11/2002 Page 6 of 7 ~ Differential Sticking cOl}e a problem if lost circulation is occurrin~)f the casing is left stationary for an extended period or time across the permeable sands.· Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~~_I_ .1~I_L_illmliml~I~lllmm~:mll:mll,:,I:lmmm:.II:.II:lm:m111:mlmm~nr,II,lmlmr;II,~I,M~'IIID. .m,. -,:11.\1111.1- .IICI:,III. .llllllllmllm:.mmm:lllllllmmll11.lllI.Illmrl. .11.1__1__1 '; ....~_ .mlll,mll_ .111. ,rt;.t¡.,rm,:+wm:I:I.. _1_:ltJoU~I'IIIIIII::III>lII,III,\Hlmlll~m:,IIII~lrl::I_,_n_I~Umlm:lnm__H_ .U' .1.1. .11I. _,lIlllllllllllm:¡llllIum: .mmmmm..1 Job 12: Run ComDletion Hazards and Contingencies: :m,IIC"::'III,mlllllllllllm,lllm,m:IIIIIIIICl:Illllmlll,1mlml.IUIIWII.III::II.!::mllUalllmmmtllllllllllll:m,:mIHlmmmlrllllmmlU1IIImlllm,llI:m:,I:IIII,ICIIII:mIIlIIIII11111:mllmm:m,IIWIlmmllm'!lrlmllllmmml,I:,~mmllmlmml'm:lrmnlm~l:mml:II'1IllmmIIU!lIIlIlUI,I,II,':I~mIUllmllmnUUllmnm:mlll:m:_T:i:11I1IlIInlllll,lIllrCllllllllllllllnll:IIIIWI,I:,:mtimmtlnntlllllmtl1!lIIm Job 13: ND/NU/Release Riø Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. W -212i Drillling Permit.doc 3/11/2002 Page 7 of 7 TREE = 4" 5000 psi WELLHEAD= FMC 11" }(CrÜATÕR;;·'"·'·····,"'·············w,,,.,',. 'KRËCì3r;-'''··--'·'ëšT@'ã3· '·BF:':·EL'B/··;;·..··" '···'··"esi.·@'·'i5C) KÕp_';'··"'N.wMmmw"',^'^W"MW.'W"^"w,~..^w·'7ÕÕ' Iv¡ã'x'jGl"gÎe··;··""··39~··'@··2:i5õ~··· '5ãfûm·MÕ"';·~·"'·~~"·····58f8···bkb bãtûñ1'iVõ;-·""'·"··'''S02!5''ŠS ') 9 5/8" 40# L-80 I 3468' I~ Minimum ID = 3.725" 4-1/2" 12.6#, L-80, TCII I 5190' I PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE PBTD 6165' 7" 26# L -80 mBTC 6248' DATE 06/26/01 03/01/02 REV BY PGS WDQ Original Proposed Completion Amended Proposed ColT'pletion W -212 i ~ I I I I z \ SAFETY NOTES 11000' TAM Port collar 12200' X Nipple, 3.813" ID ~ 15075' Z ----15090' f 1 .r" ~ COMMENTS 15155' 15175' 15190' 15740' X Nipple, 3.813" ID Production Packer X Nipple, 3.813" I.D. I XN Nipple, 3.725" ID 1 WLEG 1 Short Joint & RA tag 1 PRUDHOE BA Y UNIT I A URORA FIELD WELL: W-212i ÆRMIT No: 200-??? API No: 50-029-***** Sec. 21, T11 N, R12E. 870' FNL, 1184' FEL BP Exploration (Alaska) atVASl.ID\lE 'U1dO) Plan: W-212 wp05 (W-212lPlan W-212 Cræloo By: Ken Allen Date: 2128/2002 Checked: Date: Date: SURVEY PROGRAM Depth Fro Depth To SurveylPlan Tool 83.00 1000.00 PJanœd: W-212 wp05 VI CB-GYRO-SS 1000.00 6247.89 Planœd: W-2l2 "1><>5 VI MWD REFERENCE INFORMATION WellCenIre: W-212. TrœNorth 1 : 01 91121198800:00 83.00 SIo. - (O.OON,O.OOE) I : 01 9/121198800:00 83.00 MinimlDn Cun'3ture C<KJrdinate (NiE) Reference: Vertical (IVD) Reference: Section (VS) Ref<renœ: M"",-ured Depth Reference: Calculation Melbod: ('alculalion M..1J~kI: MUILmum CUfvatl.B\: Emir System: I~CWS~ Scan Method: 1 rav C)1ind..T NuM Em)r Surrac4.:: Elliptical t Casing W.mil1! Mctt.1d: Rules U."..d bp ~~ V o WELL DETAIL<; Namo +N!-S +E!-W Northing EBsting Latitude Longitude SI, ~ 2125.63 216132 5959351.00 612049.00 70017'52.409N 149°05'33.340W NlA TARGET DETAILS Namo 1VD +N!-S +E!-W Northing Basting Shape W-212 DB. TI 5028.00 535.02 233127 5959920.67 614371.84 Polygon W-212 TO T2 5433.00 580.98 2539.48 5959969.73 61457932 Pnlygon SECTION DErAILS I '1 \ ~ Start Di .y; \ 0 End Dir : I 776.ö7' MD. ~ \ \10 \ Permafrost .:..:_2((J0-\~ SV5 ,0-- Start Dir4/100':. . h-- SV4 \1.{),0 \ \§ '\ SV.1 ~ End Dir : 2694.48' MD. 2599.97' TVD ....~ISV2 ~Oil(l '\ . "- ~~SVI ~;:-- /\ 4 5/$" \\ ",. . . i':---- l{5t14 A ~ . \. If 40pO ''\ '-, .' -' .. '~UG~ \1. . 4000---------------..-------. -..-----..- ..'.,-- \, '\ .'\ :'\. 5000 " \ Ma ,.~ Mbl __ _______ _ __ \..~~ Mb2 . ~ ~Dir-2/1 00'~::~~193261.~t ~:~~~~~~~.~~~c . I_OA - - --. ~-_. - =. ~&b __.~-H.-.~., ~0J3~d 5999.8 MD, 5211 Yl t-·.·.·· OBe -;nm OBf . Base OBf ~. Total Depth n. 7'{ I I +EI-W DLeg TFace VSec Targe 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.87 1.00 90.00 0.85 37.46 1.50 0.00 36.52 115.30 2.50 0.00 112.40 217.40 0.00 0.00 211.93 476.14 4.00 -24.61 474.49 2110.96 0.00 0.00 2165.05 2331.27 2.00 170.88 2391.88 W-2120Ba 2430.24 2.00 179.99 2493.22 - 2539.48 0.00 0.00 2605.10 W-212 TD T2 CASING DErAILS No. TVD MD Name Size I 3203.00 3468.40 95/8" 9.625 2 5432.99 6247.88 7" 7.000 FORMATIONTOPDETArrS No. TVDPath MDPath Formation I 2033.00 2055.83 Perrnarrost 2 2058.00 2081.97 SV5 3 2178.00 2208.15 SV4 4 2583.00 2672.82 SV3 5 2783.00 2929.37 SV2 6 3103.00 3340.06 SVI 7 3483.00 3827.75 UG4 8 3523.00 3879.08 UG4A 9 3883.00 4341.10 UGJ 10 4603.00 5265.15 Ma 11 4658.00 5335.73 Mbl 12 4708.00 5399.90 Mb2 I3 4768.00 5475.97 Mc 14 4828.00 5550.56 Na 15 4853.00 5581.23 Nb 16 4893.00 5629.85 Nc 17 4983.00 5737.28 OA ..........) 18 5028.00 5790.07 OBa 19 5078.00 5848.05 OBb 20 5113.00 5888.24 OBc 21 5163.00 5945.12 OBd 22 5233.00 6023.81 OBe 23 5273.00 6068.63 OBf 24 5323.00 6124.65 Base OBf +N/-S /000 ~/I 0.00 0.00 0.00 0.00 0.00 0.00 46.39 480.96 535.02 556.87 580.98 TVD 83.00 850.00 949.99 1414.93 1766.04 2100.00 2599.97 4702.83 5028.00 5211.57 5433.00 Azi 0.00 0.00 90.00 90.00 90.00 90.00 75.11 75.11 77.55 77.55 77.55 Inc 0.00 0.00 1.00 8.00 17.00 17.00 38.81 38.81 31.00 26.81 26.81 ~ .ss ~ ~ S' ~ ~ c:::s - MD 83.00 850.00 950.00 1416.67 1776.67 2125.89 2694.48 5393.26 5790.07 5999.80 6247.89 Sec I 2 3 4 5 6 7 8 9 10 II o ,rI I I .,,1 I I 1f/J 00' : 850' MD, 850'TVD 00': 950' MD, Q4Q.Q9'TVD MD,1414.Q3'TVD 766.04' TVD 25.89' MD, 2100'TVD 41 ö.ö7' 5/100' 5 Start Di Start Di I L/ :v ù 000 ! 800 600 2400 3200 4800 c ¢: o ~ .c i5.. Ö ] 1: >- .. ::I ~ ..../000 All TVD depths are ssTVD plus 83' for RKBE TVD I I 4000 5433' MD, , 6247.89' I I , 3200 End Di 1600 2400 Vertical Section at 77.110 [800ft/in] 800 Plan: W-212 wp05 (W-2I 2IPlan W-212 erealed By: Ken Allen Dale: 212812002 Checked: Date: Date: SURVEY PROGRAM Depth Fm Depth To Sun'ey1PIan Tool 83.00 1000.00 PJanœd: W-212 wp05 VI CB-GYRO-SS 1000.00 6247.89 Planœd: W-212 wpOS VI MWD REFERENCE INFORMA nON C(K)rdina~ (N'E) Reference: Wen Centre: W-212, Tru;' North Vertical (IVD) Ref""",",,: I: OJ 9/121198800:00 83.00 Section (VS) Reference: Slot - (O.OON,O.OOE) M=ured Deplb Refereoœ: I: 01 9/121198800:00 83.00 Calculation Method: Minimum Cumllure bp ~~.? V WELL DETAILS Nam. +NJ-S +PJ-W Northing Easting Latitude Longitude Slol '-212 2125.63 216132 5959351.00 612049.00 70017'52.409N 149°05'33340W NJA TARGET DETAILS Nam. lVD +NJ-S +PJ-W Nor1biJJg Easting Shape W-212 OBa Tl 5028.00 535.02 233127 5959920.67 614371.84 Polygon W-212 ID 11 5433.00 580.98 2539.48 5959969.73 61457932 Polygon SECTION DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFaee VSee Target I 83.00 0.00 0.00 83.00 0.00 0.00 0.00 0.00 0.00 2 850.00 0.00 0.00 850.00 0.00 0.00 0.00 0.00 0.00 3 950.00 1.00 90.00 949.99 0.00 0.87 1.00 90.00 0.85 4 1416.67 8.00 90.00 1414.93 0.00 37.46 1.50 0.00 36.52 5 1776.67 17.00 90.00 1766.04 0.00 115.30 2.50 0.00 112.40 6 2125.89 17.00 90.00 2100.00 0.00 217.40 0.00 0.00 211.93 7 2694.48 38.81 75.11 2599.97 46.39 476.14 4.00 -24.61 474.49 8 5393.26 38.81 75.11 4702.83 480.96 2110.96 0.00 0.00 2165.05 9 5790.07 31.00 77.55 5028.00 535.02 2331.27 2.00 170.88 2391.88 W-212 OBa . -- 10 5999.80 26.81 77.55 5211.57 556.87 2430.24 2.00 179.99 2493.22 II 6247.89 26.81 77.5 5 5433.00 580.98 2539.48 0.00 0.00 2605.10 W-212 TD T2 CASING DETAILS No. TVD MD Name Size 1 3203.00 3468.40 95/8" 9.625 2 5432.99 6247.88 7" 7.000 W-212 TD T2 Total Depth: 6247.89' MD, 5433' 1 ~ . \ : . \\ wp05 OB'~ :"~¡~ t..-l D;'S21151!'tvD·:·· - -,..,'" .mr All TVD depths are ssTVD plus 83' for RKBE ~~ //..........,~ / .~¡"H '1iLI / /,. "'. ¡ /\<~\........... ............ .............) ", /...', ,'. ¡ /,\:, \ i / "...., ~.~. ),j '.' ~ooo ". /000 /f/ -/~ ~ FORMATION TOP DETAILS TVDPath MDPath Formation Permarrost SV5 SV4 SV3 SV2 SVI UG4 UG4A um Ma Mbl Mb2 Me Na Nb Ne OA OBa OBb OBe OBd OBe OBf Base OB 2055.83 2081.97 2208.15 2672.82 2929.37 3340.06 3827.75 3879.08 4341.1 0 5265.15 5335.73 5399.90 5475.97 5550.56 5581.23 5629.85 5737.28 5790.07 5848.05 5888.24 5945.12 6023.81 6068.63 6124.65 2033.00 2058.00 2178.00 2583.00 2783.00 3103.00 3483.00 3523.00 3883.00 4603.00 4658.00 4708.00 4768.00 4828.00 4853.00 4893.00 4983.00 5028.00 5078.00 5113.00 5163.00 5233.00 5273.00 5323.00 No. I 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 21 22 23 24 Cah.l1l.Jtion ML1hod: Minimurn Cur\'atUl\: Errnr SystA.m: ISCWSA Scan Mcll)t'.d: Tn\' Cylinder North Errur Surlåt:\:: Elliptical ~ Casiß1! WamiJlji ~1<1h<><I: Rules II....-d o II I I ¡JJ I I 1fP ## '"C #' ~ ~ I 2700 2400 2100 800 West(-)/East(+) [300ft/in] 300 o 300- 0- -300 :s ~ ~ +' :;: 1:: ~ ~ õ (/) çOlJ1pany: l1'ieïd: Site: ., . Well : Wellpath: sF> Amoco PtudooeBay PB WPád. W':212 PlanW·212 ') BP Amoco ) Planning Report - Geographic Däte:2/28/20q2 ,T.iDle:13:47:0? ..... Co-or4iþåte(NE).~eference:Well; ,^,~21 ?,-r:rÿe North. VertiCal(TVD)R~fe"ericë:. . t: 019(1?/1Q8aOO:0083.0 . $eCtioi1(VS)Refe~encë: WelJ(O. OON,Ö.ÖOE~ 77.11Azi) ·Plai1: .. W':212 wþ05 Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB W Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 47.83 ft Well: W-212 5957194.18 ft 609919.18 ft Latitude: Longitude: North Reference: Grid Convergence: Alaska, Zone 4 Well Centre BGGM2001 70 17 31.506 N 149 6 36.343 W True 0.84 deg Surface Position: +N/-S 2125.63 ft Northing: 5959351.00 ft Latitude: 70 17 52.409 N +E/-W 2161.32 ft Easting : 612049.00 ft Longitude: 149 5 33.340 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 2125.63 ft Northing: 5959351.00 ft Latitude: 70 17 52.409 N +E/-W 2161.32 ft Easting : 612049.00 ft Longitude: 149 5 33.340 W Measured Depth: 83.00 ft Inclination: 0.00 deg Vertical Depth: 83.00 ft Azimuth: 0.00 deg Wellpath: Plan W-212 Current Datum: Magnetic Data: Field Strength: Vertical Section: Plan: W-212 wp05 Principal: Yes Plan Section Information MD Incl ft deg 83.00 0.00 850.00 0.00 950.00 1.00 1416.67 8.00 1776.67 17.00 2125.89 17.00 2694.48 38.81 5393.26 38.81 5790.07 31.00 5999.80 26.81 6247.89 26.81 Section 1 : Start MD Incl ft deg 83.00 0.00 100.00 0.00 200.00 0.00 300.00 0.00 400.00 0.00 500.00 0.00 600.00 0.00 700.00 0.00 800.00 0.00 Azim TVD +N/-S +E/-W DLS Build Turn TFO deg ft ft ft deg/100ft deg/100ft deg/100ft deg 0.00 83.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 850.00 0.00 0.00 0.00 0.00 0.00 0.00 90.00 949.99 0.00 0.87 1.00 1.00 0.00 90.00 90.00 1414.93 0.00 37.46 1.50 1.50 0.00 0.00 90.00 1766.04 0.00 115.30 2.50 2.50 0.00 0.00 90.00 2100.00 0.00 217.40 0.00 / 0.00 0.00 0.00 75.11 2599.97 46.39 476.14 4.00 3.84 -2.62 -24.61 75.11 4702.83 480.96 2110.96 0.00 0.00 0.00 0.00 77.55 5028.00 535.02 2331.27 2.00 -1.97 0.61 170.88 77.55 5211.57 556.87 2430.24 2.00 -2.00 0.00 179.99 77.55 5433.00 580.98 2539.48 0.00 0.00 0.00 0.00 Slot Name: 1 : 01 9/12/1988 00:00 6/6/2001 57470 nT Depth From (TVD) ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 83.00 ft +N/-S ft 0.00 Date Composed: Version: Tied-to: Well Ref. Point 0.00 ft Mean Sea Level 26.43 deg 80.74 deg Direction deg 77.11 2/28/2002 1 From Well Ref. Point Target W-212 OBa T1 W-212 TO T2 Azim TVD +N/-S +E/-W VS DLS Build Turn TFO deg ft ft ft ft deg/100ft deg/10att deg/10att deg 0.00 83.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ) BP Amoco ) Planning Report - Geographic CQlnpany: BP Amoco i;4'ield; Prudhoe Bay Site: . PH W Pad Well: W-212 :Wellpath: . . Plan VV.;.212 Section 1: Start 1\1D ft 850.00 Section 2: Start MD ft 900.00 950.00 Section 3: Start MD ft 1000.00 1100.00 1200.00 1300.00 1400.00 1416.67 Section 4: Start MD ft 1500.00 1600.00 1700.00 1776.67 Section 5: Start MD ft 1800.00 1900.00 2000.00 2100.00 2125.89 Section 6: Start MD ft 2200.00 2300.00 2400.00 2500.00 2600.00 2694.48 Incl deg 0.00 Incl deg 0.50 1.00 Incl deg 1.75 3.25 4.75 6.25 7.75 8.00 . Incl dég 10.08 12.58 15.08 17.00 Incl deg 17.00 17.00 17.00 17.00 17.00 Incl deg 19.73 23.51 27.34 31.21 35.11 38.81 Section 7: Start MD ft 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 Incl deg 38.81 38.81 38.81 38.81 38.81 38.81 38.81 38.81 38.81 38.81 Azi.m deg 90.00 90.00 Azim· deg 90.00 90.00 90.00 90.00 90.00 90.00 Azim deg 90.00 90.00 90.00 90.00 Azim deg 90.00 90.00 90.00 90.00 90.00 Azim deg 86.34 82.73 80.07 78.02 76.39 75.11 Azim deg 75.11 75.11 75.11 75.11 75.11 75.11 75.11 75.11 75.11 75.11 <rvl) ft 900.00 949.99 TVD. .ft 999.98 1099.88 1199.63 1299.17 1398.42 1414.93 TVD ft 1497.22 1595.26 1692.35 1766.04 TVD ft 1788.35 1883.98 1979.61 2075.24 2100.00 TVD ft 2170.33 2263.28 2353.59 2440.80 2524.49 2599.97 TVD ft 2604.27 2682.19 2760.12 2838.04 2915.96 2993.89 3071.81 3149.73 3227.65 3305.58 +N/-S ft 0.00 0.00 +N/-S ft 0.00 0.00 0.00 0.00 0.00 0.00 +N/-S ft 0.00 0.00 0.00 0.00 +N/-S ft 0.00 0.00 0.00 0.00 0.00 +N/-S ft 0.80 4.40 10.89 20.23 32.38 46.39 +N/-S ft 47.28 63.38 79.49 95.59 111.70 127.80 143.91 160.01 176.12 192.22 Date: . .. 2/28/20q2. . .. ... .':fime; ·13:47:03... . ~o-ord~nate(NEJRefe~encè: 'Nen: VIJ~212,TrueNorth . Yét~iCå~ (TYDJRe(êrence: 1·: 019/12/1E!f}8 00:0083.0 Sedion(YS) Rëference: vven (O.00N,Ô~ÖOE,77.11Azi)·· Plåri:· .. VV-212 Wp05 +E/-W ft 0.00 +E/~W ft 0.22 0.87 -i-E/-W ft 2.07 6.43 13.41 22.99 35.18 37.46 +E/~W ft 50.55 70.20 94.11 115.30 +E/- W ft 122.12 151.36 180.60 209.83 217.40 +E/- W ft 240.72 277.37 319.79 367.78 421.10 476.14 +E/- W ft 479.48 540.05 600.62 661.19 721.76 782.33 842.90 903.47 964.04 1024.61 VS ft. 0.00 VS ft 0.21 0.85 VS ft 2.02 6.27 13.07 22.41 34.29 36.52 VS ft 49.28 68.44 91.74 112.39 VS ft 119.04 147.54 176.05 204.55 211.92 VS ft 234.84 271.36 314.16 363.02 417.71 474.49 VS ft 477.95 540.58 603.22 665.86 728.49 791.13 853.76 916.40 979.03 1041.67 I>I.S Bµild ·.~ùrn . ~eg/~ POft ciegll00ftdegl1 ÔOft 0.00 0.00 0.00 TFO deg 0.00 DLS . Build . ... Turn TFO d~9/100ftdeg/12oft deg.00~__ d~~~.-:._~_.~~"_-::~__.-:-_ 1.00 1.00 0.00 0.00 1.00 1.00 0.00 0.00 DLS Build Turn . deg/100ft deg/1 OQftdeg/1 OOft 1.50 1.50 0.00 1.50 1.50 0.00 1.50 1.50 0.00 1.50 1.50 0.00 1.50 1.50 0.00 1.50 1.50 0.00 DLS Build Turn deg/100ft deg/1 00ftdeg/1 000 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 DLS Build Turn deg/100ft deg/100ft deg/10OO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 DLS Build Turn deg/1 OOft ~eg/1 000 deg/10OO 4.00 ¡ 3.69 -4.93 4.00 3.77 -3.62 4.00 3.83 -2.66 4.00 3.87 -2.04 4.00 3.90 -1.63 4.00 3.91 -1.36 DLS Build Turn deg/10OO deg/10OO deg/10OO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 TFO deg 0.00 0.00 0.00 0.00 TFO deg 0.00 0.00 0.00 0.00 0.00 TFO deg -24.61 -21.14 -17.77 -15.37 -13.59 -12.29 TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ) BP Amoco ) Planning Report - Geographic ÇÒÏ11.paIiY: BPAmoco I)at~:. ...2/28/200? . .... Time:. ...13:47:03... .. ..... Field: . . prudhQß. Bay Co-~rd¡~ateCl'TJJ:) ~efer~l1~e:. WßII: w,-~ 1 ~, True N()rth ~itê: ·PBWPåd· V ertic~I(J:VI) R~ference: ·.1·: q19/12m 9~8· o~:O~ ~:3J0 Well: W-212 ... Section (VS) Reference: . . Well (0.OON;0;QOE,77;11Azi) Wellpath: PlanW'-'212 Plan: . . ... . ..... W~212wp05 ... . Section 7 : Start MD Incl. Aiim ··TVD +N/-:S ·:+E/~W vs DLS .... ..Build.··. . . T.urn..·.· .. TFO ft dfi}g deg ft ft. ft· ft deg/1 Opftdeg/1 00ftd~g/1 pOft. deg. 3700.00 38.81 75.11 3383.50 208.33 1085.18 1104.31 0.00 0.00 0.00 0.00 3800.00 38.81 75.11 3461 .42 224.43 1145.75 1166.94 0.00 0.00 0.00 0.00 3900.00 38.81 75.11 3539.35 240.54 1206.32 1229.58 0.00 0.00 0.00 0.00 4000.00 38.81 75.11 3617.27 256.64 1266.89 1292.21 0.00 0.00 0.00 0.00 4100.00 38.81 75.11 3695.19 272.75 1327.46 1354.85 0.00 0.00 0.00 0.00 4200.00 38.81 75.11 3773.11 288.85 1388.03 1417.49 0.00 0.00 0.00 0.00 4300.00 38.81 75.11 3851.04 304.96 1448.59 1480.12 0.00 0.00 0.00 0.00 4400.00 38.81 75.11 3928.96 321.06 1509.16 1542.76 0.00 0.00 0.00 0.00 4500.00 38.81 75.11 4006.88 337.17 1569.73 1605.39 0.00 0.00 0.00 0.00 4600.00 38.81 75.11 4084.81 353.27 1630.30 1668.03 0.00 0.00 0.00 0.00 4700.00 38.81 75.11 4162.73 369.38 1690.87 1730.66 0.00 0.00 0.00 0.00 4800.00 38.81 75.11 4240.65 385.48 1751.44 1793.30 0.00 0.00 0.00 0.00 4900.00 38.81 75.11 4318.57 401.59 1812.01 1855.94 0.00 0.00 0.00 0.00 5000.00 38.81 75.11 4396.50 417.69 1872.58 1918.57 0.00 0.00 0.00 0.00 5100.00 38.81 75.11 4474.42 433.80 1933.15 1981.21 0.00 0.00 0.00 0.00 5200.00 38.81 75.11 4552.34 449.90 1993.72 2043.84 0.00 0.00 0.00 0.00 5300.00 38.81 75.11 4630.27 466.01 2054.29 2106.48 0.00 0.00 0.00 0.00 5393.26 38.81 75.11 4702.83 480.96 2110.96 2165.06 0.00 0.00 0.00 0.00 Section 8 : Start MD Incl Azim TVD +N/-S +E/~W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg ............-..~.~~--_.-.~._.........~....,~-~.._-~-~.~.~..~..~.~~~.~~..~._..........'~~ . _----'-~~...,_,,_.~_...,~...._____.......,~.............._~~......_.~._.__,.~.~__~____...........___~_______.,,_.........;._..~.~,~__u..._., ..":..._~~,__..........;......:.-...,,.w_._~..~_.......,. ~.;,. __"'-.....~_...w.~.~_~_~w... 5400.00 38.68 75.14 4708.09 482.04 2115.04 2169.27 2.00 -1.97 0.51 170.88 5500.00 36.70 75.68 4787.22 497.45 2174.20 2230.38 2.00 -1.97 0.53 170.85 5600.00 34.73 76.26 4868.40 511.61 2230.83 2288.75 2.00 -1.97 0.58 170.43 5700.00 32.76 76.90 4951.55 524.51 2284.87 2344.29 2.00 -1.97 0.64 169.96 5790.07 31.00 77.55 5028.00 535.02 2331.27 2391.87 2.00 -1.96 0.72 169.33 Section 9 : Start MD Incl Azim TVD +N/.S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1 OOft· deg/10Oft . deg/1 000 . deg 5800.00 30.80 77.55 5036.52 536.12 2336.25 2396.97 2.00 -2.00 0.00 179.99 5900.00 28.80 77.55 5123.29 546.83 2384.78 2446.67 2.00 -2.00 0.00 179.99 5999.80 26.81 77.55 5211.57 556.87 2430.24 2493.22 2.00 -2.00 0.00 -179.99 Section 10 : Start MD Incl Azim TVD +N/-S +E/- W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/1 Daft deg/1 OOft· deg/1 000 deg 6100.00 26.81 77.55 5301.00 566.61 2474.37 2538.42 0.00 0.00 0.00 0.00 6200.00 26.81 77.55 5390.25 576.34 2518.41 2583.52 0.00 0.00 0.00 0.00 6247.89 26.81 77.55 5433.00 580.98 2539.48 2605.09 0.00 0.00 0.00 0.00 Survey Map Map <-- . Latitude --> <-- Longitude-> MD Incl Azim TVD +N/-S +E/- W Northing Easting Deg Min See Deg Min See ft deg deg ft ft ft ft ft 83.00 0.00 0.00 83.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 100.00 0.00 0.00 100.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 200.00 0.00 0.00 200.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 300.00 0.00 0.00 300.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 400.00 0.00 0.00 400.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 500.00 0.00 0.00 500.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 600.00 0.00 0.00 600.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 700.00 0.00 0.00 700.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 800.00 0.00 0.00 800.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 850.00 0.00 0.00 850.00 0.00 0.00 5959351.00 612049.00 70 17 52.409 N 149 5 33.340 W 900.00 0.50 90.00 900.00 0.00 0.22 5959351.00 612049.22 70 17 52.409 N 149 5 33.334 W 950.00 1.00 90.00 949.99 0.00 0.87 5959351.01 612049.87 70 17 52.409 N 149 5 33.315 W ) BP Amoco ) Planning Report - Geographic çQlDpany: BPAmocQ· ))ate: . ...2/28/200? .. .. .. ... ..... . Time: ... ..13:47:03 . ... ..... .. Field: PnJdhq~Bay .. çô-or~.inate(NÏ1:) R.ef~tenêe: 'lVal.I:. W,?1?,rrqe t-J0~h .. . Site: .. 'PBVVPad Vefti~ar(TYDJ ~eference: J: 01~/12/1~88 00:00 83~0 . Well: W1212; . Section (VS) Rëferëncë: Well (0;OÖN;O.OOE;77.11I\zi) Wellp~tb: . PlanW-212 · ·Plan:.. W~212wp05 . Survey lVI~P MIlP. <:-f-;';Latitüde. .-~. . MD ..Noi'thil1g E;asting ~)eglVIin. S~c·· . ff ft ft 1000.00 5959351.03 612051.07 70 17 52.409 N 149 5 33.280 W 1100.00 5959351.10 612055.43 70 17 52.409 N 149 5 33.153 W 1200.00 5959351.20 612062.40 70 17 52.409 N 149 5 32.950 W 1300.00 6.25 90.00 1299.17 0.00 22.99 5959351.34 612071.99 70 17 52.409 N 149 5 32.670 W 1400.00 7.75 90.00 1398.42 0.00 35.18 5959351.52 612084.17 70 17 52.409 N 149 5 32.315 W 1416.67 8.00 90.00 1414.93 0.00 37.46 5959351.56 612086.45 70 17 52.409 N 149 5 32.248 W 1500.00 10.08 90.00 1497.22 0.00 50.55 5959351.75 612099.54 70 17 52.409 N 149 5 31.867 W 1600.00 12.58 90.00 1595.26 0.00 70.20 5959352.05 612119.19 70 17 52.409 N 149 5 31.294 W 1700.00 15.08 90.00 1692.35 0.00 94.11 5959352.40 612143.09 70 17 52.409 N 149 5 30.597 W 1776.67 17.00 90.00 1766.04 0.00 115.30 5959352.72 612164.28 70 17 52.409 N 149 5 29.979 W 1800.00 17.00 90.00 1788.35 0.00 122.12 5959352.82 612171.10 70 17 52.409 N 149 5 29.781 W 1900.00 17.00 90.00 1883.98 0.00 151.36 5959353.26 612200.33 70 17 52.409 N 149 5 28.928 W 2000.00 17.00 90.00 1979.61 0.00 180.60 5959353.69 612229.56 70 17 52.409 N 149 5 28.076 W 2100.00 17.00 90.00 2075.24 0.00 209.83 5959354.13 612258.79 70 17 52.409 N 149 5 27.224 W 2125.89 17.00 90.00 2100.00 0.00 217.40 5959354.24 612266.36 70 17 52.409 N 149 5 27.003 W 2200.00 19.73 86.34 2170.33 0.80 240.72 5959355.39 612289.67 70 17 52.417 N 149 5 26.323 W 2300.00 23.51 82.73 2263.28 4.40 277.37 5959359.54 612326.25 70 17 52.452 N 149 5 25.255 W 2400.00 27.34 80.07 2353.59 10.89 319.79 5959366.65 612368.56 70 17 52.516 N 149 5 24.019 W 2500.00 31.21 78.02 2440.80 20.23 367.78 5959376.71 612416.40 70 17 52.608 N 149 5 22.620 W 2600.00 35.11 76.39 2524.49 32.38 421.10 5959389.65 612469.53 70 17 52.727 N 149 5 21.065 W 2694.48 38.81 75.11 2599.97 46.39 476.14 5959404.48 612524.35 70 17 52.865 N 149 5 19.461 W 2700.00 38.81 75.11 2604.27 47.28 479.48 5959405.42 612527.68 70 17 52.874 N 149 5 19.363 W 2800.00 38.81 75.11 2682.19 63.38 540.05 5959422.42 612588.00 70 17 53.032 N 149 5 17.598 W 2900.00 38.81 75.11 2760.12 79.49 600.62 5959439.43 612648.32 70 17 53.190 N 149 5 15.832 W 3000.00 38.81 75.11 2838.04 95.59 661.19 5959456.43 612708.64 70 17 53.349 N 149 5 14.066 W 3100.00 38.81 75.11 2915.96 111.70 721.76 5959473.44 612768.95 70 17 53.507 N 149 5 12.301 W 3200.00 38.81 75.11 2993.89 127.80 782.33 5959490.44 612829.27 70 17 53.665 N 149 5 10.535 W 3300.00 38.81 75.11 3071.81 143.91 842.90 5959507.45 612889.59 70 17 53.824 N 149 5 8.769 W 3400.00 38.81 75.11 3149.73 160.01 903.47 5959524.45 612949.91 70 17 53.982 N 149 5 7.004 W 3500.00 38.81 75.11 3227.65 176.12 964.04 5959541.46 613010.22 70 17 54.140 N 149 5 5.238 W 3600.00 38.81 75.11 3305.58 192.22 1024.61 5959558.46 613070.54 70 17 54.299 N 149 5 3.472 W 3700.00 38.81 75.11 3383.50 208.33 1085.18 5959575.47 613130.86 70 17 54.457 N 149 5 1.707 W 3800.00 38.81 75.11 3461.42 224.43 1145.75 5959592.4 7 613191.18 70 17 54.615 N 149 4 59.941 W 3900.00 38.81 75.11 3539.35 240.54 1206.32 5959609.48 613251.49 70 17 54.774 N 149 4 58.175 W 4000.00 38.81 75.11 3617.27 256.64 1266.89 5959626.48 613311.81 70 17 54.932 N 149 4 56.409 W 4100.00 38.81 75.11 3695.19 272.75 1327.46 5959643.49 613372.13 70 17 55.090 N 149 4 54.644 W 4200.00 38.81 75.11 3773.11 288.85 1388.03 5959660.49 613432.45 70 17 55.248 N 149 4 52.878 W 4300.00 38.81 75.11 3851.04 304.96 1448.59 5959677.49 613492.76 70 17 55.407 N 149 4 51.112 W 4400.00 38.81 75.11 3928.96 321.06 1509.16 5959694.50 613553.08 70 17 55.565 N 149 4 49.346 W 4500.00 38.81 75.11 4006.88 337.17 1569.73 5959711.50 613613.40 70 17 55.723 N 149 4 47.581 W 4600.00 38.81 75.11 4084.81 353.27 1630.30 5959728.51 613673.72 70 17 55.882 N 149 4 45.815 W 4700.00 38.81 75.11 4162.73 369.38 1690.87 5959745.51 613734.03 70 17 56.040 N 149 4 44.049 W 4800.00 38.81 75.11 4240.65 385.48 1751.44 5959762.52 613794.35 70 17 56.198 N 149 4 42.283 W 4900.00 38.81 75.11 4318.57 401.59 1812.01 5959779.52 613854.67 70 17 56.356 N 149 4 40.517 W 5000.00 38.81 75.11 4396.50 417 .69 1872.58 5959796.53 613914.98 70 17 56.515 N 149 4 38.752 W 5100.00 38.81 75.11 4474.42 433.80 1933.15 5959813.53 613975.30 70 17 56.673 N 149 4 36.986 W 5200.00 38.81 75.11 4552.34 449.90 1993.72 5959830.54 614035.62 70 17 56.831 N 149 4 35.220 W 5300.00 38.81 75.11 4630.27 466.01 2054.29 5959847.54 614095.94 70 17 56.989 N 149 4 33.454 W 5393.26 38.81 75.11 4702.83 480.96 2110.96 5959863.34 614152.37 70 17 57.136 N 149 4 31.802 W 5400.00 38.68 75.14 4708.09 482.04 2115.04 5959864.48 614156.43 70 17 57.147 N 149 4 31.683 W 5500.00 36.70 75.68 4787.22 497.45 2174.20 5959880.77 614215.36 70 17 57.298 N 149 4 29.958 W 5600.00 34.73 76.26 4868.40 511.61 2230.83 5959895.77 614271.77 70 17 57.437 N 149 4 28.307 W 5700.00 32.76 76.90 4951.55 524.51 2284.87 5959909.47 614325.60 70 17 57.564 N 149 4 26.732 W ) BP Amoco ) Planning Report - Geographic c.ompany: BP Amoco. . . . Field: PrudhÞe Bäy . Site: . PB WPäd · Well: .... W-212 Wellpath: PlariW"212 ·Ï>ate: .2{28/?OÔ2 .,.¡. ... ...'.fime: y1~;4.7:03 ....... . . .... .... Ço,:,(H'dinate(NE):Rererim~e: Well:'fI.;21 g, Jru~~orth.. ... .. Vertiêal(TYµ)R~fel'êIlCe; ..1: 01~/~2/198800:00~3JO·· 'Séct1oo (VS) Réfel'encé: · · ·'WeIQO;00N,OJOOE,77J11Azi) Plan: W-212wp05·· . .. ...... . . . Survey 5790.07 31.00 77.55 5028.00 535.02 2331.27 5959920.67 614371.83 70 17 57.667 N 149 4 25.379 W 5800.00 30.80 77.55 5036.52 536.12 2336.25 5959921.84 614376.80 70 17 57.678 N 149 4 25.234 W 5900.00 28.80 77.55 5123.29 546.83 2384.78 5959933.28 614425.16 70 17 57.783 N 149 4 23.819 W 5999.80 26.81 77.55 5211.57 556.87 2430.24 5959943.99 614470.46 70 17 57.882 N 149 4 22.494 W 6100.00 26.81 77.55 5301.00 566.61 2474.37 5959954.39 614514.44 70 17 57.977 N 149 4 21.207 W 6200.00 26.81 77.55 5390.25 576.34 2518.41 5959964.77 614558.33 70 17 58.073 N 149 4 19.923 W 6247.89 26.81 77.55 5433.00 580.98 2539.48 5959969.73 614579.32 70 17 58.119 N 149 4 19.309 W ) ') RECE~'VED MAR 1 2 2002 Alaska Oil & Gas Coris. Commission Anchorage DATE 02/15/02 CHECK NO. 00205538 H 205538 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS iOO.OO VENDOR ALASKAO I LA DISCOUNT NET 100.00 00 021302 CK021302G PYMT COMMENTS: HANDLING INST: Pernit to Drill 7ee S/H - Sond....a Steinman X4750 w'~\~) IE AITACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H205538 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 4'12 00205538 PAY ONE HUNDRED &: 00/100************************************* US DOLLAR DATE 02/15/02 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 NOT VALID AFTER 120. DAYS n·'··---' --. \ (~-J~r'iLl III 2 0 5 5 :l B III I: 0 L. ~ 2 0 ~ B t¡ 5 I: 0 0 B L. a. ~ g III ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fð'1 W" 2,J 2- J J CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL v INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) Pß..,OT HOLE (PH) ANNULAR D~SAL <.1!5-ÑÕ ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, ,API No. . Production should continue to be reported as a function of the original API number stated above. . In accordance with ~O AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel' (n8:me on permit)~ Annular disposal has ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS <--J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY ~',.Y WELL NAME/¿a (.¿) - 2../<-'./ FIELD & POOL IjÚ 1\ 67"O/b~ INIT CLASS / G..-Jt~ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y 'J 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y 'J 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y 'J 5. Well located proper distance from drilling unit boundary. . . Y N 6. Well located proper distance from other wells.. . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~~~ ~ D/;.T~ 12. Permit ca~ be issued without administrativ~ approval.. . . . . Y N ~ _ 'ÿ'/¥ ~ ~ _ 13. Can permit be approved before 15-day walt.. . . . . . . . . . fJ N ENGINEERING 14. Conductor string provided '.' . . . . . . . . . . . . . . . . . @. N \e t r? 80' TV D. 15. Surface casing protects all known USDWs. . . . . . . W N. 1 16. CMT vol adequate to circulate on conductor & surf csg. . . . fl N Ad..e"Ù' -.....IV UcJ2;é:'"JS 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ 0 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . _ N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N r;)()\.,Jì-.^- l ~ . 21. If a re-drill, has a 10-403 for abandonment been approved. . . NIW 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations . . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . N J- t 26. BOPE press rating appropriate; test to t{..OOO psig. N MC;P :: 1125 fe.....' . tJ1fJ.4., C~\ 4R~ :::.. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N J 28. Work will occur without op~ration shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Ii 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . A~ _ ~T~ . 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ¥""" ~~~/)/ 34. Contact name/phone for weekly progress reports [exploratory.. ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . .. . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will no,t damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ TEMAft1lYl-S Il L-. \ COT SFD_ WGA tdí1k DTS ()~/ I<J-/ó 2- JMH APPR DATE 'V)Þ¡it .') II ~ /~ p~ S/(a.fÕ7) GEOLOGY APPR DATE PROGRAM: Exp _ Dev _ Redrll _ Serv ~Wellbore seg _ Ann. disposal para req _ GEOL AREA <¡ 7' n UNIT# C //dl ~h //£0<:3 ON/OFF SHORE cs. rJ ( t./-ooo P ~. . Y N Y N G:\geology\templates\checklist.doc ( tJo 4W/U{..k¡/ d;4þhcj Y^{'t'.ú?c.}pJ , Comments/Instructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 01 16:58:11 2002 Reel Header Service name.............LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 02/08/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Narne................UNKNOWN Continuation Number......Ol Previous Reel Narne....... UNKNOWN Comments... ... ...........S'1'S LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/08/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number...... 01 Previous Tape Name.......UNKNOWN Comments. " . . . . . . . . . . . . . . S1'S LIS Writing Lib.rary. Scient.ific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS if WELL NPlME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA W-212 500292307800 BP Exploration (Alaska), Inc. Sperry Sun 01-AUG-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22060 T. MCGUIRE A. MADSEN MWD RUN 4 AK-MW-22060 T. MCGUIRE L. VAUGHN MWD RUN 3 AK-MW-22060 T. MCGUIRE L. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 21 11N 12E 906 1185 .00 85.87 52.22 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 104.0 12.250 9.630 3410.0 # RENARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. N¡^JD RUN 1 IS DIRECTIONAL WITH N,Zl.TURAL GA/VIMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. a Od -Olof.p I097(p ) 3. MWD RUN 2 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 3 & 4 IS DIREC'rIONAL WITH DU].\L GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 3342' MD, 3109' TVD TO 3410' MD, 3163' TVD. 6. DEPTH SHIFTING / CORRECTION WAIVED PER THE EMAIL FROM D. SCHNORR Of' OS/23/02. MWD CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS .1 - 4 REPRESENT WELL W-212 WITH API # 50-029-23078-00. THIS WELL REACHED A TOTAL DEPTH OF 6330' MD, 5510' TVD. SROP SMOOTHED RJ'.TE OF PENETRATION SGRD SMOOTHED GAMMA RAY SGRC SMOOTHED GAMMA RAY COMBINED SEXP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHALLOW SPACING ) SEMP = SMOOTHED PHASE MEDIUM SPACING ) SEDP = SMOOTHED PHASE DEEP SPACING ) SFXE SMOOTHED FORMATION EXPOSURE TIME SBD2 SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 SMOOTHED STANDOFF CORRECTION (l,OW-COUNT BIN) SNP2 SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR SHI FT DERIVED RESISTIVITY SHIFT DERIVED RESISTIVITY S I-II FT DERIVED RESISTIVITY SPSF (LOW-COUNT BIN) SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT SNFA RATE SNNA RATE SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 8.75" MUD WEIGHT: 9.50 PPG MUD FILTRATE SALINITY: CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: G/CC MATRIX DENSITY: 9.30 - 300 - 400 PPM 20,000 PPM CHLORIDES 1.00 2.65 G/ee LITHOLOGY: SANDSTONE $ File Header Service name...... ... ....STSLI8.001 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02!08!Ol Maximum Physical Record..65535 File Type................LO ) Previous File Name. ......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: if FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET NPHI FCNT NCNT DRHO RHOB PEF $ and clipped curves; all bit runs merged. .5000 START DEPTH 109.0 186.5 3400.0 3400.0 3400.0 3400.0 3400.0 3400.0 3400.0 3400.0 3410.0 3410.0 3410.0 STOP DEPTH 6294.0 6330.0 6286.0 6286.0 6286.0 6286.0 6286.0 6245.5 6245.5 6245.5 6254.5 6254.5 6254.5 if BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ if MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ jj REMARKS: BIT RUN NO 1 3 4 MERGED MAIN PASS. $ MERGE TOP 109.0 3420.5 5160.5 MERGE BASE 3420.0 5160.0 6330.0 II Data Format Specification Record Data Record Type.................. 0 Data Speci. f.i.cat.ion Block. Type..... 0 Logging Direction... ...... ........Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.. ......... ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OI-IMM 4 1 68 24 7 FET MWD I-IR 4 1 68 28 8 NPI-II MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Name Service Unit DEPT FT Min 109 Max 6330 Fi rst Reading 109 Last Reading 6330 Mean Nsarn 3219.5 12443 ) ) ROP MWD FT/H 2.75 694.07 209.445 12288 186.5 6330 GR MWD API 11.25 148.02 71.2397 12371 109 6294 RPX MWD OHMM 1. 35 57.92 6.92066 5773 3400 6286 RPS MWD OHMM 1. 34 930.36 7.11415 5773 3400 6286 RPM MWD OHMM 0.43 1680.56 7.31524 5773 3400 6286 RPD MWD OHMM 1.37 2000 12.8099 5773 3400 6286 FET MWD HR 0.11 84.76 1. 24013 5773 3400 6286 NPHI MWD PU-S 13.11 71.35 41.247 5692 3400 6245.5 FCNT MWD CP30 402 1091 534.434 5692 3400 6245.5 NCNT MWD CP30 2008 3752 2672.58 5692 3400 6245.5 RHOB MWD G/CM 1.26 3.22 2.25633 5690 3410 6254.5 DRHO MWD G/CM -0.18 0.59 0.071348 5690 3410 6254.5 PEF MWD B/E 0.63 7.01 2.278 5690 3410 6254.5 First Reading For Entire File..........109 Last Reading For Entire File...........6330 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/08/01 Maximum Physical Record..65535 File Type................ LO Next File Name.. .........ST8L1B.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .02/08/01 Maximum Physical Record..65535 File Type................ LO Previous File Name. ......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: II FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 109.0 186.5 STOP DEPTH 3342.0 3420.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG rvrI N I MU¡VI ANGLE: [vI.lI.XIrvrUM .lI.NGLE: 06-APR-02 Insite 4.05.5 3.3 Memory 3420.0 . '-- 38.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGI? N.I\TURAL GAJv!M."'-. PROBE $ TOOL NU!'-IBER 012 BOREHOLE Þ~D CASING DATA ) OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 3410.0 if BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Spud Mud 9.20 320.0 9.3 350 9.5 .000 .000 .000 .000 .0 82.9 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): if REMARKS: $ if Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.. ...............Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Uni.ts....................... Datum Specificatj.on Block sub-type... 0 Name Service Order DEPT ROP MWD010 GR MWDOIO Units Size Nsam Rep Code FT 4 1 68 FT/H 4 1 68 API 4 1. 68 Offset Channel o 1 4 2 8 3 FLr:st Last Name Service Unit Min Max Mean Nsarn Reading Reading DEPT FT 109 3420 1764.5 6623 109 3420 ROP MWD010 FT/H 2.75 694.07 169.997 6468 186.5 3420 GR MWD010 API 24.44 148.02 74.8565 6467 109 3342 First Reading For Entire File..........109 Last Reading For Entire File...........3420 File Trailer Service name. ...... ......STSLIB.002 Service Sub Level Name... Version Number... .... ....1.0.0 Date of Generation.. .....02/08/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name..... ........STSLIB.003 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.......02/08/01 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD NCNT FCNT NPHI RPS RPX FET PEF DRHO RHOS ROP $ 3 ) header data for each bit run in separate files. 3 .5000 START DEPTH 3342.5 3400.0 3400.0 3400.0 3400.0 3400.0 3400.0 3400.0 3400.0 3410.0 3410.0 3410.0 3420.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 5123.5 5115.5 5115.5 5074.5 5074.5 5074.5 5115.5 5115.5 5115.5 5084.0 5084.0 5084.0 5160.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BO'rTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): fLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGf) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD fILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOff (IN): EWR fREQUENCY (HZ): 10-APR-02 Insite 4.05.5 66.37 Memory 5160.0 36.7 41. 3 TOOL NUMBER PB00099HRG6 PB00099HRG6 PB00146NL6 PB00146NL6 8.750 LSND 9.40 48.0 9.5 300 6.2 6.500 5.122 6.000 7.500 7 .0 9 ._ 7 . (I 7 . (I ) # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type... ..0 Logging Direction.................Down Optical log depth units.... ... ... .Feet Data Reference Point..............Undefined Frame Spacing......... .... ... ... ..60 .1IN Max frames per record. .... ...... ..Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CP30 4 1 68 36 10 NCNT MWD030 CP30 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3342.5 5160 4251.25 3636 3342.5 5160 ROP MWD030 FT/H 17.81 547.83 300.395 3480 3420.5 5160 GR MWD030 API 11.25 124.83 63.962 3563 3342.5 5123.5 RPX MWD030 OHMM 1. 99 57.92 8.30602 3432 3400 5115.5 RPS MWD030 OHMM 1. 95 930.36 8.6493 3432 3400 5115.5 RPM MWD030 OHMM 0.43 1680.56 9.02802 3432 3400 5115.5 RPD MWD030 OHMM 1. 98 2000 18.2552 3432 3400 5115.5 FET MWD030 HR 0.11 84.76 1.4173 3432 3400 5115.5 NPHI MWD030 PU-S 17.83 71.35 43.8082 3350 3400 5074.5 FCNT MWD030 CP30 402 887 513.88 3350 3400 5074.5 NCNT MWD030 CP30 2008 3504 2606.95 3350 3400 5074.5 RHOB MWD030 G/CM 1. 26 2.72 2.20219 3349 3410 5084 DRHO MWD030 G/CM -C).18 0.41 0.0645357 3349 3410 5084 PEF MWD030 B/E 0.63 4.57 2.35523 3349 3410 5084 First Reading For Entire File..........3342.5 Last Reading For Entire File...........5160 File Trailer Service name. ...... ... ...STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/08/01 Maximum Physical Record..65535 File Type.... ............LO Next File Name...........STSLIB.004 t'hysical EOF File Header Service name. .... ....... .STSLIB.004 Service Sub Level Name... Version Number...........1. Date of Generation... ....02 0 /01 Maximum Physical Record..65 3 ) File Type................ LO Previous File Name.......STSLIB.003 Comment Record F'I L8 HEADER FILE NUMBER: RA.W MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI rCNT NCNT PEF RHOB DRHO RPS RPX RPM RPD FET GR ROP $ 4 ) header data for each bit run in separate files. 4 .5000 S'l'ART DEPTH 5075.0 5075.0 5075.0 5084.5 5084.5 5084.5 5116.0 5116.0 5116.0 5116.0 5116.0 5124.0 5160.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOF1:'WARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ STOP DEPTH 6245.5 6245.5 6245.5 6254.5 6254.5 6254.5 6286.0 6286.0 6286.0 6286.0 6286.0 6294.0 6330.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELEC'rROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD G\KE AT MT: NEUTRON TOOL M.Z\TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST.~DOFF (IN): EWR FREQUENCY (HZ): ll-APR-02 Insite 4.05.5 66.37 Memory 6330.0 25.5 39.5 TOOL NUMBER PB00099HRG6 PB00099HRG6 PB00146NL6 PB00146NL6 8.750 LSND 9.40 46.0 8.8 400 6.0 6.500 4.944 6.000 7.500 72.0 96.8 72.0 72.0 ) REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....O Logging Direction. ................Down Optical log depth units.... .......Feet Data Reference Point... ...........Undefined Frame Spacing.....................60 .1IN Max frames per record.... ... ......Undefined Absent value..................... .-999 Depth Units......... . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units S:ize Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OI-lMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5075 6330 5702.5 2511 5075 6330 ROP MWD040 FT/H 15.14 519.2 183.226 2340 5160.5 6330 GR MWD040 API 25.88 138.13 72.3251 2341 5124 6294 RPX MWD040 OHMM 1.35 31.91 4.88967 2341 5116 6286 RPS MWD040 OHMM 1. 34 28.99 4.86357 2341 5116 6286 RPM MWD040 OHMM 1. 32 38.88 4.8042.5 2341 5116 6286 RPD MWD040 OHMM 1.37 22.2 4.827 2341 5116 6286 FET MWD040 HR 0.2 16.84 0.980397 2341 5116 6286 NPHI MWD040 PU-S 13.11 54.08 37.5835 2342 5075 6245.5 FCNT MWD040 CP30 451. 86 1091 563.835 2342 5075 6245.5 NCNT MWD040 CP30 2368 3752 2766.45 2342 5075 6245.5 RHOB MWD040 G/CM 1.99 3.22 2.33378 2341 5084.5 6254.5 DRHO MWD040 G/CM -0.07 0.59 0.0810935 2341 5084.5 6254.5 PEF MWD040 B/E 1. 26 -, . 01 2.16751 2341 5084.5 6254.5 First Reading For Entire File..........5075 Last Reading For Entire File......... ..6330 ¡.'ile Trailer Service name.......... ...STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/08/01 Ma~imum Physical Record..65535 Fi 1 e Type........... _ . . _ . LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Da t e _ . . . . . . . . . . . . . . . _ . . . . 02/ 08 / I) 1 Ori,;¡in. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNO¡"JN Continuation NumbeL-...... 01 Next Tape Name......... ..UNKNOHN ) ) Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/08/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name........... UNKN01t\IN Comments...... ....... ... .STS LIS Wr.iting Library. Scientific Technical Services Physical EOF Physical EO£' End Of LIS File