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Home My WebLink About200-197MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-216 PRUDHOE BAY UN POL S-216 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 S-216 50-029-22989-00-00 200-197-0 G SPT 4841 2001970 1500 1473 1475 1473 1473 0 0 0 0 4YRTST P Sully Sullivan 9/29/2025 no issues 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 S-216 Inspection Date: Tubing OA Packer Depth 0 2627 2557 2548IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS251001135120 BBL Pumped:3.7 BBL Returned:2 Wednesday, October 22, 2025 Page 1 of 1           Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-216 200197 500292298900 4 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 Hilcorp North Slope, LLC Stan Golis, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 12/15/2021 Chris Wallace, Senior Petroleum Engineer Dave Roby, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Investigation of Self-reported Unauthorized Injection of Miscible Injectant (MI) into PBU Polaris S-216 (PTD# 200197), Hilcorp North Slope (HNS), LLC. Dear Mr. Wallace and Mr. Roby, Please see below for investigation information compiled in regards to the self-reported discovery of unauthorized injection of MI into PBU Polaris S-216 (PTD# 200197) on 12/8/2021. Well History and Event Summary: S-216 was approved for a RWO and conversion to WAG service under Sundry #321-216 on 5/14/2021. This sundry was rescinded on 7/20/2021 due to MI service in the Polaris Pool being authorized on an individual well basis upon Administrative Approval (AA) request (AIO 25A, Rule 2). HNS submitted an AA request for MI service to the AOGCC on 8/18/2021 and received confirmation of delivery for processing. A new RWO Sundry (#321-364) was approved authorizing WINJ service only and the RWO was completed in late August. An AOGCC witness waived MIT-T and MIT-IA passed on the rig to 3100 psi on 8/16/2021 and an online (PWI) AOGCC witnessed MIT-IA passed to 3044 psi on 9/2/2021. The well was on water injection from 8/30- 11/7/2021 and swapped to MI on 11/9/2021. S-216 then remained on MI until the operations engineer discovered the misinjection on 12/8/2021 at which time the well was immediately shut-in. Investigation Details: Length of time unauthorized MI injection took place: 11/9/2021- 12/8/2021 Root cause of the incident: Based on a 5-Whys (Appendix 1) review of the incident the root causes were found to be: Inadequate work process: - Well placed on WAG swap schedule prior to receiving AA approval. - Reservoir Engineer failed to confirm AA request status prior to WAG swap execution. Inadequate training: - New Well/ injection service change verification requirements not clearly communicated to staff. Inadequate oversite: - No automated system in place to flag unauthorized injection based on well type. Actions to prevent recurrence: By Samantha Carlisle at 2:21 pm, Dec 15, 2021 x Hilcorp AOGCC Injector training updated to include review of applicable Permits, AIOs, DIOs, AAs and verification of authorized well service type prior by Reservoir Engineer submitting injection request to the field operator. x Immediate reissue of training to Alaska Reservoir Engineers. To be completed by 3/31/2021. x Update daily HNS Integrity Compliance Report to flag for unauthorized injection. If you have any questions, please call me at 907-777-8356 or Oliver Sternicki at 907-564-4891. Sincerely, Stan Golis PBW Operations Manager Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.12.15 14:02:31 -09'00' Stan Golis (880) Appendix 1: 5-Why Tree Diagram MEMORANDUM TO: Jiin Regg 90 (1 c z --f P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 8, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S-216 PRUDHOE BAY UN POL S-216 Src: Inspector Reviewed By: P.I. Supry Comm Well Well Name PRUDHOE BAY UN POL S-216 API Well Number 50-029-22989-00-00 Inspector Name: Austin McLeod Insp Num: mitSAM210902203551 Permit Number: 200-197-0 Inspection Date: 9/2/2021 , Rel Insp Num: Notes' Post RWO. Tested to target of 2750. Sundry 321-364. " Pretest Initial 15 Min 30 Min 45 Min 60 Min 1243 _ 1245 1244 - 1244 - - — 8 3096 - 3051 - 3044 156 _ 459 450 442 Wednesday, September 8, 2021 Page 1 of I Packer Depth Well S-216 (Type Inj w TVD 4653 Tubing PTD 2001970 Type Test SPT Test psi 2750 IA BBL Pumped: 3.9 BBL Returned: 2.5 OA Interval OTHER 'PIF P Notes' Post RWO. Tested to target of 2750. Sundry 321-364. " Pretest Initial 15 Min 30 Min 45 Min 60 Min 1243 _ 1245 1244 - 1244 - - — 8 3096 - 3051 - 3044 156 _ 459 450 442 Wednesday, September 8, 2021 Page 1 of I Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:200-197 6.50-029-22989-00-00 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 8713 8605 5522 None None Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 3542 9-5/8" 29 - 3571 29 - 2871 5750 3090 Intermediate Production 8672 7" 26 - 8698 26 - 5611 8160 7020 Perforation Depth: Measured depth: 7980 - 8330 feet True vertical depth: 4930 - 5257 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L80 24 - 8345 24 - 5357 7877, 8039, 8139 4841, 4983, 5075Packers 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 1850000 19630 50 0 0 1246 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 5 WAG 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 measured5625 Sundry Number or N/A if C.O. Exempt: 321-364 4-1/2" HES TNT Packers 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 0028257, 0028258, 0028261 PBU S-216 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 Clean out Cement Plug, Install Regulated Injection Completion 7877, 8039, 8139, 8216, 8285 4841, 4983, 5075, 5149, 5214 No SSSV Installed 8216, 8285 5149, 5214 By Samantha Carlisle at 4:21 pm, Sep 08, 2021 and 321-216 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.08 15:28:10 -08'00' Stan Golis (880) RBDMS HEW 9/10/2021 MGR12OCT2021 DSR-9/8/21 SFD 9/9/2021 ACTIVITY DATE SUMMARY 3/22/2021 T/I/O = SSV/180/0. Temp = SI. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all moved freely. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min test (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (250 psi), bled void to 0 psi. Did not function LDS. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min test (PASS). Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA & OA = OTG. 11:00. 5/19/2021 **WELL SHUT IN ON ARRIVAL** BRUSH TBG TO X-NIP @ 7553'MD w/ FULLBORE BLB & 2.80" GAUGE RING. SET X CATCHER SUB @ SAME PULLED DMY @ 7524'MD **WSR CONT ON 5/20/21** 5/20/2021 **WSR CONT'D FROM 5/19/21** SET RK-FLOWSLEEVE @ 7524'MD PULLED X-CATCHER SUB @ 7553'MD DRIFTED w/ 2.72" CENTRALIZER TO TAG TD @ 7768'SLM **WELL S/I ON DEPARTURE** 6/13/2021 T/I/O= 0/274/1. LRS unit 70 Circ Out ( RWO EXPENSE). Spear into TBG W/ 2 bbls 60/40, Followed by 284 bbls 1% Kcl taking returns up IA to F/L of S-43. Freeze protect TxIA with 74 bbls DSL, U-tube 1 hr. CMIT-TxIA to 1000 psi *PASSED* at 1029 psi (1250 psi max applied pressure). T/IA lost 22/23 psi during the 1st 15 minutes and 19/19 psi during the 2nd 15 minutes. Pumped 1.6 bbls of 46* F diesel to achieve test pressure. bed back 1.3 bbls to Final T/I/O= 0/0/0. Freeze protect the outlet flowline of S-43 per Operator (long term shut in). Pumped 5 bbls of 60/40 MeOH. Closed the divert and pressured up to 1000 psi. 6/18/2021 Alaska E-line: Chem. Cut Tbg. RUN 1: ATTEMPTED TO MAKE IT TO DEPTH TO DO STRING SHOT RUN 2: PERFORM STRING SHOT OVER INTERVAL 7627' - 7636' RUN 3: CUT TUBING AT 7635', CCL TO CUT 11', CCLSTOP DEPTH = 7624' Job Continued on 6/19/21*** 6/19/2021 Alaska E-line: Chem. Cut Tbg. Job Continued from 6/18/21 RUN 1: PERFORM STRING SHOT OVER INTERVAL 7565' - 7574' RUN 2: CUT TUBING AT 7572', CCL TO CUT 11', CCLSTOP DEPTH = 7561' 30 min CMIT-TxIA passed to 1000 psi BLEED TXIA TO 0 PSI Job Complete 6/26/2021 T/I/O = SSV/vac/0+. Temp = SI. OA integrity test Passed (Pre RWO). No wellhouse, scaffolding or flooring. OA FL @ 50' (1.3 bbls). Used 1.9 bbls of DSL to increase the OAP to 1200 psi. The OAP decreased 40 psi in 5 minuts. No response seen at surface. Bled the OAP (.6 bbls, all fluid). Tag hung. FWPs = SSV/vac/0. SV, WV = No scaffolding. SSV = C. MV = O. IA, OA = OTG. 12:45 Daily Report of Well Operations PBU S-216 Daily Report of Well Operations PBU S-216 7/21/2021 T/I/O = 0+/0+/20. Temp = SI. CMIT Tx IA Passed to 2932/2939 psi (Pre RWO). Max applied pressure = 2989/2997 psi. Test pressure = 2750 psi. No wellhouse, scaffolding or flowline. TBG & IA FL's @ surface. Pumped 3.7 bbls of DSL down the IA to pressure up the TBG/IA to 2989/2987 psi. The TBG/IA lost -40/-41 psi in 15 minutes and -17/-17 psi in the second 15 minutes for a total 30 minute loss of -57/-58 psi. Bled the IAP 3.4 bbls. Tag hung. FWPs = 0/0/20. SV, WV. SSV = C. MV = O. IA, OA = OTG. 16:40 7/26/2021 T/I/O = 0/0/0. Set CTS #2 w/ dry rod. ND 4-1/16" calico tree w/ LEO actuator and 11" 5M FMC THA. Wellhead tech functioned LDS, set & tested plug in CTS. NU 13-5/8" 5M YJ BOP w/ 13"x11" DSA and shooting flange. RU intergals to IA/OA. Removed floor kit from S-200. RDMO. ***Job Complete*** Added HAL cost for packer, GLM, WFRM and landing Nip. 7/29/2021 Thunderbird Rig 1 Job Scope: Recomplete. MIRU. Spot base beam on 15' on center location. Attempt to spot rig. Dirt work required to get rig jacked up level. Spot rig and equipment. Yellowjacket assist with installation of 2-7/8 x 5-1/2" VBR's. ...Continue WSR on 7/30/2021... 7/30/2021 Thunderbird Rig 1 Job Scope: Pull TBG. Mill/Fish 2 packers. Mill CMT and cleanout sand. Run WFR Completion. ...Continue WSR from 7/29/2021... Continue with rig up. Function and Shell Test BOPE. AOGCC witness wavied by Bob Noble. Test gas alarms. BOPE tested to 250/3000 per Sundry requirements. Tested PVT and flowline indicator alarms. Slip and cut drill line. Pull test plug . ...Job in progress... 7/31/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Pakers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packers. ...Continue WSR from 7/30/2021... Continue working pipe in an attempt to finish cut. R/U Eline and chemical cut @ 7566' MD Reference Doyon 14 Tubing Tally Date:8/8/2021. Blew fuse and 1st cutter didn't discharge. Made second run to cut @ same depth. BOLDS and work pipe 40 minutes to pull free @ 124K (74K over) PU was 50K. Line on drum jumped wraps/loose wraps. Secure blocks and re-spool line on drum. Start pulling completion. ...Continue WSR on 8/1/2021... 8/1/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Pakers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packers. ...Continue WSR from 7/31/2021... Pulled 3-1/2" 8rd completion. OOH discivered RCT didn't completely penetrate and we pulled free atthe original chemiacl cut made @ 7572'. Check all equipment for NORM. Send tbg to CSP for scrap and GLMs to have DGLVs pulled. NU BIW head and power swivel. MU and RIH w/ and RIH w/ BHA #1 5.75" Flat bottom burn shoe w/ extension to cover 13.7', 4.75" bumper jar, oil jar, (6) 4.75" DC's, Accel., OAL 232.8'. Tripping drill and AAR RIH and tag top of TBG stub at 7572' PU drop a joint and installe BWI head for milling. ...Continue WSR on 8/2/2021... 8/2/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Pakers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packers. ...Continue WSR from 8/1/2021...Tag and mill upper PKR starting at 7572' had problems with weight transfer to BHA bottom during milling process. Added EP Mud Lube to power fluids. Weight transfer issues cleared up and continued milling. Made 31" down over PKR with no sign of assembly releasing. Desision was made to TOOH and look at mill. ...Continue WSR on 8/2/2021... Daily Report of Well Operations PBU S-216 8/3/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Pakerss/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/2/2021... TOOH and stand back work string. Trip i Hole w/ BHA #2 w/ 5-3/4" OD Overshot, 4-3/4" bumper sub, oil Jar, pump-out sub, (6) DC's, and accelerator, and 2-7/8" PH6 work sting. Resume milling @ 7676'.good indication milled through packer element by pressure increase and having to PU off to get pressuer down. Rubber from PKR element returned and caught in junk basket at pits. Continue working milling assembly on rings just above lower slips. ... Continue WSR on 8/4/2021... 8/4/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Pakerss/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/3/2021... Resume milling @ 7578'. Milled to 7859'. TOH with burnshoe mill due to lack of progress - shoe was badly worn. TIH w/ packer fishing BHA -> 5-7/8" OD Overshot (w/ 3-1/2" grapple), bumper sub, oil jar, 4-3/4" OD slick DC's, Accel., (BHA 219.44'), Up Wt 51K, SO Wt 32K, Tag fish @ 7859'. Attempt to work free. Jar once - fish free. TOH. ... Continue WSR on 8/5/2021... 8/5/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Pakerss/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/4/2021... Continue to TOH with upper packer fishing BHA. Recovered upper packer (slips & rubber missing), 2-3.5"x10ft pup joints, X profile & unique overshot - all ok & cut looked good. Send off weekly AOGCC BOP test notification. Trip in hole with 5-7/8" Overshot (with 3-1/2" short catch grapple), 4.75" bumper sub, 4.75" oil jar, 4.75" slick drill collars, accelerator (BHA 219.44') using 2-7/8" PH6 work string from derrick. Locate & latch 3.5" tubing stub at 7604ft. 9k over pull & pulled free. Trip out of hole with 3.5" tubing fish, standing back 2-7/8" PH6 work string doubles in the derrick. Recovered & laid down ->3.5" tubing stub - 12.8' of full joint on top, pup jt, XN, pup, 7.68'. Cut is flared to 4-11/16" od. Roughly 2ft of the original 3.5" completion remains in hole (attached onto of packer). Prep & begin weekly BOP test to 250psi low & 3000psi high. AOGCC vaived witnessed BOP test (Brian Bixby) ... Continue WSR on 8/6/21 ... 8/6/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/5/2021... Continue to perform weekly BOPE test to 250psi low & 3000psi high, no failures. Trip in hole w/ BHA #5 --> 2.716"x4-1/4" 4 bladed pilot mill, 4.75" bumper sub, oil jar, pump-out sub, (6) slick 4.75" DC's, accelerator and 2-7/8" PH6 work sting from derrick. Engage & mill 3-1/2" tubing stub from 7644.75' to 7645.25'. Trip out of hole, standing back 2-7/8" PH6 work string doubles in the derrick. Lay down mill. Mill had good wear on leading edge of blades, with no wear on end of pilot - indicating clean 3.5" tubing stub. Trip in hole w/ BHA #6 --> 5-3/4" OD x 4.5" ID burn shoe, 4.75" bumper sub, oil jar, pump-out sub, (6) slick 4.75" DC's, accelerator and 2-7/8" PH6 work sting from derrick. ...Continue WSR on 8/7/21... Daily Report of Well Operations PBU S-216 8/7/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/6/2021... Continue to trip in hole w/ BHA #6 & 2-7/8" PH6 work string from the derrick. RIH and tag top of packer crossover at 7627.25'. RU BWI rotating head & power swivel head for milling. Swap to clean 8.4ppg 1% KCL fluids and mill to 7650.4'. Trip out of hole with burnshoe mill due to lack of progress. Stand back 2-7/8" PH6 work string in the derrick. ...Continue WSR on 8/8/21... 8/8/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/7/2021... Continue to trip out of hole with burnshoe mill. Leading edge of mill was in good shape, indicating spinning on packer wear ring. Trip in hole w/ BHA #7 --> 5-7/8" OD short catch grapple dressed for 3-1/2", 4.75" bumper sub, oil jar, pump-out sub, (6) slick 4.75" DC's & 2-7/8" PH6 work string from the derrick. Latch & work packer at 7645'. One jar lick & free. Trip out of hole, standback 2-7/8" PH6 work string in the derrick & lay down partial packer fish - crossover sub that was on top of packer released from packer. Trip in hole with BHA #8 --> 5.75" flat bottom Packer Burn Shoe Mill, Bumper Sub, Jar, 6 4-3/4" Drill Collars and Accelerator 2-7/8" PH6 work string from the derrick. Rig up rotating head & power swivel. Tag & burn over packer from 7648.8'. ...Continue WSR on 8/9/21... 8/9/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/8/2021... Continue to burn over packer from 7648.8' using 60spm at 260 psi with 2K Ft/ Lbs torque with 3K WOB, taking returns through the work string. Mill to 7650.0'. Rig down power swivel & circulating head. Rig up riser. Trip out of hole, standing back 2- 7/8" PH6 work string. Lay down burnshoe mill - worn on leading edge. Trip in hole with BHA # 9 --> Itco Spear with carbide bull nose and 5-1/2" No-Go, grapple size 3.885" Nominal Catch (3.812" minimum and 3.958" maximum), Bumper Sub, Jar, 6 4- 3/4" Drill Collars and Accelerator & 2-7/8" PH6 work string from the derrick. Latch & work packer at 7648.8'. Jar packer free & run in hole freely to 9655'. Trip out of hole, standback 2-7/8" PH6 work string in the derrick. Lay down bottom hole assembly & lay down packer fish. Recovered all 3-1/2" tubular components below packer. ...Continue WSR on 8/10/21... Daily Report of Well Operations PBU S-216 8/10/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/10/2021... Continue to lay down packer fish - all components recovered. Pressure test casing to 2850psi for operational assurance - pass. Trip in hole with BHA # 10 --> 6" tri-cone bit, bit sub, Bumper Sub, Jar, 6 4-3/4" Drill Collars and Accelerator & 2-7/8" PH6 work string from the derrick. Rig up rotating head & power swivel. Tag & drill cement from 7742'. Drill using hi-vis sweeps at 4.5 BPM with 750 to 850 psi. pump pressure with rotating weight 44K, pick up weight 56K, slack off weight 37K, 60 to 70 RPMs and off bottom torque at 1500 Ft/ Lbs, on bottom torque 2000 to 2300 Ft/ Lbs. Swap to new fluids at 8050'. Clean pit #2. Rig up 2nd upright. Rig up 2nd flow back tank. Drill to midnight depth of 8090'. ...Continue WSR on 8/11/21... 8/11/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/11/2021... Continue to drill cement from 8090' with 6" bit using 4.5 BPM with 750 to 850 psi. pump pressure with rotating weight 44K, pick up weight 56K, slack off weight 37K, 60 to 70 RPMs and off bottom torque at 1500 Ft/ Lbs, on bottom torque 2000 to 2300 Ft/ Lbs. Notify At 8,345' md Drill string packed off. Attempt to clear drill string unsucessfully. POOH for drill string pack off. F/8345' . Notify AOGCC for weekly BOPE test.- Witness waived by Lou Laubenstein ...Continue WSR on 8/12/21... 8/12/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/12/2021... Cont POOH for plugged drill string. LD BHA. RU and Test BOPE per Sundry. 24Hr notice given to the AOGCC, witness waived by Lou Laubenstein. Test with 2-7/8" & 4- 1/2" Test Joints to 250 psi Low/ 3000 psi High. RD Test Equipment. Pull test Plug. Install 7" ID Wear ring. Make up Cement milling BHA BHA #11, 6-1/8" Milling assembly. 6-1/8" Mill Tooth Bit, Bumper Sub, Jar, 6 4-3/4" Drill Collars and 4-3/4" Intensifier and a single joint of 2-7/8" PH6 Drill Pipe. RIH on stands from derrick. MU Swivel, Tag cement at 8,335' md. Cont milling cement from 8,335' md ...Continue WSR on 8/13/21... 8/13/2021 ***TB RIG JOB*** ( JOB SCOPE: PERFORATING) RIG UP HES ELINE UNIT ON TB RIG. MU & RIH W/ 2-7/8" MAXFORCE PERF GUNS #1. CORRELATE TO SPERRY SUN MWD LOG 24-DEC-2000. ***CONTINUE JOB ON 8/15/21*** Daily Report of Well Operations PBU S-216 8/13/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/12/2021... Cont Drill Cement from 8,335' md to 8,517' md. Tag top of sand at 8,517' md. Wash & ream down from 8517' to 8,605'. Confirm PBTD at 8,605'. POOH with milling BHA F/ 8600' md standing back 2-7/8" PH6 Drill Pipe.Break and LD Milling BHA #11. Break Culdron off and Nipple up shooting flange for Perf Gun Run. Inspect gun configuration wtih HES. Verify Gun/Blank spacing. Spot and RU Halliburton Eline for perf runs. Load perf guns on rack, Make up safety joint for well control. PU & MU 4 Perf guns for perf interval # 1. (8240'-8330') 2-7/8" Max force, 6 spf. Clear Rig floor & Make up firing head. RIH ...Continue WSR on 8/14/21... 8/14/2021 ***CONTINUE RIG JOB FROM 8/14/21*** PERFORATE INTERVALS: 8240' - 8260', 8296' - 8316' & 8320' - 8330'. POOH. ALL SHOTS FIRED. RIH W/ 2-7/8" MAXFORCE PERF GUN RUN #2. PERFORATE INTERVALS: 8090' - 8130', 8150' - 8210'. POOH. ALL SHOTS FIRED. RIH W/ 2-7/8" MAXFORCE PERF GUN RUN #3. PERFORATE INTERVAL: 7980' - 7995'. POOH ALL SHOTS FIRED. RELEASED FROM RIG. RIG DOWN ELINE. ***JOB COMPLETE*** 8/14/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/13/2021... Cont RIH with Perf gun run #1 (4) guns. Pull Correlation Pass. Send Log data to Geo Kevin Eastham for Tie in confirmation. Shoot interval #1, (8240'-8330') 2-7/8" Max force, 6 spf, 60deg phase. Confirm well is stable. POOH with guns from 8,330' to 100'. Flow check well prior to Breaking pack off. Break and Laydown guns. MU Perf gun run # 2 . (6) guns. Same guns as first run. RIH correlate & fire guns for interval #2 ( 8090' - 8210'). Good indication of fire. POOH & LD guns. PU/MU single gun for run #3. (7980' -7795') Correlate and fire guns. POOH laying down drill pipe. Pulled 30 joints filled the hole. Hole took 9 bbls, 7 bbls over displacement. Pulled 30 more and well went on complete losses. Attempted to fill the hole to surface. Pumped 35 bbls at 3 bpm with no fluid to surface. Slowed rate to conserve fluid until more fluid was brought out. Filled the hole at ~1.2 bpm to overcome potential gas migration. Additional fluid arrived on location. ...Continue WSR on 8/15/21... 7995' Daily Report of Well Operations PBU S-216 8/15/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/14/2021... Additional fluid arrived on location. Pumpe additional 50 bbls down backside with no fluid at surface. Line up to pump down tubing taking returns up the backside. Pumped ~45 bbls before getting returns. Shut down pump, lined up to fill the hole with 1.2 bpm down the backside while we POOH laying down dp LD BHA. Pull Wear ring. Rig up Doyon casing. PJSM, Pick Up and Make up New Completion Jewelry: 6 X-Nipples (7 total X Nipples), 9- Water Flood Mandrels, 5- Packers as per approved Tally.MU & land hanger. Spot & RU HES Eline. ...Continue WSR on 8/16/21... 8/16/2021 RWO: MU, 4-1/2 TCII landing joint 8 RH turns to tubing hanger, land @ 11.3 RKB - Run in LDS, Toque at 450 ft lbs. Wait on rig operations. Set 4¿ H TWC RDMO. Tubing hanger MPN P1000195669 8/16/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Mill & Fish Packers/Mill Cement/FCO/Add Perf/Run Completion using Eline to correlate setting depth of packer. ...Continue WSR from 8/15/2021... MU & land hanger. Spot & RU HES Eline. RIH with Gamma / CCL. Correlate depth for packers setting. Send log data to Operations engineer. Agreed correction will be to move string 12.5' up for packer setting. POOH with Eline. Make up space out pup, Land hanger, Final PUW-97K, SOW-50K. Vault Rep to RILDS. Pump 140 bbls of Inhibited 1% KCL chased with 40 bbls of 1% KCL. Drop Ball & Rod, Set Packer, MIT- T to 3,100 psi. Passing Test. Bleed Tubing to 2,000 psi and hold. MIT-IA to 3,100 psi. 24 hr notice given to the AOGCC 8/15/21. Witness waived by Matt Herrera via email. Remove VBRs from Upper pipe ram cavity. Pump 82 bbls of Diesel FP & U-tube for 1 hr. Install TWC and test from below.-Good test. RDMO. Mobilize Rig to Deadhorse for repairs. .... Final WSR Job complete....Mobilize Rig to Deadhorse for repairs prior to moving to NK-22 8/16/2021 ***TB Rig Job*** (JOB SCOPE: COMPLETIONS TIE IN) MIRU HES ELINE ON RIG. RIH GR/CCL BHA. LOG FROM 8342' - 7500' TO CORRELATE NEW COMPLETION. POOH. RELEASED FROM RIG. ***JOB COMPLETE*** 8/17/2021 T/I/O=0/0/0. ND 13-5/8" 5M YJ BOP & 11" 5M DSA. NU 11" 5M x 4-1/16" 5M FMC THA. NU 4-1/16" CIW tree. WH tech performed passing adapter void test. Install lateral pipimg & valves for S-216 twin w/ S-112. ***Job In Progress*** 8/17/2021 Clean Tubing hanger void and ring groove, install RX-54 ring gasket ¿ nipple up adapter with SBMS seal, Install RX-39 ring gasket & NU tree. Test Tubing hanger @ 5000 psi (pass). Worley to test tree and pull TWC. Tubing hanger MPN P1000195669 Adapter MPN 02-047-619 8/19/2021 T/I/O= 0/260/0 TFS unit #2 (Assist SL) Road To location Rig up. ***Job Continued on 98/20/2021*** 8/19/2021 ***WELL S/I ON ARRIVAL*** (post rwo) ATTEMPTED TO PULL BALL AND ROD FROM RHC @ 8,337' MD ***WSR CONTINUED ON 8/20/21*** Daily Report of Well Operations PBU S-216 8/19/2021 T/I/O=0/0/0. RU CIW lubricator & leak test tree to 500/5000 psi (Pass). RIH & pull 4" CIW TWC at 125". RDMO. 8/20/2021 ***WELL S/I ON ARRIVAL*** (wfr) LRS LOADED WELL W/ 200 BBLS DIESEL. RIH W/ 4 1/2" WHIDDON CATCHER TO 7880' SLM. STAND BY ON MECHANICAL ISSUES. ***WSR CONTINUED ON 8-21-21*** 8/20/2021 ***Job continued from 08/19/2021*** Job cancelled 8/20/2021 ***WSR CONTINUED FROM 8/19/21*** (wfr) 2 ATTEMPTS TO PULL BALL & ROD (thick schmoo throughout tubing) RIG DOWN SO WELL SUPPORT CAN R/U FOR CIRC OUT ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 8/20/2021 T/I/O=20/0/2 Circ-out ( RWO EXPENSE ) Pumped 50 bbls water down IA followed by 50 bbls 180* dsl followed by 230 bbls dsl at rate taking returns up TBG to open top tank . *** Job continued on 8-21-21*** 8/21/2021 ***JOB CONTINUED FROM 20-AUG-2021*** LRS Unit #76 Assist Slickline (RWO EXPENsE) Pumped 110 BBL's of 1% inhibited KCL down the IA taking returns up the TBG to tanks followed by 44 BBL's of DSL for freeze protect.***JOB CONTINUED ON 22-AUG-2021*** 8/21/2021 ***WSR CONTINUED FROM 8-20-21*** SET 4 1/2" WHIDDON CATCHER ON 3 1/2" CROSSOVER PULLED BEK-SHEAR VALVE FROM 7,751' MD LRS CIRC'D INHIBITED 1%KCL INTO IA W/ DIESEL F/P. SET BK-DGLV @ 7751' MD. PULLED 4 1/2" WHIDDON CATCHER FROM 7889' SLM. ***WSR CONTINUED ON 8-22-21*** 8/22/2021 ***WSR CONTINUED FROM 8-21-21*** PULLED B&R FROM 8330' SLM. PULLED RK-DGLV FROM WFRM# 2 @ 8261' MD (290 psi @ surface w/ diesel in tubing) SET GUTTED RK-WFRV WFRM#2 @ 8261' MD. PULLED RK-DGLV FROM WFRM #4 @ 8,192' MD (-14 psi @ surface w/ diesel in tubing) SET RK-WFR (13/64 ports, 434 bwpd) IN WFRM #4 @ 8,192' MD SET 3 1/2" X SELECTIVE TEST TOOL IN X NIPPLE @ 8,129' MD(isolate from WFRM#4) PULLED RK-DGLV FROM WFRM #6 @ 8,112' MD (775 psi @ surface w/ diesel in tubing) SET RK-WFR (13/64 ports, 434 bwpd) IN WFRM #6 @ 8,112' MD. MOVED TEST TOOL TO X NIPPLE @ 8029' MD. PULLED RK-DGLV FROM WFRM # 8 @ 8000' MD (460 psi @ surface w/ diesel in tbg). SET RK-WFR (8/64", 160 BWPD) IN WFRM # 8 @ 8000' MD. ***WSR CONTINUED ON 8-23-21*** 8/22/2021 ***JOB CONTINUED FROM 21-AUG-2021*** LRS Unit #76 Assist Slickline (RWO EXPENSE) T/I/O= 249/0/0 Pumped 51 BBL's of diesel down the tubing to assist slickline in puling valves. ***JOB CONTINUED ON 23-AUG-2021*** 8/23/2021 ***JOB CONTINUED FROM 22-AUG-2021*** (RWO EXPENSE) Assist slickline T/I/O= 497/0/0 Pumped 20 BBL's of diesel down the tubing for slickline. Slickline in control of well on departure. FWHP's T/I/O= 0/0/0 Daily Report of Well Operations PBU S-216 8/23/2021 ***WSR CONTINUED FROM 8-22-21*** PULLED 3 1/2" X SELECTIVE TEST TOOL FROM 8029' MD. PULLED 2.81" RHC-M PLUG BODY FROM 8337' MD. SET RED SPIDER INJ VALVE (RS-310) ON 2.81" X LOCK W/ EQ SUB @ 8337' MD. ***WELL S/I ON DEPARTURE. COMPLETE*** Note: All Measured depths on post rig work from 8/19/20 - 8/23/2021 are off due to wrong data being handed over. *** Post Rig GLV change out depths have been corrected in the Data tab *** 9/1/2021 T/I/O = 1200/10/80. Temp = 98°. IA FL (pre AOGCC). IA FL near surface. SV = C. WV, SSV, MV = O. IA, OA = OTG. 21:30 9/2/2021 T/I/O = 1243/8/153. Temp = 98°. AOGCC MIT-IA PASSED to 3044 psi (reg comp, witnessed by Austin McLeod). On PWI. Max pressure = 3100 psi. IA FL @ near surface. Pumped 3.9 bbls of diesel to increase IAP from 8 psi to 3096 psi. IAP lost 45 in 1st 15 min, IAP lost 7 psi in 2nd 15 min for a 30 min total of 52 psi. Bled IAP from 3044 psi to 10 psi, 2.5 bbls. Tag hung. Final WHPs = 1243/10/150. SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:30 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, August 17, 2021 7:49 AM To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector S-216 (PTD #2001970) MIT-T & IA Passed post RWO From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, August 17, 2021 6:52 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector S‐216 (PTD #2001970) MIT‐T & IA Passed post RWO Mr. Wallace, Injector S‐216 (PTD #2001970) passed MIT‐T and MIT‐IA post RWO on 08/16/21. The passing MIT’s verify two competent well barriers. The well is now classified as OPERABLE and can be put on injection once remaining tie in and post rig slickline work is complete. An online AOGCC MIT‐IA to 2750 psi will be conducted within 5 days of stabilized injection per sundry #321‐364. 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 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. 1 Guhl, Meredith D (CED) From:Rixse, Melvin G (CED) Sent:Tuesday, July 20, 2021 2:39 PM To:Brian Glasheen Cc:Roby, David S (CED); Guhl, Meredith D (CED); Davies, Stephen F (CED); Carlisle, Samantha J (CED); Stan Golis Subject:Sundry Request 321-216, PTD200-197, PTD PBU S-216 - RESCINDED Attachments:Sundry_321-216_051421.pdf Brian, Sundry Request 321‐216 for well PBU S‐216 (PTD200‐197) will be RESCINDED. The requested work is more appropriately addressed via a request by Hilcorp to modify AIO 025A. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907‐793‐1231 Office 907‐223‐3605 Cell CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907‐793‐1231 ) or (Melvin.Rixse@alaska.gov). cc. David Roby, Meredith Guhl, Steve Davies, Samantha Carlisle, Stan Golis Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:200-197 6.API Number:50-029-22989-00-00 PRUDHOE BAY, POLARIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028261 Property Designation (Lease Number):10. 8. PBU S-216 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 Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 55Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 8713 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): 5625 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 7574, 4606 / 7639, 4653 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 29 - 3571 29 - 2871 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 110 Structural Proposal Summary 13. Well Class after proposed work: 3-1/2" Baker S3 Packers None None 3-1/2" 9.2#24 - 7697 Production 7785 4765 7785 None 30 - 110 470 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 3542 5750 Intermediate 8672 7" 26 - 8698 26 - 5611 8160 7020 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 1404 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. Cleanout Cmt Plug, Install Regulated Inj Completion 55 7/28/21 By Meredith Guhl at 2:50 pm, Jul 21, 2021 321-364 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.21 14:34:54 -08'00' Stan Golis (880) , ADL 2258257, ADL0025258 SFD 7/21/2021 MGR21JUL21 SFD 7/21/2021 *BOPE test to 3000 psi. Annular to 2500 psi. *Witnessed MIT-IA to 2750 psi. 24 hour notice. *Witnessed MIT-IA within 5 days after stabilized production. DSR-7/21/21 10-404 dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 10:31:01 -08'00' RBDMS HEW 7/22/2021 RWO S-216 PTD:200-197 Well Name:S-216 API Number:50-029-22989-00-00 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:07/28/2021 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:200197 First Call Engineer:Brian Glasheen 907-545-1144 Second Call Engineer:Brodie Wages 713-380-9836 AFE Number:215-01234 IOR 281 Current Bottom Hole Pressure:1,904 psi @ 5,000’ TVD 7.6 PPGE (+0.3 SF)| SBHP S-217 04/21/19 Max. Anticipated Surface Pressure:1,404 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:630 psi (Taken on 12/11/19) Min ID:2.8” ID @ 7,617’ MD Max Angle:70 Deg @ 3,873 MD’ Brief Well Summary: S-216 is a reservoir abandoned Oa, Oba, Obb, Obc, Obd injector. S-216’s waterflood pattern < 30% HCPV in all five sands and is extremely immature. This RWO will recomplete S-216 into the Oa, Oba, Obb, Obc, Obd sands as a PW regulated injector to accelerate production from S-213A. Objective: Pull the existing 3 ½” L80 tubing out of the well, washer over both baker S-3 packers, mill/clean out cement and sand to ~8,500’MD. Replace tubing with a WFRM competition. Achieve a passing MIT-IA & MIT-T. Pre RWO work: DHD OA Integrity test Cycle LDS’s SL Pull Station 1 GLV and replace with flow sleeve FB Circulate out well with 305(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 2000 psi. a. Tubing Volume to GLM 1 is .0087 bbls/ft*7,524’ = 65 bbls b. Annular volume to GLM is .0252 bbls/ft* 7,524’ = 189 bbls (I neglected the 71’ of 4.5’’) c. Total volume to GLM1 is 254 bbls d. Rig up to neighboring producer FL or take returns to tanks. CMIT-TXIA- 1,000 psi Freeze Protect well. Pump 74 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. EL Cut tubing@ ~ 7,636’ MD (3’ above packer) Cut tubing @ ~ 7,572’ MD (2’ above packer) ** All steps above in red have been completed from prior sundry 321-216. ** PW regulated injector t RWO S-216 PTD:200-197 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 ~69.9K 5. Pull 4 ½” / 3 ½” tubing to floor. 6. Wash over both Baker S3 Packers at 7,574’ and 7,639’ MD 7. Pressure test casing to 2750 psi 8. Mill cement and sand from 7,785’ to ~8,500 MD 9. Rig up Eline and reperf all existing perfs. a. Rig up shooting nipple. This will be used only when shooting guns. 10. Run 4 ½” / 3 ½” tubing with stacker packers and waterflood regulator mandrels detailed on proposed schematic 11. Land Hanger and reverse in corrosion inhibited 8.5ppg 1%KCl 12. Drop ball and rod and set packer with 3,500psi pump pressure. 13. 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 14. Shear valve in GLM. 15. Freeze protect to ~2,000ft with diesel 16. Set TWC 17. Rig down Thunderbird #1. Post RWO 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. Post RWO work: SL Spot Slickline unit and RU. Pressure test lubricator to 300psi low and 2,800psi high. Pull Ball and rod RWO S-216 PTD:200-197 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 RWO S-216 PTD:200-197 Wellbore Schematic RWO S-216 PTD:200-197 Proposed Wellbore Schematic RWO S-216 PTD:200-197 RWO BOPs Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: July 21, 2021Subject: Changes to Approved Sundry Procedure for Well S-216Sundry #: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:200-197 6.API Number:50-029-22989-00-00 PRUDHOE BAY, POLARIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: Property Designation (Lease Number): 10. 8. PBU S-216 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 Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 8713 Effective Depth MD: L-80 11. 5/1/2021 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): 5625 Effective Depth TVD:Plugs (MD): Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 7574, 4606 / 7639, 4653 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 29 - 3571 29 - 2871 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 110 Structural Proposal Summary 13. Well Class after proposed work: 3-1/2" Baker S3 Packers None None 3-1/2" 9.2#24 - 7697 Production 7785 4765 7785 None 30 - 110 470 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 3542 5750 Intermediate 8672 7" 26 - 8698 26 - 5611 8160 7020 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 1404 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. Cleanout Cmt Plug, Install Regulated Inj Completion ADL 0028261, 0028258, 0028257 By Samantha Carlisle at 1:46 pm, Apr 26, 2021 321-216 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.26 12:14:33 -08'00' Stan Golis (880) MGR13MAY21 10-404 SFD 4/26/2021 * BOPE test to 3000 psi. Annular to 2500 psi. *Witnessed MIT-IA to 2750 psi. 24 hour notice. *Witnessed MIT-IA within 5 days of stabilized production. DSR-4/26/21dts 5/13/2021 JLC 5/13/2021 5/14/2021Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.14 10:22:18 -08'00' RESCINDED per email M. Rixse 7/20/2021 RESCINDED per email M. Rixse 7/20/2021 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:200-197 6.API Number:50-029-22989-00-00 PRUDHOE BAY, POLARIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: Property Designation (Lease Number): 10. 8. PBU S-216 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 Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 8713 Effective Depth MD: L-80 11. 5/1/2021 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): 5625 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 7574, 4606 / 7639, 4653 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 29 - 3571 29 - 2871 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 110 Structural Proposal Summary 13. Well Class after proposed work: 3-1/2" Baker S3 Packers None None 3-1/2" 9.2#24 - 7697 Production 7785 4765 7785 None 30 - 110 470 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 3542 5750 Intermediate 8672 7" 26 - 8698 26 - 5611 8160 7020 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 1404 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. Cleanout Cmt Plug, Install Regulated Inj Completion ADL 0028261, 0028258, 0028257 By Samantha Carlisle at 1:46 pm, Apr 26, 2021 321-216 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.26 12:14:33 -08'00' Stan Golis (880) MGR13MAY21 10-404 SFD 4/26/2021 * BOPE test to 3000 psi. Annular to 2500 psi. *Witnessed MIT-IA to 2750 psi. 24 hour notice. *Witnessed MIT-IA within 5 days of stabilized production. DSR-4/26/21dts 5/13/2021 JLC 5/13/2021 5/14/2021Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.14 10:22:18 -08'00' RBDMS HEW 5/14/2021 RWO S-216 PTD:200-197 Well Name:S-216 API Number:50-029-22989-00 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:06/04/2021 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:200197 First Call Engineer:Brian Glasheen 907-545-1144 Second Call Engineer:Brodie Wages 713-380-9836 AFE Number:215-01234 IOR 281 Current Bottom Hole Pressure:1,904 psi @ 5,000’ TVD 7.6 PPGE (+0.3 SF)| SBHP S-217 04/21/19 Max. Anticipated Surface Pressure:1,404 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:630 psi (Taken on 12/11/19) Min ID:2.8” ID @ 7,617’ MD Max Angle:70 Deg @ 3,873 MD’ Brief Well Summary: S-216 is a reservoir abandoned Oa, Oba, Obb, Obc, Obd injector. S-216’s waterflood pattern < 30% HCPV in all five sands and is extremely immature. This RWO will recomplete S-216 into the Oa, Oba, Obb, Obc, Obd sands as a MI/PW regulated injector to accelerate production from S-213A. Objective: Pull the existing 3 ½” L80 tubing out of the well, washer over both baker S-3 packers, mill/clean out cement and sand to ~8,500’MD. Replace tubing with a WFRM competition. Achieve a passing MIT-IA & MIT-T. Pre RWO work: DHD OA Integrity test Cycle LDS’s SL Pull Station 1 GLV and replace with flow sleeve FB Circulate out well with 305(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 2000 psi. a. Tubing Volume to GLM1 is .0087 bbls/ft*7,524’=65 bbls b. Annular volume to GLM is .0252 bbls/ft* 7,524’=189 bbls (I neglected the 71’ of 4.5’’) c. Total volume to GLM1 is 254 bbls d. Rig up to neighboring producer FL or take returns to tanks. CMIT-TXIA- 1,000 psi Freeze Protect well. Pump 74 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. -00 RWO S-216 PTD:200-197 EL Cut tubing@ ~ 7,636’ MD (3’ above packer) Cut tubing @ ~ 7,572’ 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 ~69.9K 5. Pull 4 1/2”/ 3 ½” tubing to floor. 6. Wash over both Baker S3 Packers at 7,574’ and 7,639’ MD 7. Mill cement and sand from 7,785’ to ~8,500 MD 8. Run 4.5’’/3.5” tubing with stacker packers and waterflood regulator mandrels detailed on proposed schematic 9. Land Hanger and reverse in corrosion inhibited 8.5ppg 1%KCl 10. Drop ball and rod and set packer with 3,500psi pump pressure. 11. 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 12. Shear valve in GLM. 13. Freeze protect to ~2,000ft with diesel 14. Set TWC 15. 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. Post rig: RWO S-216 PTD:200-197 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 S-216 PTD:200-197 Current Wellbore Schematic: RWO S-216 PTD:200-197 Proposed Wellbore Schematic: RWO S-216 PTD:200-197 RWO BOP: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: April 22, 2021Subject: Changes to Approved Sundry Procedure for Well S-216Sundry #: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 • 0 ~:.,_ 6 ~ C ~~ ~c 4 ~~ ( b ~ ~ ~ } ~ ~~ 1 I ~ ~ ~~ 0 p a @ ,$ gy 11~~ yg\ ~ e~-y' 1t 1C{ Ip1 ~~ 9~ pr.~ t t SEAN PARNELL, GOVERNOR Fe ~.-ak P ~ K..:~ ~~:~1~ ~J !.- ~. ,"~ Ord. ~ bd~ Ate". ~-d' e-t A Lii~[a-7~~ O~ ~ l~-7 333 W. 7th AVENUE, SUITE 100 CO1~T5ER`PATI011T COrII~i15SIO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 21, 2010 FAx (907)276-7542 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~~' ~1~ ~ ~. ~~ ~ ~ ~ Re: PBU S-216 Notice of Violation PTD 2001970 Polaris Oil Pool Dear Mr. Rossberg: The Alaska Oil and Gas Conservation Commission (Commission) has reviewed BP Exploration (Alaska) Inc. (BPXA)'s request to rescind the notice of violation issued for the alleged abandonment of Prudhoe Bay Unit S-216, an enhanced oil recovery injection well within the Polaris Oil Pool. BPXA's request to rescind the notice of violation is rag nted. Incorrect information provided by BPXA to the Commission about the status of PBU S-216 resulted in a notice of violation and request for specific information documenting the well abandonment. Included with BPXA's request was clarification that PBU S-216 was not plugged and abandoned as originally communicated to Commission staff. Instead, the injection perforations in PBU S-216 were squeezed with cement to control fluid movement within the Polaris Oil Pool sands. Also included in its response was a copy of BPXA's written training, guidance, policy and procedures that were in place at the time, and a Report of Sundry Operations documenting perforation squeeze operations completed in December 2007. As noted by BPXA in its January response, the cement squeeze of injection perforations in an injection well is a routine activity that has been exempted from the Application of Sundry Approvals (Form 10- 403)requirements in the Polaris Oil Pool wells.' The Commission considers this matter closed. Sincerely, Daniel T. Seamount, Jr. Chair cc: AOGCC Inspectors (via email) ' "Well Work Operations and Sundry Notice/Reporting Requirements for Pools subject to Sundry Waiver Rules" (Sundry Matrix) attached to Conservation Order 556 dated July 29, 2005. by January 14, 2010 • Mr. Daniel T. Seamount, Jr. Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Reference: Notice of Violation AOGCC Letter December 14, 2009 PBU S-216 PTD 2001970 Polaris Oil Pool Dear Mr. Seamount: ~~= =~~ /~1~1~\ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5637 REC~IVEC~ JAN ~ ~ 2p10 Ale~k~ 0~ S ~t Caa. Corrmilaxion aA~nW.~e The purpose of this letter is to respond to your December 14, 2009 Notice of Violation letter. The subject letter indicates that based upon information provided by BP Exploration (Alaska) Inc. (BPXA), PBU S-216 was plugged and abandoned without Alaska Oil and Gas Conservation Commission (Commission) approval. Upon reviewing the history of PBU S-216, BPXA incorrectly provided information to the AOGCC that suggested the well was plugged and abandoned. The expression "plugged and abandoned" was used out of context in our communication to AOGCC staff. The proper verbiage should have been "squeezed to control fluid movement in zone". PBU S-216 was not plugged and abandoned in July 2007 as required in 20 AAC 25.105. However, in December 2007 the perforations were squeezed with cement to control fluid movement from an upcoming new grassroots injection well (PBU S-217). PBU S-216 remains available for future potential sidetrack or other utilization. Background PBU S-216 was drilled in 2000 as a Schrader Bluff producer. Several fracture treatments were performed in the "O" and "N" sands. The well had poor productivity on gas lift and jet pump lift and produced significant volumes of sand. The well was converted to produced water injection on November 15, 2005. The well remained on produced water injection from November 2005 through July 2006 and was shut-in due to the risk of a matrix bypass event similar to what was experienced in offset injector S-215. There was concern that the fracture treatments on S-216 had broken the shale barriers between sands, which would compromise intrazone isolation in the near wellbore region. Injection into S-216 ceased on July 19, 2006. The latest Polaris injector basis of design relies on multiple straddle packers and good zonal isolation for effective flood distribution between different sands. S-216 was deemed inappropriate for continued use as an injector because it lacked intra-zonal control in the completion and in the near wellbore region. S-217, a new grass roots injection well was drilled in October 2007 as a replacement well for S-216. Prior to initiating water injection into S-217, the perforations in S-216 were squeezed with cement in December 2007 to • • control fluid movement between zones in the S-216 wellbore region as a result of injection in S-217. As per the AOGCC Sundry Matrix dated July 15, 2005, an Application for Sundry Approval was not required. However, a Report of Sundry Well Operations (AOGCC form 10-404) was not submitted. This issue came to light during communication between Commission staff and BPXA Well Integrity Engineers regarding injection well mechanical integrity tests. Subsequent to the communication, BPXA incorrectly submitted an Application for Sundry Approval (AOGCC form 10-403) for the cement squeeze treatment conducted in December 2007. Sundry Application number 309-428 was approved December 28, 2009. Corrective Actions BPXA had a system to manage compliance with Commission regulations at the time of the cement squeeze on S-216 in December 2007. Subsequent to December 2007 the system has been strengthened to ensure compliance. Enhancements included: BPXA developed a Well Integrity Management System (WIMS) which includes fundamental well integrity and specific AOGCC requirements related to Sundry Applications and reports. Additionally it establishes compliance responsibilities for specific BPXA engineering positions. A required WIMS training module for all engineers associated with well operations was developed to ensure conformance with BPXA expectations and compliance with Commission requirements. Attachment 1. 2. BPXA developed a set of flowcharts summarizing Commission requirements related to Permit, Sundry Applications and Reports. It also includes BPXA's internal process and responsibilities. Attachment 2. 3. BPXA routinely communicates the AOGCC Sundry Matrix to appropriate staff. 4. Communicated this incident to all pertinent engineering and support staff. Attachment 3. Recommendations BPXA requests the Commission cancel approved Sundry Application 309-428, dated December 28, 2009. BPXA herein submits a Report of Sundry Operations (AOGCC form 10-404) documenting the cement squeeze treatment conducted in December 2007. Attachment 4. We regret that our miscommunication created confusion related to the subject well work on S-216. Considering the events surrounding this issue, we respectfully request the Commission rescind the Notice of Violation dated December 14, 2009. If you have any questions, please call me at 564-5637 or Harry Engel at 564-4194. Sincerely, e 1 ~Q R. Steven Rossberg Wells Manager BP Exploration (Alaska) Inc. Attachment 1 by .~ ` Y '~ rl ~,` ., • For Wells Group PEs, Production Engineers, Optimization Engineers, and AD&W Engineers •• ~.~, ..~ ~, Authority: Alaska Wells Manager Custodian: GPB Operations Manager Milne Point PUL Author: Well Integrity Coordinator ACT East PUL Well Integrity Coordinator Scope: Well Integrity Document BPXA HSE Web Specialist Management System Control & VTA Administrator (WIMS) Training -Wells Administrator: Group & Drilling Engineers Issue Date: November 10, 2008 Issuing Dept: Alaska Wells Group Revision Date: July 31, 2009 Control Tier: 2- BPXA Next Revision July 31, 2011 Version: 1.7 Date: .. Training Objectives • Overview of the Well Integrity Management System • Production Engineer Responsibilities • Wells, Optimization, and ADW Engineer Responsibilities ~ • Well Operations Training • Well Classifications • Confirmation of classification using Digital Well File • Reference Regulations and Policies • Sundry Matrix and Sundry Applications • Sand Control and Corrosion /Erosion Management ~ • Operating Pressure Limits (MOASP) • Anomaly Identification and Reporting • AOGCC Administrative Approvals • The RACI Chart 3 Specific to BP Alaska operations regarding integrity and compliance issues, intended to meet requirements of Well Operations ETP, DWOP, and IM Standard -- Agreed to by Operations slope-wide and Well Integrity ~ ~-~a States accountabilities and responsibilities for Operations and ADW line management ~~ States well operational requirements for Well Operators, Board Operators, and Engineers -- The WIMS is a controlled document. It may be accessed through the HSE __ ,r ; ~:~~ °y ~'~~ ~F~~.. Eventually a link to this document will added to the Operations Document Information Exchange (ODIE). ~ WIMS Training ~~ You are acknowledging that you know how to locate the WIMS document for future reference. ~- As part of your regular job duties, you must understand and abide by the reauirements of the WIMS document. 4 Well Integrity Management System (WIMS) .. Production Engineer Responsibilities .' ® Being knowledgeable of requirements of the WIMS document and AOGCC Regulations, AOGCC Conservation Orders, AOGCC Area Injection Orders, MMS Regulations and EPA Class I Permit requirements. ® Attending initial and annual refresher training on the WIMS document. This training ~ shall be documented in VTA or equivalent. • Ensuring that well classification conforms to regulatory and policy requirements (e.g., does the activity require Sundry Notice, current MIT-IA status, etc.) when initiating well work. ® Ensuring any required "AOGCC Request for Sundry Approval" (form 10-403) has been submitted anal the "AOGCC Report of Sundry Well Operations" (form 10-404) has been completed ® Reporting any well integrity issues to the Well Integrity Coordinator immediately • Reporting non-conformance from this WIMS document to the Well Integrity Coordinator and appropriate Team Leader immediately ® Ensuring EPA Class I well permit requirements are completed (e.g. temperature logs, step rate/pressure fall off tests, tubing calipers) 5 Wells, Optimization, & ADW Engineers Responsibilities • Attending initial and annual refresher training on the WIMS document. This training shall be documented in VTA or equivalent. 6 _~ _ ._ , . , l •• j Well 0 erations Trainin p g ~. ~. ~~~f • Drillsite/Pad Operators and Well Tenders, DHD Technicians, WI Engineers, Management, Production Engineers, Wells Engineers, Drilling Engineers, Rig Workover Engineers and well service contractors shall be knowledgeable of well integrity operations, including but not limited to the following topics: ~ - Fundamentals of annular pressure control - Contents of this WIMS document - Explanation of Annular Fluid Expansion - Requirements for pressure gauges - Well anomalies that require notification to the Well Integrity Coordinator - Familiarity with Operable/Under Evaluation/Not Operable well classifications ~ Operable Welf ~- Meets integrity requirements to be online including downhole testing- on production or injection - Has two tested downhole mechanical barriers -competent tubing and production casing Jet Pumps and Electric Submersible Pumps allowed with only tested production casing due to completion design -- Does not have a surface casing leak to atmosphere ~-- Must be operated under maximum operating pressure limits (MOASP) -~ May have minor annular repressurization if pressure is manageable by bleeds ~~-- In~ectors are approved by the AOGCC for continued operation with minor annular 1 repressurization with an Administrative Approval (AA) Designated as 'Operable' in Digital Well File May be shut-in for other reasons such as swap to MI, flowline repair, pressure build-up for static survey, etc. These reasons should be captured in Field Logbook or a similar system. 8 Not Operable Well --w Must remain shut in because it does not meets one or more of the following integrity requirements: ~ ~~ Competent tubing ~- Competent production casing -- No surface casing leaks to atmosphere -~ Compliant with downhole integrity testing Manageable by bleeds within maximum operating pressure limits (MOASP) Includes suspended wells and observation wells • - Designated as 'Not Operable' in Digital Well File Before requesting start-up of any well, confirm not classified as Not Operable Reason for Not Operable classification is documented in the Well Integrity Note. Contact a Well Integrity Engineer with any questions. 9 Under Evaluation Well - 28 Day Clock -~ Exhibits an integrity anomaly -annular repressurization or bubbling in the cellar ~- Internal policy allows well to be evaluated for up to 28 days ~ -~ Within 28 days, the Wells Group needs to find the cause of the anomaly, successfully restore integrity, prove the well meets definition of Offerable, or safe out the well and reclassify it as Not Operable -~ Everyone's responsibility to help progress the work on these wells in a timely manner to comply with the 28 day clock -- Do not underestimate the amount of time it takes to write a program, schedule equipment, and conduct the work i ® Plan for things not going as they should ~-- Under Evaluation classification may be used to return to production to confirm economic viability of future repair - Designated as 'Under Eval' in Digital Well File ~o = Digital Well File - Online tool to confirm well classifications -- Accessible at http://digitalwellfile.bpweb_bp.CO ~- Type in well name - select ok - Click on WI Info Tab - Well Classification M ITIA due date for _.~ injectors in WI note :~ Call the Well Integrity Coordinator at x 5102 with questions c{igital well file Well: NS29 OK ~ ALASKA CONSOLIDATED TEAM» NS» NS»NS29 Well Events TIO Well Test GLY Oper Notes H2S PE Info BHP WI Info Dir Survey System Config AL Info Mame Dispensations Anomalies Casing Ratings Tree Maintenance Reports Administration WI Info » Home Problem Status Planned Action r INS29 has dispensation for SC Leak and has a ~. Dispensation for WI System Policy - 05(19108 ~i potential to burp diesel, Control room has alarms _ I !AA A[O 23,001 for SC Leak 01/09/06 in place to warn of the occurrence. Please discuss i ' with control room prior to commencing work on th7s ! '~> 09/20103: Set IBP @ 13,370' and 'wall, '> 11(19/03; RWO replaced tubing I. > 11/12/03: Baker 3-3/8" IBP 'fish' left in hole @ '~, ^C Leak - 01/10/06 13644' slm. Rw rompleted 11/19/03 i ~> 01/18/04; NS Oper reported high IAP 1700 psi ~, 'Fish 'ibr '-~ hole @ 13644' - 11/OS ~ '.after bleeding 1750/700 on 1/16 Gas OeteRio~. 'stalled in wellhouse due to well i !> 01/19/04: Notified AOGCC by voice mail & e- being on dispense'^n for SC Leak __ 'mail of IA re-pressurization, PPPOT-T Passed to ~, i 6500 psi I `.;5/8" Casing set on manor 'hanger I I '> Ol/21(04i NFT-IA in progress. > 01/2 310 4 1 NFT-IA Passed, 75 scfh @ 2.5 psi IA flai., = is 7500 psi working, IA R~st:,..•ssembly "; ~.>_Ol/24/041 MITiA Passed to 3440 psi . v Ma>. Allowa~: • Annulus Surface Pressure Well Details _ _ Actions ____ _ _ "~~ Adion Group `~ Max iA Pressure '*4. 1500 Alive Wellbore INS29 Max OA Pressure 1,. ', PTD NUi„' a~. 12030410 ! Date Start (m/d/y) 05/31/2009 Max OOA Pressure 500 WI Status Under Eval ~ Max OOOA Pressure 500 Well Type GI v Leaks Reports ^TxIA ^ Wireline Rpt? ~~,.~ Engineering Notes ``~~ Category 0 I -~ ~ ~ ^ IAxOA ^ Watch Rpt? Well Inte tit En inset Note ~ ~ _ y g g PE lOR _ ~ ^ Prod Csg Leak ^ Excl Miss Press Rpt? --- _ __ ____ _ ~SC Leak AA & Dis ensation - MITIA due 7!25/2009 I P Turin I ~ Surf Csg Leak ^Q AA/Sundry? ~ AOGCC Inj Rpt? Optimization Engineer Note _ _ __ _ - - ~I i i • The following area specific Conservation Orders, found on the un~~~~~~:-~~ _ ,pertain to sustained casing pressure in producing wells f CO 457B Aurora - C O 492 CO 494, 432D CO 496 - CO 500 ~~ C O 501 ~~ CO 502 - CO 503 CO 505A -- CO 570 -- CO 559 GPB (all pools) Milne Point (Kuparuk) Milne Point (all pools) Badami Endicott (all pools) Northstar Pt. McIntyre (all pools) Orion Raven Put River 12 by The following AOGCC Area Injection Orders, found on the ~?~ ~ ~ '~,~~k~~it are regulations pertaining to injection wells ~- A10 001 Endicott A10 003 WOA --J A10 004E EOA and GPMA - A10 010B Milne Point Unit (MPU) A10 014A Niakuk ~- A10 017 Badami -~- A10 019 Endicott Eider ~- A10 020 Midnight Sun -- A10 22D Aurora -~ A10 023 Northstar A10 024B Borealis -~ A10 025A Polaris v~ A10 026A Orion - ~ A10 031 Raven 13 Pad 3 AK-11004-A Badami AK-11001-A Northstar AK-11002-A Milne Point AK-11005-A Grind and Inject AK-11008-A 14 The following are area specific EPA Class 1 Disposal Well Permits _ .. Other Key References A GC~ latic~_ ___. (Applications for Sundry Approvals) Alaska Di_p~~~~_~r~._~s~ Gi,_e (the "Red Book") lask~ ~~ety Hadb~~ (ASH) ® __ _rsllsnc_r~ 1~~I __e~~ti _~I~c_y.~__E3P~_~~ (DWOP) • ~,5~_~_ul~~i~s_ found at 30 CFR 250 and 251 • MMS concurrence letter dated November 19, 2003 for Northstar • _____ell_:__~'rWRi ~~stin0_~ie_lr~.~_s. • S 1~::____~II:__.car~i~a~ Intri~y_~T~s~i_.ui~lin~~ • Vilel_I ~~erati®ns__E_TP (G P-10-35) 15 • Sundry Application - The AOGCC Sundry Matrix may be accessed through the AOGCC webpage at °~~ ~°~~~ ~° °~~~~~~~~~~ ~~~~~~ -~ or through the Wells Group webpage. Note: Badami and Northstar are not covered b the Sundr Matrix. ~ Y Y --- Many thru-tubing, pumping, coil, rig, and wellhead operations require one or more of the following forms: -- Application of Sundry Well Operations (10-403) -- Report of Sundry Well Operations (10-404) ~- Well Completion or Recompletion Report and Log (10-407) Production Engineers are responsible for obtaining approved Applications for ~ Sundry Well Operations prior to sending work to the WBL. Work with PDC to develop Sundry Applications. PEs and WSLs are responsible for having a copy of the required form on location Submittal of required Reports of Sundry Well Operations and Completions are completed by Anchorage positions 16 Scale Control -- The Production Engineer is responsible for monitoring well productivity and for requesting well interventions on wells needing scale treatment or clean outs ~ Corrosion/Erosion Management ~-~ A corrosion/erosion control program is being developed for ADW by the CIC group -- The Wells Group is responsible for Ensuring trees removed for drilling operations are disassembled and visually inspected -- Annually removing and inspecting trees and running calipers on G&I wells n En ineer is res onsible for ensurin the ro er design of ~ The Wells Optimizatio g p g p p choke step-up and weekly velocities checks The CIC group is accountable for maintaining an action corrosion coupon monitoring process and database 17 M OAS P Maximum Operating Annulus Surface Pressure Previously referred to as MAASP --- Maximum pressure at which an annulus is allowed to operate _-~ Pressures above MOASP shall be bled & reported to the Well Integrity Coordinator --~ IMPORTANT: MOASP are absolute limits. It is more important to identify and report a well with a pressure anomaly before the pressure reaches this limit. Deviations listed on AOGCC AAs for some injectors and in WIMS for disposal wells Maximum Operating Annulus Surface Pressure Jet Pump GPB LPC Endicott Milne Point Northstar Badami Inner Annulus (IA) Power Fluid Pressure 2,000 psig 2,500 psig 2,500 psig 2,000 psig 2,000 psig 2,000 psig Outer Annulus (OA) 1,000 psig 1,000 psig 1,000 psig 1,000 psig 1,000 psig 1,000 psig 1,000 psig Other Outer Annuli (OOA) 500 psig 500 psig 500 psig 500 psig 500 psig 500 psig 500 psig 3 Anomaly identification and Reporting ®Immediately report any of the following conditions to the Well Integrity Coordinator -Wells with annuli pressure above MOASP -Any well requiring an unmanageable number of bleeds to keep pressures under MOASP ~ -Natural flow producers when the IA pressure increases or equalizes with the tubing pressure when the well is shut in. -An increasing trend in OA pressure -NOTE: It is a BPXA well integrity recommended practice to keep at least a 250 psi differential between the tubing and IA pressure and at least a 100 psi differential between the IA and OA pressure on producers. -Any well that exhibits tree growth or vertical or side-to-side tree movement. ~ -Any well that exhibits ground subsidence. Document if the wellhouse is discovered resting on the tree or flowline. Ensure barricades and guards are in place to heighten awareness of the hazard. -Any well that exhibits wellhead flange leaks, bradenhead leaks, or any other possible indications of leakage from the well such as hydrocarbons or water in the cellar. 19 Anomaly Identification `and Reporting - ®The following need to be immediately reported to Well Integrity for further evaluation and so that the Well Integrity Coordinator can notify the Commission within 24 hours as required by AOGCC Area Injection Orders. -Injection wells with annuli pressure above MOASP ~ -All annular bleeds performed on wells, other than to manage temperature changes - A significant change or increasing trend in IA and/or OA pressure - NOTE: It is a BPXA well integrity recommended practice is to keep at least a 100 psi differential between the IA and OA pressure on injectors. -Wells unable to maintain a 250 psi pressure differential between the tubing and IA pressure on injection wells as this may be an indication of a slow leak. -Any well that exhibits tree growth or vertical or side-to-side tree movement. ~ -Any well that exhibits ground subsidence. Document if the wellhouse is discovered resting on the tree or flowline. Ensure barricades and guards are in place to heighten awareness of the hazard. -Any well that exhibits wellhead flange leaks, bradenhead leaks, or any other possible indications of leakage from the well such as hydrocarbons or water in the cellar. 2C ~~ Administrative Approval Official approval by the AOGCC for continued operation with slow repressurization -- Laminated copy on the SVS panel in the wellhouse --- Engineers responsible for being familiar with the information on the AA accessible on the Wells Group web page --~ May state changes in MOASP -- May require automatic shut-in, remote monitoring equipment, or additional surveillance and reporting Notification to the Well Integrity Engineer Immediately notify the WIE if the rate of repressurization increases. 1 1111 II=~ r1 IIIr l ' `` ~~ i,l ~~{ ~ I L!~, r~I ~ ;J~ S L.:~LILILI `~ ~ U1P~I.J~ SARM+F+4lJN. GGrErWOR >/ A1~. Rlave Rasaherg Well: I'ruµrllun Mnlu~cr \anWu: e'cll Inrarity f.'V[xdinnlnT, PRp-20 BP Exyklrl>Iitm (Ab:~knj Im:. P.O. ftnn 1glIG12 \nchor;lcc, AK Y9519-GG12 RE. PRL; Y-114A (P'I I) 20318511) Regtust Por ndtnlulsunti~•c Appmvnl 1311realir; Uil IY,r,I AfI,Ab1IfA OII. A1f-D 4~B JJ. ~n +e nrrur, r.ln:Ei CoxSBavafilcoir CoriaflSSItWC nn~:T~'~E AVkrI MY:'de YT •tgVE 'DT 2'1 IJJ3 ' fAr ;?l'~:IE~ :J7 -11NIN151'Ir A'1'1 V}:APPROVAL r~i0 24A.IINI 1)ex X11. Rwyl+clg: In Ivxnlr/lu: T:e v<ah Rule k of J'uea Injection CkJcr ("Af0'~ ".4A.IYiMI, the Alnke Oil r,ll Gav CAW1U~'atlDn CONL1155:On C'~Atl( iCa~" nr "Cumtr:i"iun"1 hereby' 4r&ufs the rCyllebl Of t3N Gxp;:+mti:+n {plaxksl ine. 1">tPXA' !iH udEninialrntive npprovnl w con~tsue venter injectioa in It2C subjwl ntal. P.ulon' lituing the spprosal cenditiwn, hot+rver, the t.'wnmisxi: r, wiR a>mrnent on nPk.A's operation at this well with presttx~e .nromuniculiion in viululi+r+ of C~nnrncs!iolt roquirn,tents. Hoscalis lhl Pc+ul (lu:rt of lMe Hvttthee Itay Isnici tt•et; ~'•1 :SA cnmmcxcd cnrich.d gaa i»jccl~en in $eplember 2!1(Itl. I'rc>,awc Jnta i,kli:,ttR: tltc wrll oyclatrd with a stot?!c itmr unalluy pra;xure rm:ginµ ('nlrn 6UIr l0 9iH! psi ulxil utid-J»ln 2007. UwirlX suhacqucnu munlhs I;:Iaiing LSl kl tll1.kA's 1JOtrticlrtian to tl>v Cotnutisaicn at Augusl'7, "?OD? :+l' Pnswre wn>.~,uniwlirxl; 1'1111 Y'y>ed yn:olmcl en•~agcd in the rlt:tivc ,rumayrn,enl of irueuviuµ inner n,rullux proSaElfe ,vlth 'JC7iw9ic bbcds, Pad ~yrT:Ning pcrrv unreel rr,a,ihn~irtCl ll:e well prassu[ea hno'c nylattl (gllWlus lrrr.:rtiurc uiltlrcrn loon I:nr:!ervnliu:l l )rrler 4'12 (apfsllcahk to pcodttctial 1tr11s only') ht opctlHhtl; phi. well. I3T.1-- it realuded that tkene io a more N$~E•nt rcqulrentcnl I;uvrrr. i.K rnntElrr prl:ssrrr+l iu 6lj cctinn wc14 thtlw rksclopssuwt w•dls; itnminlilEte rWti$cntiow is Tegxirw! fret r~ intlitaliett of prerrul'e cYmnxit+ihrtiun rK krkE!gr is w: Injcctiwt IECN. Plo!xu'c' darn provided wah l:aia :uhniniwnlivu xplxovxl rayuart llxllcn:e that the CetnlulssMu should liar bccn nulii icJ ul' presr+ue awaumtlcntion, ntlc the ti+ell should hive bac',+ sK•;J~xd ur wrleT injection in ]tlne'_007 instead o: ~cistcntbc7 ~txs;. .1t no titsx dwhttt Wu n,aYlw of inurrasing inner arundns prolsnte has ttrl'e been any 1nli:Jtlion ui~}>'i:ss,rK: emm~utnicntinn or IeakaRe mnside of the K~cll; all hljtcli:sn has rentnincd wnfit!uJ k: the Ikx,talis Oil PExd and 'h. wcilbon_. 'Ilicrcforc, the Canntissiun doc+t not inl4t,d kJ Idce enfareuxra action agnltrst BPR.•1 nt this liux k» the ennti:y,acl injection nt faa inm I'lll: V- I I1A In tlx yros;.nc:~ of pm~5uro enmmunicalion tll t11C I:II1Cf J:RILLILL~. VUIISIfAtEill delaga m tDn fWura will txsult W cwfWCCrncnt urtk:tE.. 21 ~: RACI Chart A chart located in the WIMS document - RACI stands for Responsible Accountable Consulted ~~ Informed Lists for each item in the WIMS document who is Responsible, Accountable, and who should be Consulted or Informed RACI Chart Z c O ~ ~ m 10 ~ ~ y ~ l ~ v y J y ~ C O y O o ` N Qa V C C O C C W C C d y ~~ C w y c ~ f m O ~ o, - °"^ - d ~ o c tll ~ j (7 OI R ~ 0 ~ O C ~ Ay O c 7 (] ~' 3 ' l7 Z d j 7 O C V d C U 9 J N C U N m ~ of ~ a ~ O ¢ 'C 0 N 3 G O 0. t9v~ d J C C om 3~n a` 3v 3g va WIMS Accountability/ Responsibility 4.1.1 Overall Responsibility for implementation of the Well Integrity I I 1 I I A C I I I R I R 1 Management System (well intervention and well integrity activities) 4.1.2 Overall Responsibility for implementation of the Well Integrity 1 A R I I I R C R C I C C I Management System (day-to-day operational activities) 4.1.1 Ensure Functional Roles know their RACI status (well intervention and well I I A R R R integrity activities) 4.1.2 Ensure Functional Roles know their RACI status (day-to-day operational A R R C C I I 1 activities) 4.2.1 Ensure adequate resources are 4.2.2 available to fulfil the RACI chart A R R R C C requirements (well intervention and well integrity activities) 4.2.3 Ensure adequate resources are available to fulfil the RACI chart A R C requirements (day-to-day operational activities) '. 4.2.3 Review the Area Management Report to stay apprised of potential compliance A R C C C issues 22 Well Integrity Management System -~~ The WIMS is a controlled document. It may be accessed through the HSE -~ -- _ , webpage: ~' ~~ ~ ~ "~ ~ ~ ~ °~ _ . Eventually a link to this document will added to the n Information Exchan e ODIE . Operations Docume t g ( ~ ®WIMS Training You are acknowledging that you know how to locate the WIMS document for future reference. ~s You are agreeing to read and familiarize yourself with the WIMS document outside of training. Your Responsibilities Know your responsibilities. -- Be familiar with Operator responsibilities given our interactions 23 attachment 2 ~ AOGCC Permitting Forms Summary Flowchart Form 10-401 Application for Permit to Drill for new drilling, redrilling, re-entry or lateral operations. Requires AOGCC Form 10-407 within 30 days of completion. Form 10-403 Application for Sundry Approval for all well operations not covered by Form 10-401. Requires AOGCC Form 10-404 or 10-407 within 30 days, except for certain variances. Form 10-404 Report of Sundry Well Operations for workovers, operation shutdowns, stimulations etc. Closes Form 10-403 when completion interval is unchanged. Form 10-407 Well Completion or Recompletion Report and Log to close Form 10-401 when well is completed or recompleted and to close Form 10-403 when completion interval is changed or well is suspended or plugged and abandoned. I Application for Permit to Drill Form 10-401 Change Program I After Spud Change Program Before Spud No I yI Yes Form 10-403 New Form 10-401 Operation Shutdown ~ No ~ Yes ~ Form 10-404 within 30 days ~ I Form 10-403 to restart I I Form 10-407 •I Application for Sundry Approval, Form 10-403 Add/Change I Completion Interval Yes I I No I Form 10-404 I Other AOGCC Forms/Reports: The North Slope based Well Integrity Coordinator (WIC) submits the following documents: Injector Mechanical Integrity Test (MIT) forms, Monthly Underground Injection Control (UIC) Injection Report of Sundries/Administrative Approvals for injectors and producers. HRE/MLB 1-25-08 • AOGCC Form 10-401 Application for Permit to Drill for: New Drilling, Redrilling, re-entry orsidetracks/lateral operations. Multiple branches require a separate Permit to Drill for each branch. Approved Permits expire 24 months after approval. Requires AOGCC Form 10-407 within 30 days of completion ADW Engineer Responsibilities: Review AOGCC Regulations 25 AAC 25.005. Generally prepare the following information; As Built Survey, Identify drilling hazards, MIT procedure, Casing & Cementing program, drilling fluid program, drilling program, general description of muds & cuttings waste management, wells drilled from an offshore platform, jack-up etc. require an analysis of seabed conditions, injection and disposal wells must include a review of wells within 1/4 mile area of review (see 20 AAC 25.402 (e), 20 AAC 25.252(e)). AOGCC maintains ROPE and Diverter information on file for rigs operating in Alaska. If new rigs are considered, ensure BOPE and Diyerter information is provided to the AOGCC. Ensure copy of the approved Permit to Drill is included in the program and is available onsite for inspection by the AOGCC. I Provide Information To: I Terrie Hubble. Drilling Sondra Stewman, Drilling Technologist for GPB Rotary Technologist for ACT Rotary and all CTD operations and Exploration Prepare 10-401. Gain Signature of Drilling Engineer TL or CTD Engineer Signed 10-401 Submitted to AOGCC. AOGCC requires +/- 10 days to process. Approved Permit sent to ADW Tech Aide. Distribution: Original Well File, Engineer, Petro-Technical Data Center (PDC), Asset. Copy must be available onsite for inspection by the AOGCC. PDC creates a record in Finder for data to be available HRE/MLB 1-25-08 AOGCC Form 10-403 I, Application for Sundry Approval for specific well operations not covered by Form 10-401. See attached AOGCC Sundry Matrix dated July 15, 2005 for details regarding what operations require a Sundry. NOTE: The AOGCC Sundry Matrix applies only to operations covered under specific AOGCC Conservation Orders; 261A-(Kuparuk River Field, All Pools), 297A-(Endicott Field, All Pools), 347A-(Milne Point Unit, Kuparuk River, Schrader Bluff and Sag Oil Pools) , 351A-(Uncoal Operated Cook Inlet Fields), 556 & 559 (Prudhoe Bay Field- All Pools). Relatively new fields such as Northstar, Badami and Alpine must comply with AGOCC regulations and Conservation Orders related to Sundry requirements. Requires AOGCC Form 10-404 or 10-407 within 30 days after work is completed. ADW Enoineer, Anchorage PE ": Review AOGCC Regulations 25 AAC 25.015 & 25.280 and AOGCC Sundry Matrix dated July 15, 2005 to determine what operations require an approved Sundry notice before commencing field work. Prepare a brief description of proposed work. Do not include economics or cost estimates. Specify if approved sundry is required in the program. Ensure copy of Sundry is included in program and is available onsite during the job for inspection by the AOGCC. When work requiring a Sundry is initiated by a Well Integrity Engineer, they will contact the APE with a draft procedure to be approved by the APE. The APE will initiate the request for Sundry. _ I Provide Above Information To: I T (x47501. Drilling Technolooists ~~ Manager for all non-rig for all rotary and CTD rig related operations. operations. Prepare 10-403. Gain Signature by Drilling Engineer TL, CTD Engineer or Anchorage PE Signed 10-403 Submitted to AOGCC. AOGCC requires +/- 5 days to process. Approved Sundry sent to Drilling Technologists or Gary Preble. Distribution: Original Well File, Engineer, APE, Petro-Technical Data Center (PDC), Wells Group, Asset. Copy of approve Sundry must be included in program and available onsite for inspection by the AOGCC. PDC maintains a scanned copy of the approved 403. " Non-routine operations may require a 10-403 generated by a contractor or Special Projects engineer. HRE/MLB 1-25-08 • AOGCC Form 10-404 i Report of Sundry Well Operations. Required to be submitted to the AOGCC within 30 days after completing work described in the approved Sundry or was authorized in the Sundry Matrix. NO Responsibilities for ADW Engineer & Anchorage PE. Special Case: Some wells were allowed to continued operations under a Sundry Approval. The Slope based Well Integri4y Coordinator (WIC} manages communications and actions to cancel these sundries. A request is made to Gary Preble (x4944) to prepare a 10-404 to be signed by the W IC and sent to the AOGCC. Note: There are currently only two wells remaining under Sundry for integrity annomalies as of 01/08. Terrie Hubble (x4628). Sondra Stewman (x4750), Drilling Technolooists review DIMS weekly for all rig related non-drilling operations. A weekly report of work completed is sent to AOGCC. Mana er queries Well Events via Finder weekly for non-rig operations. This query is sent to AOGCC. Prepare 10-404, sign and submit to the AOGCC within 30 days of work completion. Distribution: Original Well File, Petro-Technical Data Center (PDC), Asset. PDC maintains a scanned copy of the 10-404. HRE/MLB 1-25-08 AOGCC Form 10-407 ' Well Completion or Recompletion Report and Log. Required to be submitted to the AOGCC within 30 days to close Form 10-401 when well is completed or recompleted, and to close Form 10-403 when completion interval is changed or well is suspended or plugged and abandoned. NO Responsibilities for ADW Engineer Anchorage PE and Slope based Well Integrity Coordinator. Prepare Form 10-407, sign and send to the AOGCC with attachment including; Summary of Daily Drilling Activities, Final Directional Survey, Well Bore Schematic, Leak Off Test data, Pre and Post work info (set whip stock, post rig perforating etc.) Distribution: Original Well File,~-~ Petro-Technical Data Center (PDC), Asset. HRE/MLB 1-25-08 ~ ! AOGCC Administrative Approval Process "Administrative Approval" (AA) refers to AOGCC approval obtained for continued operation of an injector and some producers with an integrity anomaly where corrective actions are not planned. The request for approval prescribes diagnostic and compliance testing. A similar document must be submitted to the MMS for applicable wells at Northstar. All Administrative Approval requests to the AOGCC or MMS are signed by the Alaska Wells Manager. AA's are authorized in Aea Injection Orders and some Pool Rules. NO Responsibilities for ADW Enoineers, The Slope based Well Integrity Coordinator (WIC) manages the process to prepare Administrative Approvals. The W IC drafts an Administrative Approval request letter. The letter is then sent to the Alaska Wells Manager for review and signature. ,The letter is mailed to the AOGCC Commissioners for their review and action. The AOGCC sends a written response to the Alaska Wells Manager. The W IC ensures AnnComm is updated, compliance testing is scheduled, and distributes the letter to operations. If there' is an additional requirement that involves a change to equipment or the procedure to operate the well, the W IC coordinates with the approprite North Slope Facility Engineer and initiates an MoC. (Example: the addition of remote annulus pressure monitoring will require an MoC.) HRE/MLB 1-25-08 Attachment 3 From: Engel, Harry R Sent: Wednesday, January 13, 2010 10:26 AM To: G ANC GPB Pad Engineers; G ANC Petroleum Engineers; G ANC Wells Group; G NSU ADW Wells; G ANC ADW All Subject: AOGCC Sundry and follow up reporting Requirements Importance: High All- We recently received a notification of a potential violation from the AOGCC related to conducting well work without an approved Sundry application (10-403) or follow up report (10-404). This note is to communicate the requirements and responsibilities for obtaining AOGCC approvals for all ADW operations and submitting follow up reports. If you are an ADW Engineer or Pad Engineer you are required to understand the requirements and your responsibilities for obtaining AOGCC approvals for all ADW operations and submitting follow up reports. Team Leaders, ensure that everyone in your group is aware of these requirements. The following information provides the AOGCC requirements and BPXA responsibilities. 1. Well Integrity Management System (WIMS) training module for Wells Group PE's, Production Engineers, Optimization Engineers and ADW Engineers that has been added to respective job titles in VTA, http~//eportal bpweb by com/hse/getContent aspx~objectName=UPS-US-AK-ALL-ALL-ADW-DOC- 00287-2 2. The current AOGCC Sundry Matrix dated July 15, 2005. This AOGCC document identifies which operations require AOGCC approvals and follow up reports. Note: the Sundry Matrix does not apply to Northstar, Badami or Liberty. For these fields, refer to AOGCC regulations 20 AAC 25.280 for Sundry and follow up report requirements. ,J SundryMatrix aly 15, 2005.pdf. 3. AOGCC Permitting Forms Summary Flowchart u AOGCC Form wcharts 012808.: Contact me, the Well Integrity Coordinator (Anna Dube/Torin Roschinger) or Mike Bill if you have any questions. Harry Engel Engineering Team Leader Alaska Drilling 8~ Wells • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Attachment 4 REC~IVEQ JAN ~. ~ 2010 1.Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate^ O~r_~ Performed: ~a ~ a Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Exte °n L J Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re ter Suspended Well ^ ~n 2.Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^ Exploratory 200-1970 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ .API Number: Anchorage, AK 99519-6612 50-029-22989-00-00 8. Property Designation (Lease tuber) : .Well Name and Number: ADLO-028261 S-216 10. Field/Pool(s): PR DHOE BAY D / U FIEL POLARIS OIL POOL 11. Present Well Condition Summary: Total Depth measured ~ 8713 feet Plugs (measured) TOC 7785' feet 12/11/2007 true vertica 5625.44 feet Junk (measured) None feet Effective Depth measured 8612 feet Packer (measured) 7494 7520 7569 7639 true vertical 5463 feet (true vertical) 4551 4568 4606 4653 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3542 9-5/8" 40# L-80 29 - 3571 29 - 2871 5750 3090 Intermediate Production 8672 7" 29# L-80 26 - 8698 26 - 5611 8160 7020 Liner Liner Pertoration depth: Measured depth: SQZ 8000-8316 _ True Vertical depth: 4947.99 - 5243.74 _ _ _ - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 Surface-71 Surface-71 3-1/2" 9.3# L-80 71-7697~P ~K,a 71-4696 Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker S-3 PKR 7574 4606 3-1/2" Baker S-3 PKR 7639 4653 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~' ~~N ~ ~ ~O~Q Treatment descriptions including volumes used and final pressure: 13. ~ Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 1 Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ Q SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Harold R. Engel Printed Name Ha Id R. Engel Title Engineering team Lead Signatur t Ph a 564-4 Date 1/14/2010 St10p Form 10-404 Revised 7/2009 ~ ~.Z'~~O ~~.~/o Submit Original Only • 5-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/10/2007. CTU #6. Unit on S-Pad. Get flat tires changed out. MIRU. Perform weekly BOPE test. Work on return micro motion. Shut down for night. E ***Continued on 12/11/07 WSR*"* Job in progress 12/11/2007 CTU #6 with 1.75" coil.'`**Continued from 12/10/07 WSR*** Kill well with 2% KCL. RIH with 2" BDJSN. Tag TD at 8512' ctmd. Correct to 8521' elm. Flag pipe at 8511'. Load backside with diesel. Mix and pump 46 bbls 15.8 ppg liner cement and 23 bbls 15.8 ppg cement w/ 12 ppb aggregate. Estimate TOC at 7770' and 41 bbls behind pipe. Clean out and contaminate to 7800'. POOH, jet all jewelry, and stack. Freeze protect coil and well with 60/40. Trap 350 psi WHP. Stand back injector and secure well for night. Will either RDMO or make nozzle run to tag cement tomorrow. ''''*Continued on 12/12/07 WSR*"* 12/12/2007 CTU #6 Job Cont' From 12/11/07 WSR Drift and Tag. RIH with 2.0" JSN. Tag cement at 7787'. Reconfirm tag @ 7785'. PT plug to 300psi(good). POOH. Freeze protect well to 2500' with 60/40 methanol. Notify Pad Operator of well status. RDMO ***Job Complete*** 12/25/2007 T/I/0= 40/140/0. Temp= S/I. MIT-T PASSED to 1000psi. Held tight for entire 30 minute test. Pumped 0.5 bbls of 42* 60/40 Meoh to achieve test pressure. Final WHP= 40/140/0. Annulus casing valves are open to gauges. Wing is flagged closed and tagged. FLUIDS PUMPED BBLS 286 2% KCL 203 1 % X-SLK 40 1.5# BIO 72 DIESEL 122.5 60/40 METH 46 15.8 PPG "G" LINER CEMENT 23.2 15.8 PPG "G" CEMENT WITH 12 PPB AGGREGATE 44 FRESH WATER 836.7 Total TREE= 4-1/16" CIW DATE REV BY COMMENTS DATE REV BY GOMMENTS 12/28/00 PGS ORIGINAL COMPLETION 07/05/05 KDC/PJC GLV C/O 08/12/01 D-14 RWO 10/22/05 RCC/PJC ACTUATOR CORRECTION 05/22/01 CS/KAK PERFS 11/02/05 GJB/TLH ADPERF 07113/01 JLG/KAK ADPERFS /SAND DUMP 04/19/06 RCTIPJC GLV CORRECT~N 07/08/03 JJ/TLP PULL UPPER ECLIPSE/JET PUMP 02/17!08 TW/PJC DRAWING CORRECTION 04/02/05 WTS/TLH JET PUMP PULLED POLARIS UNtT WELL: 5-216 PERMff No: 2001970 API No: 50-029-22989-00 SEC 35, T12N, R12E, 964' FNl & 780' FWL BP Exploration (Alaska) STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMISS ~G4~1 V ,IAN 1 5" 2010 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ AnCh Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-e er Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^ Exploratory 200-1970 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-22989-00-00 8. Property Designation (Lease Number) : .Well Name and Number: \ ADLO-028261 S-216 10. Field/Pool(s): PRUDHOE BAY FIELD /POLARIS OIL POOL 11. Present Well Condition Summary: Total Depth measured ~ 8713 feet Plugs (measured) TOC 7785' feet 12/11/2007 true vertical \ 5625.44 feet Junk (measured) None feet Effective Depth measured 8612 feet Packer (measured) 7494 7520 7569 7639 true vertical 5463 feet (true vertical) 4551 4568 4606 4653 Casing Length Size MD TVD Burst Collapse Structural ._ .._.... Conductor 80 20" 91.5# H-40 30 - 110 30~ - 110 1490 470 Surtace 3542 9-5/8" 40# L-80 29 - 3571 29 - 2871 5750 3090 Intermediate Production 8672 7" 29# L-80 26 -8698 26 - 5611 8160 7020 Liner Liner A (~~ ~ `~a ~ ~,0~~ c I~I~ ~A4C.~ a~ . .. y Pertoration depth: Measured depth: SQZ 8000-8316 = _ True Vertical depth: 4947.99 - 5243.74 _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 Surtace-71 Surface-71 3-1 /2" 9.3# L-80 71-7697 71-4696 ~" " 4606 Baker S-3 PKR 7574 ~tC Packers and SSSV (type, measured and true vertical depth) 3-1/2 3-1 /2" Baker S-3 PKR 4653 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL G OR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Harold R. Engel Printed Name Ha Id R. Engel Title Engineering team Lead w Signatur R Phone 564-4194 Date 1/14/2010 Form 10-404 Revised 7/2009 ~ ~ _ ® /_~y,~~ Sub it Original Only f^"" ~~~~/r0 • • 5-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/10/2007fCTU #6. Unit on S-Pad. Get flat tires changed out. MIRU. Perform weekly BOPE ;test. Work on return micro motion. Shut down for night. ***Continued on 12/11/07 WSR*** Job in progress 12/11/2007CTU #6 with 1.75" coil. ***Continued from 12/10/07 WSR*** Kill well with 2% KCL. 'RIH with 2" BDJSN. Tag TD at 8512' ctmd. Correct to 8521' elm. Flag pipe at 18511'. Load backside with diesel. Mix and pump 46 bbls 15.8 ppg liner cement and 23 bbls 15.8 ppg cement w/ 12 ppb aggregate. Estimate TOC at 7770' and 41 b s ^~;behind pipe. Clean out and contaminate to 7800'. POOH, jet all jewelry, and stack. ,Freeze protect coil and well with 60/40. Trap 350 psi WHP. Stand back injector land secure well for night. Will either RDMO or make nozzle run to tag cement =tomorrow. ' ***Continued on 12/12/07 WSR*** 12/12/2007jCTU #6 Job Cont' From 12/11/07 WSR Drift and Tag. RIH with 2.0" JSN. Tag acement at 778T. Reconfirm tag @ 7785'. PT plug to 300psi(good). POOH. Freeze protect well to 2500' with 60/40 methanol. Notify Pad Operator of well status. RDMO ***Job Complete*** j 12/25/2007;T/I/0= 40/140/0. Temp- S/I. MIT-T PASSED to 1000psi. Held tight for entire 30 1 minute test. Pumped 0.5 bbls of 42* 60/40 Meoh to achieve test pressure. Final 'WHP= 40/140/0. Annulus casing valves are open to gauges. Wing is flagged 'closed and tagged. FLUIDS PUMPED BBLS 286 2% KCL 203 1 % X-SLK 40 1.5# BIO 72 DIESEL 122.5 60/40 METH 46 15.8 PPG "G" LINER CEMENT 23.2 15.8 PPG "G" CEMENT WITH 12 PPB AGGREGATE 44 FRESH WATER 836.7 Total TREE = 4-1/16" CM/ WELLHEAD = FMC 11" GEN 5 ACTUATOR = LEO KB. ELEV = 64.5' BF. ELEV = $6' KOP = 883' Max Angle = 70 @ 3873' Datum MD = 8127' Datum ND = 5000' SS 9-5/8" TAM PORT COLLAR 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" TOP OF 3-1/2" TBG STUB Minimum ID = 2.800" @ 7617' 3-1 /2" HES X NIPPLE, MILLED OUT ~ ~ 3-1/2" TBG, 9.2#, L-80, NSCT, .0087 bpf, ID = 2.992" ~ PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD MD ON 12!24/00 ANGLE AT TOP PERF: 27 @ 8000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2-1/2" 4 8000 - 8010 S 12!11/07 2-1/2" 6 8090 - 8130 S 12/11/07 2-1/2" 6 8150 - 8170 S 12/11/07 2-112" 4 8170 - 8190 S 12/11/07 2-1/2" 6 8190 - 8210 S 12/11/07 2-1/2" 6 8240 - 8260 S 12/11/07 2-1 /2" 6 8296 - 8316 S 12111 /07 2-118" 4 8320 - 8330 S 12!11(07 I I7" CSG, 29#, L-80 BTC/ HYD, .0371 bpf, ID = 6.182" I S-216 71, ~- ~ 4-1 /2" X 3-1 /2" XO, ID = 2.992" d9$' 3-1/2" HES X NIP, ID = 2.813" rAG I IFf MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 4 2653 2410 49 MMG DMY RK 0 08112!01 3 5154 3420 68 MMG DNIY RK 0 08/12/01 2 7401 4424 50 MMG DMY RK 0 08/12!01 1 7524 4506 45 MMG DMY RK 0 07105/05 7553' I--13-1/2" HES X NIP, ID = 2.813" 7574' -i 7" X 3-1/2" BKR S-3 PKR, ID = 3.875" 7594' 3-1/2" HES X NIP, ID = 2.813" 7612' UNIQUE MACH OVERSHOT 767' ~ 3-1/2" HES X NIP (MILLED 03!31101 }, ID = 2.80" 7" X 3-1/2" BKR S-3 PKR, ID = 3.875" 3-112" HES X NIP, ID = 2.813" 3-112" HES X NIP, ID = 2.813" 7697' -{3-1/2" WLEG, ID = 2.992" I 7696' ELMD TT LOGGED ON 04/02/01 7785' CTMD TOP OF CEMENT (12/1 07) 77$7' TOP OF 20' PUP Wl RA TAG 897' ~ TOP OF 20' PUP W/RA TAG (TOP OF SAND (04/16/02) ~ DATE REV BY COMMENTS DATE REV BY GOMMENTS 12!28!00 PGS ORIGINAL COMPLETION 07/05/05 KDC/PJC GLV C/O 08/12/01 D-14 RWO 10/22/05 RCC(PJC ACTUATOR CORRECTION 05/22/01 CSlKAK PERFS 11/02/05 GJB/TLH ADPERF 07/13/01 JLG/KAK ADPERFS /SAND DUMP 04/19/06 RCT/PJC GLV CORRECTION 07/08103 JJ/TLP PULL UPPER ECLIPSE/JET PUMP 02/17/08 TW/PJC DRAWING CORRECTION 04/02/05 WTSlTLH JET PUMP PULLED POLARIS UNIT WELL: S-216 PERMIT No: 2001970 API No: 50-029-22989-00 SEC 35, T12N, R12E, 964' FNL & 780' FWL BP Exploration (Alaska) • Page 1 of 1 Regg, James B (DOA) From: Engel, Harry R [Harry.Engel@bp.com] i ~ it'2~l o Sent: Monday, January 11, 2010 12:31 PM ~2d 9 To: Regg, James B (DOA) l I Cc: Foerster, Catherine P (DOA); Rossberg, R Steven; Cismoski, Doug A; NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor; Cyr, John E Subject: PBU S-216 NOV Jim- Thank you for the additional time. We will have a response to you by the end of the week. Harry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] ' Sent: Monday, January 11, 2010 11:29 AM To: Engel, Harry R Cc: Foerster, Catherine P (DOA) Subject: PBU S-216 NOV per our discussions, BPXA has until Tuesday, January 19, 2010 to respond to the Commission's notice of violation requiring information about the plugging of PBU S-216 (PTD 2001970). [Monday, January 18, was initially agreed to in our phone conversation but that is a State and Federal Holiday] Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 yr~~.i~~4~~°~~~ ~~}~ G ry~~~ 907-793-1236 ~ ~ '~' - v 1/11/2010 • • ;~- - ~ ~ ~~ ~ ~ ~~~ E ~ ~ ~ SEAN PARNELL, GOVERNOR ~17~A OIL AI~TD t]rv-7 r 333 W. 7th AVENUE, SUITE 100 COI~TSERQA7`IO1~T COrII~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Egor Makarov Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, 5-216 Sundry Number: 309-428 Dear Mr. Makarov: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount r~~ Chair DATED this ~ ~ day of December, 2009 Encl. ~, ~,.~~' ' STATE OF ALASKA , R~QL3F3V ~~ ALAS~OIL AND GAS CONSERVATION COMIVI~SS ~~~^~~O'v ~°~~'i~'~ APPLICATION FOR SUNDRY APPROVALS F!/T11~' ~~i~/LG ~n aar. ~~ ~Rn ~'~~D a~ DEC ~ ~ ~_ 1. Type of Request: Abandon ~ ~ Suspend ^ Operational shutdown ^ Perforate ^ - n r us en a e11 Alter casing ^ Repair well ^ Plug Perforations ^~ Stimulate ^ Other ^ ~~~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 200-1970 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service a 6. API Number: Anchorage, AK 99519-6612 50-029-22989-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ S-216 - 9. Property Designation (Lease Number): 10. Field/Pool(s): , ADLO-028261 ~ PRUDHOE BAY Field /POLARIS OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8713 5625.44 - 8612 5463 TOC 7785' 12/11/07 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 30 110 30 110 1490 470 Surface 3542 9-5/8" 40# L-80 29 3571 29 2871 5750 3090 Intermediate Production 8672 7" 29# L-80 26 8698 26 5611 8160 7020 Liner Perforation Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED' 4-1/2" 12.6# L-80 24 - 66 3-1/2" 9.3# L-80 66 - 7608 3-1/2" 9.3# L-80 7608 - 7697 Packers and SSSV Tvoe: 2-3/8" Patch Packer Packers and SSSV MD and ND fft): 7494 4551 2-3/8" Patch Packer 7520 4568 4-1/2" Baker S-3 Perm Packer 7574 4606 3-1/2" Baker S-3 Packer 7639 4653 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/28/2009 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ - WAG ^ Abandoned - ^~ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Egor Makarov Printed Name E r karov Title petroleum Engineer Signature Phone Date ~' 564-5687 12/14/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY N diti f l tif t ti it S d mb C N C i i th t er: ~~ on approva : y a represen ve may w ness un ry u ons o o omm ss on so a a Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ L ocation Clearance ^ o Other. Nd ~; t (~- d N, n+, : J'S.dlti y5? Gd • inn e-fs ~ ~ v/ G C.h~. c n~ ~~ .. l.Scv ~SG acs-.~. «~~4~zsiiz~l Subsequent Form Required: /~ . ~/Q '~- / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~~ z1 Form 10-403 Revised 07 0 ', ' + ; t~ ~ ~z Z 3" Submit in Duplicate ~.. tit ~~ii@ ~! 1t_. S-216 200-197 DFDF ATTA~_HMFNT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-216 4/2/01 PER 8,320. 8,330. 5,247.54 5,257.06 S-216 5/19/01 APF 8,170. 8,190. 5,104.79 5,123.82 S-216 6/12/01 FCO 8,050. 8,410. 4,993.05 5,333.26 S-216 6/12/01 FIL 8,060. 8,410. 5,002.17 5,333.26 S-216 6/30101 FCO 7,838.. 8,100. 4,808.42 5,039.03 S-216 6/30/01 FIL 7,838. 8,410. 4,808.42 5,333.26 S-216 7/2/01 APF 8,000. 8,010. 4,947.99 4,956.93 S-216 7/5/01 SPS 8,050. 8,100. 4,993.05 5,039.03 S-216 7/29/01 BPS 7,651. 7,662. 4,661.44 4,669.62 S-216 7/30/01 BPP 7,651. 7,661. 4,661.44 4,668.87 S-216 8/3/01 BPS 7,671. 7,681. 4,676.35 4,683.89 S-216 8118/01 BPP 7,671. 7,681. 4,676.35 4,683.89 S-216 8/26/01 FIL 8,108. 8,410. 5,046.46 5,333.26 S-216 8/30/01 FCO 8,108. 8,612. 5,046.46 5,527.8 S-216 11/18/01 FIL 6,020. 8,591. 3,840.58 5,507.49 S-216 11/19/01 FCO 6,020. 8,591. 3,840.58 5,507.49 S-216 10/31/05 APF 8,296. 8,316. 5,224.71 5,243.74 S-216 11/1/05 APF 8,150. 8,170. 5,085.85 5,104.79 S-216 11/1/05 APF 8,190. 8,210. 5,123.82 5,142.86 S-216 11/1/05 APF 8,240. 8,260. 5,171.42 5,190.45 S-216 11/2/05 APF 8,090. 8,130. 5,029.76 5,067.02 S-216 12/12/07 AB 7,785. 8,330. 4,765.13 5,257.06 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE by To: Jerry Bixby /Clark Olsen, Well Operation Supervisors From: Donald Reeves -Wells Engineer Taylor West -Orion/Polaris Production Engineer Subject: S-216 CT Cement Plug & Abandon PLD5M1090 Plua & Abandon • August 20, 2007 Est. Cost: $150M IOR: 500 BOPD Cost Code Note: This work is to be billed to the capital AFE PLD5M1090. This AFE is for new drill S-217i, which includes P&A of S-216i as part of the AFE scope. Please perform the attached P&A procedure: 1 F MITIA to 2500 psi, LLR if fails (pre P&A) 2 C Cement P&A perfs 3 F MIT-T to 1000 psi, LLR if fails (10 days post P&A) 4 S Drift and tag corrected cement top (10 days post P&A) Current Status: Last Infectivity: Deviation: Minimum ID: Last TD Tag: Last Downhole Ops: SBHP & BHT: Latest H2S value: Objective LTSI - "Operable" Produced Water Injector 6.5 bpm at 1720 psi (pumped from CTU on 10/10/05) Max of 70° at 3873' DD, ~ 18° at perfs to be P&A'd 2.80" -Milled out XN nipple at 7617' DD 07/02/07: Slickline tagged 8521' DD (corrected to TT) 07/02/07: Memory SBHPS 07/02/07: 1712 psi & 98° F at 5000' TVD Unknown - No Data The objective of this procedure is to permanently abandon the current perforated intervals from 8000'-8330' DD with a cement plug placed by coiled tubing from TD up to 7800' DD (200' over pert interval). For questions or comments: Contact Office Cellular Home Donald Reeves 907 564-4080 907 980-5490 Ta for West 907 564-4647 907 632-0111 907 337-2028 Jennifer Julian 907 564-5663 907 240-8037 907 274-0929 Note: JJ's cell phone may not work if called from the unit, may have to use alternate phone. cc: w/a: Well File S-216 CT - P&A • Background S-216 was drilled in 2000 as a deviated Schrader Bluff producer, and was proppant Frac'd several times in the O and N sands. The well had very poor productivity on gas lift, as well as on jet pump lift, and produced significant volumes of sand which filled up the liner. After several unsuccessful attempts to sustain production on jet pump, the well was converted to produced-water injection to support newly drilled multilateral S- 213A. The well was on injection from 11/05 through 7/06, then it was shut-in due to the risk of a matrix bypass event (MBE) which is ashort-circuit from injector to producer. Offset injector S-2151 experienced an MBE to S-213A in 2006, so S-216 was SI as a preventative measure since it was configured similarly to S-215i. Due to significant differences in rock and oil quality between the 5+ Schrader Bluff sands, the field development plan relies on highly controlled injection into each sand by utilizing amulti-packer completion, and zone-specific waterflood regulators. It is suspected that the frac in S-216 has broken the shale barriers between sands, so intra- zone isolation has been lost in the near-wellbore region. Anew grass-roots injector, S- 217 is planned as a replacement well to be drilled in the S-216 area. Prior to initiating injection in S-217i, S-216 will need to be cement squeezed to prevent cross flow between the sands at the wellbore, and through the fracs. After the frac and perfs are squeezed, S-216 will be classified as a LTSI well available for future sidetrack utilization. ~' Coy c v~ ~~~~~ ja~~~Q~ Job Plannin Perforations: 8000'-8010' (10') -Added 07/02/01 8090'-8130' (40') -Added 11/02/05 8150'-8210' (60') -Added 05/19/01 & 11 /01 /05 8240'-8260' (20') -Added 10/31 /05 8296'-8316' (20') -Added 10/31 /05 8320'-8330' (10') -Original perfs from 04/02/01 (160' Total) Gas Lift Design: DGLVs at 2653', 5 154', 7401' & 7524' DD Drift History: 07/02/07: Slickline tagged 8521' DD (corrected to TT) 04/18/06: Slickline tagged 8512' DD (corrected to TT) 10/22/05: Slickline tagged 8428' DD (corrected to TT) 10/10/05: CT jetted to 8600' CTM during FCO Wellbore Volume: 99 bbls in Tbg & Liner, 72 bbls in CTxTbg backside Fracture Pressure: 3350 psi at the sandface (frac gradient = 0.67 psi/ft) Static: 07/02/07: 1712 psi & 98° F at 5000' TVD A full column of diesel will be slightly overbalanced. Cement Design: Place 45 bbls of class G liner blend in rathole and behind pipe. Cover perfs with 18 bbls class G cement with aggregate. 2 2 S-216 CT - P&A • Discussion With a static bottom-hole pressure of only 1712 psi, the well will be overbalanced with either 1% KCI, dead crude, or diesel. This could make it difficult to see positive wellhead pressure unless squeeze pressure builds. Infectivity into the perfs is high (CT established an infectivity rate of 6.5 bpm at 1720 psi following a fill clean out on 10/10/2005). A review of the job details for a P&A of V-201 dated 3-3-07 will provide information on how a similar low-BHP job was completed. In order to prevent possible future cross flow between sands, 45 bbls of class G liner blend (low fluid loss) will be placed in the rathole and squeezed into the formation as part of the abandonment. Standard class G cement (high fluid loss) with aggregate will be left in the wellbore to complete the plug. There were no mechanical issues during the last CT work in the well on 10/10/05. P&A Program Fullbore 1. MITIA to 2500 psi, establish leak rate if fails. Coiled Tubing P&A 2. MU BHA with 2.25" BDN and stingers as necessary (this will be done with no checks). Min. ID in well = 2.80" 3. Bullhead down backside at max rate with 1.5x wellbore volume of 2% KCI (150 bbls) to kill well. Continue pumping at min rate to keep well liquid packed. • The tubing was freeze protected with gas down to 8100'. 4. RIH and dry tag bottom. Pick up until full string weight is recovered and set depth to corrected depth of 8521' DD tagged by slickline. PUH additional 10' and flag pipe. PUH to 8000'. 5. Pump a full column of diesel down the backside (~72 bbls) to minimize the amount of overbalance on the well (~58 psi overbalanced) (based on SBHP of 1712 psi at 5000' TVD). Do not proceed with P&A unless the tubing is liquid packed and gas free. 6. Batch mix 45 pumpable bbls Class G cement to meet the following Volume to Pump 45 bbls total Cement Type 15.8 ppg Class G "Liner Blend" Fluid Loss 10 cc/30 minutes at 98°F BHT Acceptable Range 8-15 cc/30 minutes at 98°F BHT Compressive Thickening Time 2000 psi ultimate 5-7 hours 3 s S-216 CT - P&A , 7. Batch mix 18 pumpable bbls Class G cement to meet the following ions: Volume to Pump Cement Type Fluid Loss Acceptable Rang Compressive Thickening Time 18 bbls total 15.8 ppg Class G with Aggregate (~12#/bbl) 100 cc/30 minutes at 98°F BHT e 60-120 cc/30 minutes at 98°F BHT 2000 psi ultimate 5-7 hours 8. Catch samples of cement for QC testing and place in hot water bath. Line up cementers to the coil. 9. With backside SI, pump the following down the coil: • 10 bbls spacer water (Do Not use J313 Friction Reducer as it will clabber cement) • 45 bbls Class G "Liner Blend" • 18 bbls Class G with Aggregate (empty tub mixer) • Displace with spacer water 10. RIH with coil to flag as cement reaches nozzle & open backside to take returns. • With the well overbalanced (even with a column of diesel in the backside), returns to surface may not be possible. Positive pressure and fluid returns may not be seen until cement builds a filter cake across perforations. 11. Pump 3 bbls of liner blend cement out nozzle before pulling uphole. (Ideally this will place 87' of cement above nozzle to prevent dilution while PUH). After 3 bbl of cement is out the nozzle, PUH and lay in additional 20 bbls of liner blend cement 1:1 to a depth of 7980' (just above the~top perf). 12. Shut-in the backside choke and reciprocate coil just above top perf at 7980' pumping the remaining 22 bbls of liner blend cement and 14 bbls of Class G with aggregate to displace the liner blend into the formation fracture (this assumes 1 bbl of class G with aggregate leaks off to formation before building a filter cake). • Do not build squeeze pressure with coil across the perfs to avoid getting "noded-in" (although this is unlikely with the liner blend). • Class G liner blend has low fluid loss and should flow thru the fracture without plugging off. It may however build some pressure as a small filter cake is formed then breaks down with additional squeeze pressure. • If squeeze pressure rises over 1000 psi without breaking down, then open choke and lay in rest of cement 1:1. Drop ball and pump Biozan to 4 4 S-216 CT - P&A • contaminate the extra cement down to desired cement top of 7800'. Jet uphole at 80% pulling speed and max CT pressure. If no liner blend cement is displaced into the formation, the WCTOC would be 4080'. This is unlikely given the large proppant size in the frac and the low fluid loss property of the liner blend cement. 13. If 14 bbls of class G with aggregate successfully displaces the liner blend into the formation, open backside choke keeping 100-200 psi backpressure, PUH and layer in 1:1 the remaining 4 bbls of cement. Position nozzle at cement top just as last barrel of cement reaches nozzle. Remember there should be ~3 bbls of cement above the nozzle. • If all 35 bbls of liner blend cement is successfully displaced into the formation this should leave the TOC 7800'. 14.If squeeze pressure built up during the aggregate pumping and it is felt that aggregate cement stayed in liner, then freeze protect the top 2000' and RDMO. 15. However, if the backside pressure stayed at 0 psi (or was on a vac) during the final aggregate pumping, then consider the option to have CTU standby until SWS lab confirms cement has reached enough compressive strength to RIH and dry tag. It is acceptable to have the cement top as deep as 7900'. • This option will require several hours of standby time but is better than+ finding out later from the slickline drift that TOC is too low, requiring. a new RU and squeeze. /~L .23-a~ Fullbore ~ ~a ~~~ z5.1TZ~ ~(Z~ ~ ~~' p,:, ~ o~ 16. RU Fullbore and perform MIT-T to 1 psi, establish leak rate if fails. ' slickline 17. RU slickline and drift to cement top with TEL and sample bailer. Correct tag to tubing tail and note any returns from the bailer. 5 5 S-216 CT - P&A TREE= d-1f16 GiW WELLHEAD= FMC 11" GEN 5 ACTUATOR = LEO KB ~tV = _ 64.5' .ew...,. BF. ELEV = ., . . „,~.- .. ,...,_w 36' KOP= 88 3' Max Angle -~-. TM~T _ _ ~ ._,_, 70 @3873' n°. n. -._._. . Datum MD - 8127' Datum TV D = 5000' SS 9-518" TAM PORT COLLAR 35/8" CSG, 40#, L-80 BTC, ID = 8.835" ITOP OF 3.112" TBG STUB 1 ~z 1 ~ 761~CTOMILLED O~ QZZ 800'1' iD 03S/ 1 01 71' 4-1/2" X 3-112" XO, ID= 2.992" 2098' 3-112" HES X NIP, ~ = 2.813" C~A.S L~-T fNAN~ElS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 2653 2410 49 NMG DMY RK 0 08/12/01 3 5154 3420 68 MMG DMY RK 0 08/12(01 2 1 7401 7524 4424 4506 50 45 MMG MMG DMY DMY RK RK 0 0 08/12101 07!05/05 1006' 3571' 7553' ~--13-1/2" HES X NP, ID = 2.813" I 7574' 7" X 3-112" BKR S•3 PKR, ~ = 3.875" 7594' 3-112" HES X N~, ID = 2.813" 7612' BTM OF UNIQUE MA CH OV ERSH07 Minimum ID = 2.800" @ 7617' 3-1 /2" HES X NIPPLE, MILLED OUT 7617' I--I3-1 /2" HES X N~, MLLED ID = 2.80" (03131 /01) I 7639' I--I7" X 3-112" BKR S•3 PKR, m = 3.875" 7664' 3-1/2" HES X NIP, ID = 2.813" 7685' 3-112" HES X N~, ID = 2.813" II 3-112" TBG, 9.2#, L-$0, NSCT, .0087 bpf, O = 2.992" I"'I 7696' PERFORATION SUMMARY REF LOG: SPERRY-SUN MIND MD ON 12/24/00 ANGLE AT TOP PERF: 27 @ 8000' Note: Refer to Production ~ for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 4 8000- 8010 O 07102/01 2-112" 6 $090- 8130 O 11102/05 2-112" 6 8150 - 8170 O 11101!05 2-112" 4 8170- 8190 O 05/19!01 2-112" 6 8190 - 8210 O 11/01/05 2-112" 6 8240-8260 O 10!31/05 2-1/2" 6 8296-8316 O 10/31/05 2-118" 4 8320 - 8330 O 04/02/01 I7" CSG, 29#, L-80 BTC! HYD, ~ = 6.182" I DATE REV BY COMMENTS DATE REV BY COMMENTS 12/28100 PGS ORIGINAL COMPLETION 07/05/05 KDGPJC GLV GO 08!12!01 CH RWO 10/22/05 ROGPJC ACTUATOR CORRECTION 05/22/01 CS/KAK PERFS 11102/05 GJB/TLH ADPERF 07/13/01 JLG/KAK ADPERFS / SAID DUMP 04/19V06 RCT/PJC GLV (:ORRECTION 07/08/03 JJ/TLP PULL UPPER ECL~SE/JET PUMP 04/02/05 WTS(TLH JET PUMP PULLED POLARIS UNfT WELL: S-216 PERMR No:2001970 API Na: 50-029-2298300 SEC 35. T12N, R12E, 4501' FEL & 4317' FSL BP 6cpioration (Alaska) 7696' ELMD TT LOGGED ON 04102!01 7787' TOP OF 20' PUP W/ RA TAG 8605' I--ITOP OF SAND (04/16102) • • December 14, 2009 Certified Mail Return Receipt Requested 7009 2250 0004 39114856 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Notice of Violation Plugging PBU 5-216 without Approval PTD 2001970 Polaris Oil Pool Dear Mr. Rossberg: The Alaska Oil and Gas Conservation Commission (Commission) recently completed a compliance review of BP Exploration (Alaska) Inc. (BPXA) operated injection wells in Alaska, focusing on mechanical integrity testing (MIT). In electronic mail correspondence with BPXA's North Slope Well Integrity Office on December 11, 2009, the Commission provided a list of injection wells with unknown MIT status. Information provided by BPXA about Prudhoe Bay Unit 5-216 (PTD 2001970) indicates the injection well was plugged and abandoned on or about July 20, 2007 without Commission approval. Rule 11 of Area Injection Order (AIO) 25A addresses the plugging and abandonment of fluid injections wells in the Polaris Oil Pool, stating: "An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. " Rule 12 of AIO 25A requires BPXA to comply with all regulatory requirements of the Commission. Failure to obtain Commission approval as required prior to plugging and abandonment of PBU 5-216 constitute a violation of AIO 25A. Within 14 days of receipt of this letter, BPXA is required to provide the following: Form 10-407, "Well Completion or Recompletion Report and Log", with appropriate attachments documenting the work completed, including the Daily Operations Summary Report; u December 14, 2009 Page 2 of 2 • - Documents confirming the type, depth, size, and verification testing of all plugs placed in the well; - Current well schematic; - Discussion of what procedures BPXA will put in place to prevent recurrence of similar non-compliance items. The Commission reserves the right to pursue further enforcement action in connection with this apparent violation as provided by 20 AAC 25.535 and AS 31.05.150. Should you have any questions regarding this correspondence, please contact Mr. James Regg at (907) 793-1236. Sincerely, Daniel T. Seamount, Jr. Chair RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be en•oneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration aze FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. . . Page 1 of 3 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, December 11, 2009 2:49 PM To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA); Preble, Gary B (SAIC); Makarov, Egor Subject: RE: Missing MITs Jim, Correct, our records show the last injection in S-216 (PTD 2001970) was 07/20/06. It appears a 10-403 was never submitted to the AOGCC. I have contacted the town engineer and asked him to begin working with the group that manifests the sundries to bring us into compliance with the AOGCC. Please let me know if you need anything from the Well Integrity Dept. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 11, 2009 12:34 PM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: Missing MITs re: PBU S-216 (PTD 2001970) - Our data shows last injection was 7/20/2006. - I do not find in our well file any request to P&A or subsequent report of plugging ops which you indicate were completed on 12/11/07; do you mean the well was secured? Please provide appropriate info to document completed work. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, December 11, 2009 11:18 AM 4/15/2010 ~ ~.~ ~~~~ ~'~~ Page 2 of 3 To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: Missing MITs Jim, MPU E-07 (PTD 1910490) was pressure tested on 05/25/09, however, our records do not show who the inspector was on location. I have attached the MITIA form for your review. The well is currently on water injection. PBU 04-10 (PTD 1760420) was reclassified as Not Operable on 11/07/09 due to a failing MITIA. A tubing patch was set on 12/07/09 to mitigate the TxIA communication. On 12/08/09, the well was placed on water injection for a state witnessed MITIA. PBU 12-19 (PTD 1821980) Our records show that AIO 4C.013 was cancelled on 09/14/07. I have attached the canceled AA for your reference. The well was worked over on 11/20/08 and placed on a 4 year MITIA schedule. It is currently on water injection. MPU E-03 (PTD 1890170) is scheduled for a witnessed by John Crisp today. I will provide you a copy of the MITIA form at the end of the month. It is currently on gas injection. PBU S-216 (PTD 2001970) was P&A'd on 12/11/07 and hasn't been injected in since 07/20/09. There are no '-~ plans to inject in this well in the near future. I hope this helps and please let me know if you need anymore information. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 11, 2009 9:51 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: Missing MITs Following MITs are missing or late: MPU E-07 (PTD 1910490) due 10/16/2009 PBU 04-10 (PTD 1760420) due 11/19/2009 PBU 12-19 (PTD 1821980) due 12/6/2009 (AIO 4C.013) Followng MITs are due: MPU E-03 (PTD 1890170) due 12/12/2009 --~ PBU S-216 (PTD 2001970) due 12/13/2009 These wells are shown in our database as currently injection as of October 31; unfortunately our production/injection data lags a month so some or all of these may currently be SI. Please provide current status and, if MITs have been performed that satisfy the Commission's regulatory requirements, forward the test results. Jim Regg 4/15/2010 • • June 25, 2009 ~ ~~ ~ ~ ~- ~ 1 ~.~~ ~`~~ ~.~-.9 ~-~ JUL ~ ~. 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~,~~~~~ ~~! ~ C~,e ~~nc~ ~~~r~i~~i~€~ 333 West 7th Avenue ~~~~~~~~~c,~ Anchorage, Alaska 99501 ~~o - ~q~ Subject: Corrosion (nhibitor Treatments of S-Pad 5 ~ c~ t/_ O~, (~ Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to fi~ling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, t{'w ~Y;'"1~?' ,.1„j~ •~i ~ d^UJ~1 Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Seaiant Top-oH Report of Sundry Operetions (10-404) &pad I]atw 6/25/2009 Well Name PTD k Initial top ot cement Vol. of cement um ed Final top of cement Cemern rop off date Corrosion inhibitor Corrosion inhibitod sealant date it bbls tt na al S-Ot8 1952020 025 NA 0.25 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 7.7 5/25/2009 S-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 S-oa 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-O6 1821650 0 NA 0 NA 0.9 5/26/'2009 S-07A 1920980 0 NA 0 NA 0.9 5/26l2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/37/2009 S-t0A 1971230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/t/2009 5-13 7821350 8 NA 8 tJA 55.3 6/1/2009 S-15 1840170 025 NA 0.25 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-79 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 0.25 NA 025 NA 7.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.s 5/25/2009 5-26 19~580 0.75 NA 0.75 NA 3.a 5/26l2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31l2009 S-29AL1 1960120 0 NA 0 NA 0.85 5/27/2009 S-30 1900660 0.5 NA 0.5 NA 5.7 5/31/2009 S-3tA 7982200 0.5 NA 0.5 NA 3.a 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/3112009 5-35 1921480 0 NA 0 NA ~,e5in 5/31f2009 S36 1921 t60 0.75 NA 0.75 NA 4.25 5/27/2009 5-37 1920990 125 NA 125 NA 11.9 5/27/2009 5-38 1921270 0.25 NA 025 NA 102 5/27/2009 S-a7 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5/3W2009 S-43 1970530 0.5 NA 0.5 NA 7 J 5/28I2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 S•100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 ~ 2001150 1.25 NA 1.25 NA 71.9 5/29/2009 S-t0211 2031560 125 NA 125 NA tt.t 5/31/2009 S-t03 2001660 1.5 NA 1.5 NA t7.s 5/18/2009 S-t04 2001960 1.75 NA 7.75 NA t5.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.~ 5/20/2009 5-106 2010120 1625 NA 76.25 NA 174.3 6/2/2009 S-t07 2011130 2.25 NA 225 NA 28.9 5/18l2009 5-708 2011000 3.5 NA 3.5 NA 40 SI30/2009 5-109 2022450 2 fVA 2 NA 27.3 5/30/2D09 S-710 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 S-~ 13 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 Sa14A 2021980 725 NA 125 NA 10z 5/30/2009 S-7~5 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2~9 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-719 2041620 1 NA 1 NA 52 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2~9 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA ii.9 5/26/2009 5-125 2070830 225 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 725 NA 15.3 6~112009 5-200 1972390 125 NA 125 NA 14.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18J 6/7/2009 ~ S-218 2007970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 025 NA 0.25 NA 7.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.a 5/28/2009 S•401 2060780 i6 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 Sclllunl~ePgeP RI:CEIVED SEP 1 5 2006 ~OH & Gas Cons.~j¡ 't~ ~~" 09/15/06 NO. 3963 Schlumberger-DCS 2525 Gambell St, Su~e 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Altn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Polaris Well Job # Log Description Date BL Color CD V-213 40010719 OH EDIT OF MWDILWD 07/22/04 2 1 V-213 PB1 40010719 OH EDIT OF MWD/LWD 07/18/04 2 1 S-2t6 11296702 INJECTION PROFILE 07/18/06 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Schiumberger·DCS 2525 Gambeil St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: . 5CANNED SEP 1 ~ 20Df; UI~DtO~lq~ MEMORANDUM e e State of Alaska Alaska Oil and Gas Consel"Vation Commission TO: Jim Regg P.I. Supervisor 1<efi IZltHD7" DATE: Wednesday, December 14,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-216 PRUDHOE BAY UN POL S-216 ifDO- \ q 1 FROM: Jeff Jones Petroleum Inspector Sre: Inspector Reviewed By: P.I. SuprvJßL- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN POL S-216 API Well Number 50-029-22989-00-00 Insp Num: mitJJ051213171527 Permit Number: 200-197-0 Rei Insp Num Inspector Name: Jeff Jones Inspection Date: 12/13/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. we'I'I"S-216 "'rTYP~~I-;'j~~-wlTVn-'r-~'Ùi06!-iAI-IO-25---'-"-~î6-I-o"'T--ï570-T---I55S---T"··.'··· ~--T"~--- ~~?~'~k~'#",T':tJ';¡i ",,; }:~~J~:;:-=~+~:=r ~:r=I~=:=- _,~,______________",____________________~______ _______L____L_.__~____~_~~__._________.._.__L.______.~,___ __.~~_____ Notes 0.9 BBLS 60/40 methanol pumped. 1 well house inspected; no exceptions noted. '';;'.·I('fì,\!'H\'Ir:;r J \;::,';~71', -~.!\,:,; '" :..;::...",:~ Wednesday, December 14, 2005 Page 1 of 1 TREE = WELLHEAD = A CTUA TOR = KS. ELBI = SF. ELBI = KOP= Max Angle = Datum MD = Datum lVD = 4-1/16" CIW FMC 11" GEN 5 LEO 64.5' 36' 883' 70 @ 3873' 8127' 5000' SS e 19-5/8" TAM PORT COLLAR H 1006' I 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" I I TOP OF 3-1/2" TBG STUB H 7594' ELM I Minimum ID = 2.800" @ 7617' 3-1/2" HES X NIPPLE, MILLED OUT I 3-112" TBG, 9.2#, L-80, NSCT, .0087 bpf, ID = 2.992" I ÆRFORA TION SUMMARY REF LOG: SÆRRY -SUN MWD MD ON 12/24/00 ANGLEATTOPÆRF: 27 @ 8000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 8000 - 8010 0 07/02/01 2-1/2" 6 8090 - 8130 0 11/02/05 2-1/2" 6 8150 - 8170 0 11/01/05 2-1/2" 4 8170 - 8190 0 05/19/01 2-1/2" 6 8190 - 8210 0 11/01/05 2-1/2" 6 8240 - 8260 0 10/31/05 2-1/2" 6 8296 - 8316 0 10/31/05 2-1/8" 4 8320 - 8330 0 04/02/01 17" CSG, 29#, L-80 STC I HYD, ID = 6182" I 8698' , , !~t [0 I¡ , II I' i ~ ! V L DATE 12/28/00 08/12/01 OS/22/01 07/13/01 07/08/03 04/02/05 RBI BY COMMENTS PGS ORIGINAL COM PLETION CH RWO CS/KA K PERFS JLG/KAK ADÆRFS I SAND DUMP JJ/TLP PULL UPÆR ECLIPSE/JET PUMP WTS/TLH JET PUMP PULLED DATE 07105/05 10/22/05 11/02/05 5-216 RBI BY KDC/PJC RCc/PJC GJB/TLH S NOTES: UNDERSIZED 3-112" HES X NIP @ 7617' - CT MILLED OUT TO 2.800" ID - 03131/01. 2098' ST MD lVD 4 2653 2410 3 5154 3420 2 7401 4424 1 7524 4506 71' -4-1/2" X 3-1/2" XO, ID = 2.992" I -j3-1/2" HES X NIP, ID = 2.813'" GAS LIFT MANDRELS DBI TYÆ VLV LATCH 49 MMG DMY RK 68 MMG DMY RK 50 MMG DMY RK 45 MMG DMY RKP FûRT DA TE o 08/12/01 o 08/12/01 o 08/12/01 o 07105/05 7553' - 3-1 /2" HES X NIP. ID = 2.813" I 7574' -j 7" X 3-1/2" BKR S-3 PKR, ID = 3.875" I 7594' -j 3-1/2" HES X NIP, ID = 2.813" I 7612' -l BTM OF UNIQUE MACH OVERSHOT 7617' H3-1/2"HESXNIP,MILLEDID=2.80"(03/31/01) I 7639' -j 7" X 3-1/2" BKR S-3 PKR, 10 = 3.875" 7664' - 3-1/2" HES X NIP, ID = 2.813"1 7685' - 3-1/2" HES X NIP, ID = 2.813" I COMMENTS GL V C/O A CTUA TOR CORRECTION ADÆRF 7697' 7696' - WLEG I H ELMD TT LOGGED ON 04/02/01 I - TOP OF 20' PUPW/ RA TAG I 8097' -l TOP OF 20' PUP W/RA TAG I 8605' -lTOP OF SAND (04/16/02) I POLA RIS UNIT WELL: S-216 ÆRMIT No: "2001970 API No: 50-029-22989-00 SEC 35, T12N, R12E, 4501' FEL & 4317' FSL SP Exploration (Alas ka) e STATE OF ALASKA _ ALASKA Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D [] 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 64.52 KB 8. Property Designation: ADL-028261 11. Present Well Condition Summary: Total Depth measured 8713 true vertical 5625.44 Effective Depth measured 8605 true vertical 5521.03 Casing Conductor Surface Production Length 80 3542 8672 Size 20" 91.5# H-40 9-5/8" 40# L-80 7" 29# L-80 Perforation depth: Measured depth: 8000 - 8010 8320 - 8330 True Vertical depth: 4947.99 - 4956.93 5247.54 - 5257.06 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): K I::: t; I:: IV I:: U DEC 12 2005 iöi1 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic rJ Stimu~ate D . ther D ARsl:lørage Waiver D Time Extension D Re-enter Suspended Well D·.....j¡I 5. Permit to Drill Number: Exploratory Service 200-1970 P' 6. API Number: 50-029-22989-00-00 9. Well Name and Number: S-216 10. Field/Pool(s): Prudhoe Bay Field/ Polaris Oil Pool feet Plugs (measured) None feet Junk (measured) None æANNEr" fJE. C 'r ~ feet '-.,.- ',:.'< feet MD TVD Burst Collapse 30 - 110 30 - 110 1490 470 29 - 3571 29 - 2870.76 5750 3090 26 - 8698 26 - 5610.94 8160 7020 8090 - 8130 8150 - 8210 8240 - 8260 8296 - 8316 5029.76 - 5067.02 5085.85 - 5142.86 5171.42 - 5190.45 5224.71 - 5243.74 4-1/2" 12.6# L-80 24 - 71 4-1/2" Baker S-3 Perm Packer 3-1/2" Baker S-3 Packer 7574 7639 Treatment descriptions including volumes used and final pressure: RBDMS 8FL DEC ¡ 20ns 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o Shut-In o 547 15. Well Class after proposed work: Exploratory rJ Development 16. Well Status after proposed work: Oil Gas rJ WAG 700 Tubing pressure 1450 1900 Service P' WDSPL rJ .W:I!W"Jt 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Title Data Mgmt Engr Phone 564-4424 Date 12/6/2005 Form 10-404 Revised 04/2004 OR\G\NAL Submit Original Only .. HI::CEIVED e STATE OF ALASKA. D ALASKA OIL AND GAS CONSERVATION COM~SION EC 0 5 2005 REPORT OF SUNDRY WELL OPERATIONS Alaska 0" & G I as Cons. " , 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D Other DAnChttr. Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown D Perforate [] Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P'J Exploratory 200-1970 3. Address: P.O. Box 196612 Stratigraphic rJ Service rJ 6. API Number: Anchorage, AK 99519-6612 50-029-22989-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.52 KB S-216 8. Property Designation: 10. Field/Pool(s): ADL-028261 Prudhoe Bay Field/ Polaris Oil Pool 11. Present Well Condition Summary: Total Depth measured 8713 feet Plugs (measured) None true vertical 5625.44 feet Junk (measured) None Effective Depth measured 8605 feet true vertical 5521.03 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3542 9-5/8" 40# L-80 29 - 3571 29 - 2870.76 5750 3090 Production 8672 7" 29# L-80 26 - 8698 26 - 5610.94 8160 7020 Perforation depth: Measured depth: 8000 - 8010 8090 - 8130 8150 - 8210 8240 - 8260 8296 - 8316 8320 - 8330 True Vertical depth: 4947.99 - 4956.93 5029.76 - 5067.02 5085.85 - 5142.86 5171.42 - 5190.45 5224.71 - 5243.74 5247.54 - 5257.06 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24 - 71 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 7574 3-1/2" Baker S-3 Packer 7639 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: R8DMS BFl DEC 0 (; 2005 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 Shut-In 1450 Subsequent to operation: 0 0 547 700 1900 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory rJ Development P'J Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil P'J Gas rJ WAG rJ GINJ rJ WINJ rJ WDSPL rJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Title Data Mgmt Engr ~./ Phone 564-4424 Date 11/30/2005 Signat .I r;¿,.£d,U Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only -_. e e S-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ~C!TVlfY.!lAtìiE II ,äF~F,~ I~ l'~' ,P;:~~~~'t;:'ä;:L;¡~~"'J.; ;.IIj¡ 10/31/2005 CORRELATED TO SPERRY-SUN MWD GR LOG DATED 23-DEC-2000 (INJ CONVERSION - ADD PERFS) PERFORATED 8296 - 8316 FT WITH 2.5" PJ 6 SPF HSD **CONT. PERFORATING IN AM-NOTIFY DSO OF WELL STATUS** 11/1/2005 CORRELATED TO SPERRY-SUN MWD GR LOG DATED 23-DEC-2000 PERFORATED 8240-8260, 8190-8210, 8150-8170 FT WITH 2.5" PJ 6 SPF HSD 11/2/2005 Perforate from 8090-8130' with 2.5" HSD guns loaded 6 spf with Powerjet charges. Log correlated to Sperry MWD GR log~<:1ated 12/23/2000. FLUIDS PUMPED BBLS 33 4 37 I Diesel Meth TOTAL ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATION§n ) 1. Operations Perlormed: Abandon D Alter CasingD Change Approved Program D Repair Well[&! Pull TubingD Operation Shutdown D PluQ Perforations D Perforate New Pool D Perforate D 'l 7 2005 Stimulate IJlaska 0,·, & Ga C OtherŒ CONVERTED Sons. Com' . waiverD JJ_Hg~iOn U"¥§SJSIRJ Re-enter Suspended WellD 2. Operator Name: 3. Address: 4. Current Well Class: Development D ExploratoryD 5. Permit to Drill Number: 200-1970 6. API Number 50-029-22989-00-00 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.52 8. Property Designation: ADL-028261 11. Present Well Condition Summary: StratigraphicD Service[&) 9. Well Name and Number: S-216 10. Field/Pool(s): Prudhoe Bay Field / Polaris Oil Pool Total Depth measured 8712 feet true vertical 5624.5 feet Plugs (measured) None Effective Depth measured 8605 feet Junk (measured) None true vertical 5521.0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 110 30.0 110.0 1490 470 Surface 3542 9-5/8" 40# L-80 29 - 3571 29.0 - 2870.8 5750 3090 Production 8672 7" 29# L-80 26 - 8698 26.0 - 5610.9 8160 7020 Perforation depth: Measured depth: 8000 - 8010, 8170 - 8190, 8320 - 8330 True vertical depth: 4947.99 - 4956.93,5104.79 - 5123.82,5247.54 - 5257.06 Tubinç¡ ( size, Qrade, and measured depth): 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 3-1/2" 9.3# L-80 @ 24 @ 66 @ 7608 66 7608 7697 ., ~l-') ~U'l 2, 6GA,\\\N~L. ~.» ~ ?Gß:l Packers & SSSV (type & measured depth): 3-1/2" Baker S-3 Packer 4-1/2" Baker S-3 Perm PKR 3-1/2" HES X Nipple @ 7639 @ 7569 @ 2098 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Representative Dailv Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure CONVERTED TO WINJ WELL o (Started on 07-14-2005) Tubing Pressure Prior to well operation: Subsequent to operation: 1818 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD ServiceŒ Signature DeWayne R. Schnorr ;;;Z;::;¿y~ WAG D GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 305-026 & 305-095 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Petroleum Engineer Phone 564-5174 Date 7/26/05 ORIGINAL RBDMS BFL ,JUL 2 8 2005 Form 10-404 Revised 4/2004 ') ) 5-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/26/05 CTU #4: HOT/FISH JET PUMP. ***WELL SHUT IN UPON ARRIVAL*** RIH W/ 2.011 JSN. DID NOT SEE ANY RESISTANCE RUNNING IN HOLE. JETTED DIESEUXYLENE TO TOP OF JET PUMP @ 7497'. JET DIESEUXYLENE WHILE POOH @ 80%. MU WFD FISHING TOOLS. ***CONTINUED ON 3/27/05*** 03/27/05 CTU#4: PULL JET PUMP. ***CONTINUED FROM 3/26/05*** RECOVER UPPER AND LOWER HALF OF ECLIPSE PATCH/JET PUMP ASSEMBLY IN 2 RUNS (UPPER HALF OF PATCH WAS TEMPORARILY TRAPPED IN MASTER WHILE FISHING TOOLSTRING WAS SHORTENED). RIH W/ 211 JSN. ***CONTINUED ON 3/28/05*** 03/28/05 CTU#4: JET DIESEL. ***CONTINUED FROM 3/27/05*** CONT. RIH W/ 211 JSN. ENCOUNTER CONSIDERABLE DIFFICULTY, OVERPULLS WHILE RIH DUE TO STICKY OIL. PUMP HOT WATER DOWN COIL, WHILE WAITING ON DIESEL TANKER - NO IMPROVEMENT. JET LINER FROM 7697' TO BELOW BOTTOM PERF @ 8350' CTMD WITH COLD DIESEL. CHASE OUT W/ DIESEL @ 80%. PICK-UP WEIGHTS DROPPED SIGNIFICANTLY. FREEZE PROTECT FLOWLINE W/ 5 BBLS 60/40 MEOH. LEFT WELL SI. NOTIFIED PAD OPERATOR OF CONDITION. ***JOB COMPLETE*** 03/30/05 T/I/0=410/190/150. SI. TBG & IA FL (PRE MITIA, INJECTION CONVERSION). TBG FL @ SURFACE. IA FL @ SURFACE. 04/02/05 ***WELL SHUT-IN UPON ARRIVAL*** (SBHPS / CHANGE STATION #1 TO SHEAR VALVE) RUN SBHPS, GOOD DATA. GET STUCK IN HOLE W/ CATCHER SUB. 2 5879' SLM LRS TO PUMP. LRS PUMPING DOWN THE IA. *** CONTINUE ON WSR 4-3- 05*** 04/03/05 CONTINUED FROM 4-2-05 ASSIST SLICK LINE, PUMPED 256 BBLS (TOTAL) DIESEL DOWN IA @ 180*. PUMPED 110 BBLS 180* HEATED DIESEL DOWN TUBING. FINAL WHP'S=850/660/120. 04/03/05 ***CONTINUED FROM WSR 4-2-05*** (SET SHEAR VALVE IN #1 STATION). STUCK IN HOLE AT 5879' SLM, NO JAR ACTION. PUMP HOT DIESEL DOWN IA WHILE FLOWING WELL. . PUMP DIESEL DOWN TBG AND GOT TOOLS FREE. APPEARS TO BE POSSIBLE RUBBER FROM PULLING. THE JET PUMP. RETRIEVED ALL TOOLS FROM WELL. RAN A 2.811 B/L BRUSH AND A 2.5" GAUGE RING TO THE TUBING TAIL.. IILRS PUMPED 100 BBL OF DIESEL". SET 3.511 X-CATCHER @ 7569' SLM.. STUCK IN HOLE @ 5128' SLM, NO JAR ACTION. WAIT FOR LRS TO PUMP HOT DIESEL DOWN TUBING.. *** CONTINUED ON WSR 4-4-05*** 04/04/05 T/I/0=550/560/0 ASSIST SLlCKLlNE (HOT OIL TREATMENT) - PUMP AS DIRECTED. PUMPED 64 BBLS DIESEL @ 90* DOWN TUBING. PUMP 100 BBLS 180* HEATED DIESEL DOWN IA TAKING RETURNS DOWN FLOWLINE TO FREE UP SLlCKLlNE. PUMP 30 BBLS 180* HEATED DIESEL DOWN TUBING WHILE SLB BRUSHES. FINAL WHP'S=600/650/300. ***CONTINUED ON LRS 62 AWGRS DATED SAME*** 04/04/05 ** JOB IN PROGRESS** TIO=650/600/300 ASSIST SLICK-LINE PUMPED 200 BBLS OF DIESEL DOWN TBG TO HELP SSL DH. Page 1 ') ') 5-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/08/05 *** CONT FROM 4-07-05 WSR *** RETRIEVE SHEAR VALVE AND DROPPED DGLV IN STATION #1 FROM STATION #4. SET RK-DCR SHEAR VALVE (3000# SHEAR) IN STATION #1. RESET DGLV IN STATION #4 & PULLED EMPTY CATCHER. NOTIFIED PAD OP WELL LEFT SHUT-IN FOR MITIA. 04/10/05 T/I/O = 1080/660/140. WELL SLlA FLUID LEVEL @ 381 = 1BBL. (PRE MITIA CONVERT TO PWI). 04/16/05 T/I/0=1250/700/120 MIT IA TO 2500 PSI. PASSED ON 2ND TRY (ANN COMM) PUMPED 11.3 BBLS OF DSL TO PRESSURE UP TO 2500 PSI. IA LOST 40 PSI IN 15 MIN AND 10 PSI AFTER SECOND 15 MIN FOR A TOTAL PRESSURE LOSS OF 50 PSI OVER 30 MIN PASS. BLED IA PRESSURE TO STARTING. FINAL WHpIS=1250/900/140. 04/19/05 T/1/0=1200/960/170. TEMP=SI. TBG, lA, & OA FL. (PRE OA FL DEPRESSION). TBG FL @ 22001, IA FL @ 501, OA FL @ SURFACE. 04/26/05 T/I/O = 1060/890/150. OA FL DEPRESS (PRE OA DOWN SQZ). OA FL @ SURFACE. INCREASED OAP TO 1000 PSI. IN 200 PSI. INCREMENTS (W/ AL FROM S-200). OA FL BEGAN TO DEPRESS @ 750 PSI. DEPRESSED OA FL TO 14761 IN 5 HRS, AT WHICH POINT, OAP & OA FL APPEARED TO STABILIZE AT 990 PSI. MONITOR WHP FOR 1 HR. FINAL WHP = 1060/890/980. 04/27/05 T/I/O = 1060/890/850. TEMP = SI. OA FL DEPRESS (PREP FOR OA DOWN SQZ). OA FL @ 17881. OAP DECREASED 130 PSI. TO 850 PSI. FROM YESTERDAY. INCREASED OAP TO 1000 PSI. (W/ AL FROM S-200) IN 10 MINS. MONITOR WHP FOR 30 MINS. OA FL DEPRESSED TO 18661. FINAL WHP = 1060/890/990. 04/30/05 T/I/O = 1060/890/1150. TEMP = SI. BLEED OAP < 500 PSI. (PRE OA DOWN SQZ). OA FL @ 30061? BLED OAP FROM 1150 PSI. TO 480 PSI. IN 1 HR. MONITOR WHP FOR 30 MINS. OA FL @ 28801? (75 BBLS). FINAL WHP = 1060/860/480. ***NOTE*** NO MEASURED DEPTH REFERENCE AVAILABLE TO ATTAIN ACCURATE VELOCITY FOR FLUID LEVEL SURVEY. IA & OA CASING VALVES ARE BOTH 2 - 1/16" A.P.I. 5000 W.P. R-24 TYPE JOINT. F.M.C. MODEL 120 W/ 2" TAPPED BLIND FLANGE INSTALLED. 05/01/05 T/I/0=1050/880/500, TEMP=SI. MONITOR OAP POST BLEED. OAP INCREASED 20 PSI FROM 4-30-05. 05/07/05 T/I/0=1175/900/580 INJECTIVITY TEST ON OA (DOWNSQUEEZE PREP) - PUMPING CRUDE DOWN OA @ 5 BPM TO ESTABLISH INJECTION, OAP CLIMBED TO 2000 PSI (MAX PRESSURE) W/ 64 BBLS AWAY, SD PUMPING, OA LOST APPX 100 PSI IN 10 MIN, BUMPED OAP TO 2000 PSI W/.6 BBLS CRUDE, OAP BEGAN TO FALL OFF, RESTART PUMPING, PUMPED 86 BBLS ADDITIONAL DOWN OA @ 5 BPM 1500 PSI FINAL WHpIS=1240/1260/800 05/15/05 T/I/0=1050/880/0 MIT OA TO 2500 PSI.**(PASSED) ON 3RD TRY** (POST OA DOWNSQUEEZE) PRESSURED UP OA W. 1 BBL CRUDE OA LOST 20 PSI IN 15 MIN AND 10 PSI AFTER SECOND 15 MIN FOR A TOTAL PRESSURE LOSS OF 30 PSI OVER 30 MIN. BLED OAP. FINAL WHP'S=1075/900/0 Page 2 ') ) 5-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/05/05 ***CONTINUED FROM WSR 7-4-05***(PRE INJECTION CONVERSION) RAN 3 1/2 CATCHER SET @ 7571 SLM. PULLED RP GLV, STATION #1 @ 7524 MD. SET DGLV STATION #1 @ 7524 MD. RAN 3 1/2 GS, LATCHED AND PULLED CATCHER @ 7571 SLM. MIT-IA WITRIPLEX TO 1500# PASSED, RDMO. *** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. *** 07/14/05 FIRST WATER INJECTION REPORTED ON 07/14/2005. PRESSURED UP TUBING, BUT NO WATER INJECTED INTO WELL. DATA BEING EVALUATED. BBLS 155 15 98 1162 171.5 227 89 10 14 1941 .5 FLUIDS PUMPED FRESH WATER METHANOL 60/40 METHANOL WATER DIESEL DIESEUXYLENE CRUDE 1% KCL WATER DS CW101 SURFACTANT ARCTIC SET 1 (15.7#) TOTAL Page 3 , TREE = 4-1/16" CrN WELLHEAD = FMC 11" GEN 5 ) . ÄctÜÄTOR'';' .. NA ....._..~...... KB. ELEV = 64.5' èF~ECÐT;" "",m" '''' " '" "36; KOP = 883' ..~a~···A·~~I~~_~~3~~3ä¿à' Datum MD = 8127' ..,...,...,.,..,,,,,...,,,,.....,,,,,,.....,'.. DatumTVD = 5000' SS 8'·216 ( i - I - L ~ ~ 19-5/8" TAM PORT COLLA R 1-1 1006' I 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" 1-1 3571' I I :8: ~ TOP OF 3-1/2" TBG STUB 1-17594' ELM 1 r ~ Minimum ID = 2.800" @ 7617' 3-1/2" HES X NIPPLE, MILLED OUT :8: & ~ J I 3-1/2" TBG, 9.2#, L-80, NSCT, .0087 bpf, ID = 2.992" 1-1 7696' / . ÆRFORA TION SUMMARY REF LOG: SÆRRY -SUN MWD MD ON 12/24/00 A NGLE AT TOP ÆRF: 27 @ 8000' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 4 8000 - 8010 0 07/02/01 2-1/2" 4 8170-8190 0 05/19/01 2-1/8" 4 8320 - 8330 0 04/02/01 I I I r 7" CSG, 29#, L-80 BTC / HYD, ID = 6.182" 1-1 ~ 8698' DATE 12/28/00 08/12/01 OS/22/01 07/13/01 11/23/02 12/02/02 04/08/03 REV BY COMMENTS PGS ORIGINAL COM PLETION CH RWO CS/KAK ÆRFS JLG/KAK ADÆRFS / SAND DUMP DTRfTP GL V C/O JB/TLH SET UPPER ECLP/JET PUMP DRS/TP TV D/MD CORRECTIONS Sj.,)y NOTES: UNDERSIZED 3·1/2" HES X NIP @ 7617' - CT MILLED OUT TO 2.800" ID· 03/31/01. 71' 1-14-1/2" X 3-1/2" XO, ID = 2.992" 1 2098' 1-13-1/2" HES X NIP, ID = 2.813" I GA S LIFT MA NDRELS DEV TYÆ VLV LATCH 49 MMG DMY RK 68 MMG DMY RK 50 MMG DMY RK 45 MMG DMY RKP ST MD TVD 4 2653 2410 3 5154 3420 2 7401 4424 1 7524 4506 PORT DATE o 08/12/01 o 08/12/01 o 08/12/01 o 07/05/05 I 7553' 1-13-1/2" HES X NIP, ID = 2.813" 1 I 7574' 1-17" X 3-1/2" BKR S-3 PKR, ID = 3.875" 1 I 7594' 1-13-1/2" HES X NIP, ID = 2.813" 1 I 7612' 1-1 BTM OF UNIQUE MA CH OV ERSHOT I 7617' 1-13-1/2" HES X NIP, MILLED ID = 2.80" (03/31/01) 1 7639' 1-17" X 3-1/2" BKR S-3 PKR, ID = 3.875" 1 7664' 1-13-1/2" HES X NIP, ID = 2.813" 1 7685' 1-13-1/2" HES X NIP, ID = 2.813" 1 7697' 1-1 WLEG 1 7696' 1-1 ELMD TT LOGGED ON 04/02/01 1 7787' 1-1 TOP OF 20' PUPW/ RA TAG 1 8097' 1-1 TOP OF 20' PUP W/RA TAG 1 8605' 1-1 TOP OF SAND (04/16/02) 1 DATE 07/08/03 1 0/29/03 04/02/05 04/25/05 07/05/05 REV BY COMMENTS JJ/TLP PULL UPPER ECLlPS8JET PUMP BJMcN/TLH SET JET PUMP (10/21/03) WTS/TLH JET PUMP PULLED RMH/TLH GLV C/O (04/08/05) KDClPJC GL V C/O POLA RIS UNIT WELL: S-216 ÆRMIT No: '2001970 API No: 50-029-22989-00 SEC 35, T12N, R12E, 4501' FEL & 4317' FSL BP Exploration (Alaska) (ru ''-~. r ,mß'~: \~, ~~,:.', !"ïp 'V\' ;;1 ifl'\\ il !:J-. ',' ,\, ; i. '!i \\ : ,. i;""" [-~' ~ :U' II r \:! j ¡i '. ~J,~ : ,I ,r?~ i ¡ II f"_ .~ ' ",ø~ 'WI U '--:! ) :r-üIJ~ iF ,f¡0:-'1 !I~:r, .Iß\¡! \, \ ¡ ¡ ! ' ! ,¡1 ~ 'r : . I :' I , L ~ \~,' :_~ lJ~j l_:.7=J ) /~:;-'j '\,~::. CtJ)1 "- r:ï\ð" i/·/:' '~ i l ' '~ i ,j1'\ .J U FRANK H. MURKOWSKI, GOVERNOR AI,ASIIA ORAND GAS CONSERVATION COlWlISSION 333 W. ]TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 ~,éR'" "iQt~ ~¿'~~~i{l'I";¡' /"\" Taylor West Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay S-216 Sundry Number: 305-095 ') ¡:: 20G1 :""f"'A' NNED APR 1., qJ " ~"J Dear Mr. West: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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 holiday or weekend. A person may not appeal a Commission decision to Superio Court unless rehearing has been requested. . fe)/j/ 1{~ ~ " DATED this 11 day of April, 2005 Encl. f)~ <1/5 \L.lc4- 4/7-0(2-<705 ) STATE OF ALASKA r ¿5- RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 9 2005 APPLICATION FOR SUNDRY APPROVAL 1 C" 20 AAC 25.280 Alaska Oil & Gas Cons. ommlsSlon AnchoragE PerforateD Waiver D StimulateD Time Extension D Re-enter Suspended Well D Development..oo- Exploratory D WGA- J Stratigraphic D Service lJ1 9. Well Name and Numb5!r: S-216 / 10. Field/Pool(s): Prudhoe Bay Field / Polaris Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 8612 5463.3 Size MD TVD top 30 26 29 1. Type of Request: Abandon D D D D , ŒJ / D D D D Suspend Operation Shutdown Plug Perforations Perforate New Pool Alter Casing Change Approved Program Repair Well Pull Tubing 2. Operator Name: 3. Address: 4. Current Well Class: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.52 KB 8. Property Designation: ADL-028261 11. Presen1 Total Depth MD (ft): 8712 Casing Total Depth TVD (ft): 5624.5 Length 30.0 26.0 29.0 bottom 110:0 5610.9 2870.8 Tubing Grade: L-80 L-80 L-80 L-80 Conductor Production Surface Perforation Depth MD (ft): 8000 - 8010 8170 - 8190 8320 - 8330 80 8672 3542 20" 91.5# H-40 7" 29# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 4948 - 4956.9 5105 - 5123.8 5248 - 5257.1 bottom top 110 8698 3571 Tubing Size: 2-3/8 " 4.7 # 3-1/2 " 9.3 # 3-1/2 " 9.3 # 4-1/2 " 12.6 # Packers and SSSV MD (ft): Packers and SSSV Type: 3-1/2" Baker S-3 Packer 2-3/8" Patch Packer 2-3/8" Patch Packer 4-1/2" Baker S-3 Perm Packer 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal ŒI Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: 5. Permit to DrillþJumber: 200-1970 ,/ 6. API Number / 50-029-22989-00-00 Plugs (md): None Burst 5750 1490 8160 Tubing MD (ft): 7494 66 7608 24 7639 7494 7520 7569 May 2,2005 Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD Date: WAG 0 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Taylor West 7ájb-¿'¿I~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test æ:] Other: Subsequen 10 ~ 404 · "-- i ('\¡o.~AL ' ~ i ~\ -.. ~ t -1 " \lv'~ Form 10-403 Revised 11/2004 Service Œ] Other D Junk (md): None Collapse 3090 470 7020 7524 7608 7697 66 /' GINJD Abandoned D / WINJŒ] WDSPLD Prepared by Garry Catron 564-4657. Taylor West Contact Title Phone Petroleum Engineer 564-4647 4/18/05 Sundry Number: <]e ~~¿~1 ~ Location Clearance D ¿~~~~I: Date: (1~ D 'l/YD l- XA SUBMIT IN DUPLICATE ) 4-1/16" OW FWC 11"GEN5 NA 64.5' 36' 883' 70 @ 3873' .......... ······8127; . . SÖOO'SS TREE = W8..LHEAD = ';AcrUAfóR";;;'"'' ì<S'.'ELEV;;; BF. ELE\! = KOP= Max Angle = ÖatÙiTïMO:::' DatumTVO"; 8-216 \ J ( ~ L 19-5/8" TA M PORT COLLAR H 1006' 1 9-5/8" CSG, 40#, L-80 BTC, 10 = 8.835" l-i 3571' I :8: Z ITOP OF :>-112' lEG STlB H 7594' ELM I ~ Minimum ID = 2.800" @ 7617' 3-112" HES X NIPPLE, MILLED OUT g ;&. 13-1/2" 1BG, 9.2#, L-80, NSCT, .0087 bpf, 10 = 2.992" 1-1 7696' 1 I . PffiFORATION SUMMARY RB= LOG: SÆRRY -SUN IVWD MD ON 12/24/00 ANGLEATTOP ÆRF: 27 @ 8000' I'-bte: Refer to A'oduction DB for historical perf data SIZE SPF INTffiVAL Opn/Sqz DA TE 2-1/2" 4 8000- 8010 0 07/02/01 2-1/2" 4 8170 - 8190 0 05/19/01 2-1/8" 4 8320 - 8330 0 04/02/01 t 17'CSG,29#,L-80BTC/HYD, 10=6.182" H 8698' ~ DATE 12/28/00 08/12/01 OS/22/01 07/13/01 04/16/02 06/26/02 11/23/02 REV BY COMrvENTS PGS ORIGINAL COMPLETION CH RWO CS/KA K ÆRFS JLGA<AK ADÆRFS / SAND DUrvP CA O/TLH SA f\l) DEPTH DT~KK 00 UPÆR ECLP/JET PUrvP DT~TP GL V C/O DATE 1 2/02/02 04/08/03 07/08/03 10/29/03 04/02/05 REV BY COtvfv1ENTS JBlTLH SET UPÆR ECLP/JET PUrvP CRSffP lV DIM 0 CORRECllONS JJITLP RJLL UFPER EQIPSElJET PUMP BJ~t'-VTLH SET JET PU'v1P (10/21103) WTS/lLH JET RJrvP RJLLED FDLARlS LNIT WELL: 8-216 PffiMrr No: "2001970 AR No: 50-029-22989-00 SEC 35, T12N, R12E, 4501' F8.. & 4317' FSL ) /' SAFETY NOTES: UNDERSIZED 3-1/2" HES X NIP @ 7617' - CT MILLED OUT TO 2.800" IÐ - 03/31/01. 71' H4-1/2" X 3-1/2" XO, 10 = 2.992" 1 /" = H 3-1 /2" HES X NIP, 10 = 2.813" 1 GAS LIFT MA NDRELS DE\! TYÆ VLV LATCH 49 DMY RA 68 DMY RA 50 /'~) RA 45 FLOW J:,~V RA 2098' ~ ST rvD TVD 4 2653 2410 3 5154 3420 2 7401 4424 1 7524 4506 PORT DA TE 08112/01 08112/01 08112/01 11/23/02 1 7553' 1-13-1/2" HES X NIP, 10= 2.813" 1 1 7574' H7" X 3-1/2" BKRS-3 PKR, 10 = 3.875" 1 1 7594' 1-13-1/2" HES X NIP, 10 = 2.813" 1 l 7612' l-i BTM OF UNQUE MACH OVERSHOT 1 {I'/ 1 7617 H3-1/2" HES X NIP, MLLID 10= 2.80" (03/31/01) 7639' 1-17" X 3-1/2" BKR S-3 PKR, 10 = 3.875" 1 7664' 1-13-1/2" HES X NIP, 10 = 2.813" 1 7685' H3-1/2" HES X NIP, 10 = 2.813" 1 7697' l-i WLEG I 7696' 1-1 8..tv1D TT LOGGED ON 04/02/0 1 1 77 87' 1-1 TOPOF 20' PUPW/ RA TAG I 8097' 1-1 TOPOF20'PLPW/RA TAG 1 I I 8605' HTOP OF SAND (04/16/02) 1 BP Exploration (Alaska) ~ ' ) ) bp ... .\1,.,,,. -.....~ ~..~ ~~- -:..~- ......~ ~..... .,.,.".\- ". Memorandum Date: April 18, 2005 From: Taylor West Polaris/Orion Production Engineer Subject: 5-216 OA Down squeeze S-216 is being converted from producer into injector service to support new penta-lateral producer S-213A. The surface piping change from producer to injector is not expected to be completed for several months, so until then, temporary injection is proposed using the existing jet pump supply line by injecting down the IA through a flow sleeve~ and into the formation. Sundry approval has been obtained for the service change. ./ / The MIT-OA on 03/25/05 failed at 3.0 bpm at 1400 psi. In order to assure two barriers of protection while injecting down the lA, an OA down squeeze must be performed, followed by a successful MIT-OA. The OA fluid level is being determined, but at this time, it is assumed that the MIT -OA failed due to an open shoe. /' /' \ · '7 -r tAl (J V,) t:VVV t é-1- ~ . 04 (:zA1 ~ T~¡ ¿~ S() 0 fP!/tJ ~ ~_k- MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ) FRANK H. MURKOWSKI, GOVERNOR AI1A~KA. OIL AM) GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 df)€>--t,1 Victoria Imeh Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe S-216 Sundry Number: 305-026 Dear Ms. Imeh: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior C unless rehearing has been requested. DATED this~y of February, 2005 Encl. SC.AN,\jED FEB 1 5 2005 \tJ6Â- zt11zoo5 OrY 2(f /5 ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Suspend D AlterCasing D RepairWell D Change Approved Program D Pull Tubing D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.52 KB 8. Property Designation: ADL-028261 11. Present Total Depth MD (ft): 8712 Casing Length Conductor Production Surface Perforation Depth MD (ft): 8000 - 8010 8170 - 8190 8320 - 8330 80 8672 3542 20" 91.5# H-40 7" 29# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 4948 - 5123.8 5104.8 - 5257.1 5247.5 - 5257.1 Packers and SSSV Type: 3-1/2" Baker S-3 Packer 2-3/8" Patch Packer 2-3/8" Patch Packer 4-1/2" Baker S-3 Perm Packer 12. Attachments: February 3, 2005 Date: Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: / Development ŒJ Exploratory 0 PerforateD Waiver D StimulateD Time Extension D Re-enter Suspended Well D Convert Inj /~ 5. Permit to Drill ~.. mber: 200-1970 /' top 30 26 29 bottom top 110 8698 3571 Tubing Size: 2-3/8 " 4.7 # 3-1/2 " 9.3 # 4-1/2 " 12.6 # 3-1/2 " 9.3 # Packers and SSSV MD (ft): bottom 110.0 5610.9 2870.8 Tubing Grade: L-80 L-80 L-80 L-80 StratigraphicD Service D 9. Well Name and Number: S-216 ./ 10. Field/Pool(s): Prudhoe Bay Field / Polaris Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 5624.5 8612 5463.3 Size MD TVD Description Summary of Proposal ŒI Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Vi~ia 1-'. eh Signature ~ 30.0 64.5 29.0 13. Well Class after proposed work: Other [!] 6. API Number / 50-029-22989-00-00 Plugs (md): Junk (md): None None Burst Collapse 5750 1490 8160 Tubing MD (ft): 7494 7608 24 66 3090 470 7020 7524 7697 66 7608 7639 7494 7520 7569 ServiceŒl /' Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD WAG D GINJD Contact PluggedD AbandonedD ./ WINJriI WDSPLn 'i#epared by Garry ~on 564-4657. Victoria Imeh Title Phone Production Engineer 564-5233 1/20/05 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test Ii Sundry Number: R .....'- .. -~R S -l!J 2..þ . 1:: F~ \/t:L) Location Clearance D FEB 0 4 2005 P,ugHnte . D BOP TestD Other: fJl ~ c\j ~ .' Subsequen :- ~'IIkJ: . 10 - 404 ' r RI» ß.Á / Approved: /.. (/ ~ ..------- Form 10-403 Revised 11/2004 A, . r""~::"".¡¡<:'~;¡~""I. ~~:~~~~ISSION Date: v,,;;¡;;¡ O( RBDMS BFLFEB 14 2005 0 RIG I N A L SUBMIT IN DUPLICATE ) ) Memorandum From: J. Bixby 1 D. Cismoski GPB Well Ops Team Leaders Victoria Imeh Polaris Production Engineer Date: January 18, 2004 To: PECT: PLSPDWL 16-M PLSPDWL 16-R Jet Pump SBHP/FBHP SURVEY 400 $ 20M Subject: S-216 Convert to Injection. SBHPS lOR: Est. Cost: 1. 5 Pull jet pump & packers, Drift tag, SBHP5, Converting well to injector Replace flow sleeve (GLM #1) MIT-IA Test with WL on location / 2. F Current Status: Max. Deviation: Minimum ID: Last Tag: Last Downhole OP: Latest H25 Value: 51 awaiting conversion to injection 70 deg @ 3873' MD 0" @7494'MD (Jet Pump straddle) 8419' MD @ 07/28/03 SL (89' of rathole) 10/21/03 - Set jet pump straddle (7495' -7524' MD) NI A - offsets < 1 Oppm S-216 was drilled as a producer in 2001. However, its well performance was poor. This may have been due to reservoir and multiple jet pump failures. Production had declined to 24 bopd until it was finally shut in Nov 2003. Future well work options are limited, so it is currently being converted to a water injector. In addition to 5-215i, 5-216i will provide injection support to 5-213A sidetrack. It has /' no well in its % mile radius. It is hoped that the actual surface conversion will be completed by 2Q of this year. Meanwhile, the existing jet pump power fluid system will be utilised for temporary injection. This program requests well preparation to confirm integrity in inner annulus prior to start of temporary injection and in tubing before final surface injection. The intent is to initially inject down the IA until the surface piping is completed. S-216 is ready for injection as soon as the IA test is completed, and appropriate state approval has been obtained. Contacts Victoria Imeh Taylor West Office 564-5233 564-4647 Home 843-278-0257 337-2028 Cell 632-0111 cc: w/a: Well File Victoria Imeh Taylor West Donn Schmohr FEB 0 4 2005 ORIGINAL ) ) Procedure Slickline 1. RU SL. Pull jet pump, straddle packers. 2. Drift & tag TD. 3. Run SBHPS. 4. Pull flow sleeve from GLM #1 @ 7524' MD. 5. Run dummy in GLM#1. Full bore 6. MIT -IA to 2500psi. ./ Slickline 7. Install new flow sleeve in GLM#1. 8. POOH and RDMO. ," --) TREE;: 4-1/16" OW . W8...LI-EAD = FMC 11" GEN 5 }\ctÜÄTÓR = NA. KB. ELEV = "'--64]' ~~....mm,.m. .......... BF. ELBI = 36' ~..........,...~.._._- ._....~.............^,- KOP = 883' Max Angle = 70 @ 3873' 'öafu~mrv1õ = --'--------'-if127, "õãb:ïrñ-nFt)";;'----_.. --S-ÕÕÒïSS 19-518" TA M PORT COLLAR H 1006' 1 9-518" CSG, 40#, L-80 BTC, ID = 8.835" H 3571' TOP OF 3-1/2" 1BG STLB H 7594' ELM Minimu m ID = 0" @ 7494' JET PUMP STRADDLE 13-112" 1BG, 9.2#, L-80, NSCT, .0087 bpf, ID = 2.992" H 7696' I PERFORATION SUMIV1A RY RB= LOG: SÆRRY -SUN rvwD MD ON 12/24/00 ANGLEA TTOP ÆRF: 27 @ 8000' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DAlE 2-1/2" 4 8000 - 8010 0 07/02/01 2-1/2" 4 8170 - 8190 0 05119/01 2-1/8" 4 8320 - 8330 0 04/02/01 17" CSG, 29#, L-80 BTC / HY D, ID = 6.182" H 8698' DAlE 12128100 08112101 05122/01 07/13101 04/16/02 06/26/02 11/23102 REV BY COMMENTS PGS ORIGINAL COMPLETION CH RWO CS/KA K PERFS JLG/KA K A [PERFS / SA t\Ð ruMP CAOffLH SAND DEPTH DTRJ1<K C/O UPPER ECLF¥JEr Pl1v1P DTRlTP GLV 00 DAlE 12/02/02 04/08103 07/08103 10/29/03 ( ~ 5-216 ,/ \ J L 0 ~ 8: :8: / ~ = ~ ~ I z,. 1 . t / I I ) SAFETY NOTES: UNDERSIZED 3-1/2" HES X NIP @ 7617' - CT MILLED OUT TO 2.800" ID -03/31/01. /' I 71' H4-1/2"X3-1/2"XO,ID=2.992" I I 2098' H3-1/Z' HES X NIP, ID = 2.813" GAS LIFT MA NDRELS ST rvD TVD DBI TYÆ VLV LATCH PORT DAlE 4 2653 2410 49 DMY RA 08112/01 3 5154 3420 68 DMY RA 08112/01 ~ 2 7401 4424 50 DMY RA 08112/01 1 7524 4506 45 FLOW FS RA 11/23102 17494'-7524' HWFD JET RJ~ STRADI1E(10121103) 1 7553' H3-1/2" HES X NIP, ID = 2.813" 1 7574' H?'X3-112"BKRS-3PKR,ID=3.875" 1 7594' H3-1/2" HES X NIP, ID= 2.813" 1 1 7612' HBTMOFUNQUEMACHOVERSHOT I 7617 H3-1/2" HES X NIp, MLLID ID= 2.80" (03/31/01) / 7639' H7" X 3-112" BKRS-3 PKR,ID = 3.875" I 7664' H3-1/2" HES X NIP, ID = 2.813" 1 7685' H 3-1/2" HES X NIp, ID = 2.813" 7697' HWLEG 1 7696' H 8...rvD TT LOGGED ON 04/02/01 1 7787' H TOPOF 20' PUPW/ RA TAG I 8097' H TOPOF20'PUPW/RA TAG 1 ZOD5 f~':~ 8605' HTOP OF SAND (04ì16/02) 1 REV BY COMrÆNTS JBffLH SET UFPER EQ.P/JET Pl1v1P DRSlTP TV D'rvD OORRECTIONS JJffLP PULL UPPER ECLPS&'JEr PUMP BJMcNm.H SET JEr Pl1v1P(10/21/03) POLARIS UNIT WELL: 8-216 PERMT No: 2001970 API No: 50-029-22989-00 SEC 35, T12N, R12E, 4501' FEL & 4317' FSL BP Exploration (Alaska) nRIGI[\IAI 1 February 2005 Taylor West Satellite Pad Engineer BP Exploration (Alaska), Inc. Taylor, The review of the USIT log of well S-216, dated 26 December 2000, resulted in the following interpretation. Well 5-216 was logged with the USIT on 26 December 2000 with the objective of evaluating the LiteCrete (12 ppg) cement job. The cemented casing is 7", 29#/ft. The cement evaluation log was ran approximately 14 hours after CIP and then again after approximately 18 hrs CIP. Both a non-pressure pass and a pressure pass (500 psi / whp) were logged. All tool parameter settings appear to be reasonable. Review of the Fluid Properties log plots show selected FP settings to be reasonable. The LiteCrete cement was pumped per job design without issue. Review of the drilling reports indicate / good cement placement. As per API Standard, the LiteCrete cement in place was tested and designed to cure at anticipated bottomhole temperature. Any lower temperatures (as will be encountered uphole) will effect curing times. In other words, the LiteCrete uphole is anticipated to require a longer curing time before reaching its ultimate compressive strength. Past learnings have shown that evaluation of LiteCrete cement at less than 24-36 hrs of cure time can produce pessimistic results. At 14 hrs after CIP, the US IT log indicates good cement up to approximately 7700' md./" As the cement uphole sets, it is presumed that there will be adequate cement further up the wellbore as time after CIP increases. At 18 hrs after CIP, a second pass was logged, and it appears to indicate cement further uphole to approximately 7600' md. This /' appears to indicate correlation that the cement is curing uphole, but at a slower rate than at BHT, as would expected. Based upon the Cement job data, it's then reasonable to assume cement placement & the true cßment top is further uphole than was observed on the 18 hrs after CIP USIT pass. /' Regards, Gary Elmore BP DESC Engineer - Schlumberger REW C) l_- ') ) TRæ... 4-1/16" aN W8.U-EA'D = Frv'C 11" GEN 5 'ACTUATOR = Nt\. KB. ELEV = 64.5' BF. ELBI = 36' KOP = 883' Max Angle = 70 @ 3873' OatumMO= 8127' OatumTVD= 5000' SS 8-216 SAÆTYNOTES: UNDERSIZB> 3-1/2" HES X NIP @ 7617' -CTMLLB> OUTT02.800"1) -03/31/01. 8: ~ 71' 114-112' X 3-112" XO, 10= 2.992" I 2098' H3-1/2" HES XNIP,IO= 2.813" I GAS LIFT MA I'ÐRELS ST MJ TVO OBI TYFE VLV. LATCH PORT DAlE 4 2653 2410 49 OW Rð. 08112101 3 5154 3420 68 OW Rð. 08112101 ~ 2 7401 4424 50 OW Rð. 08112101 1 7524 4506 45 FLOW FS Rð. 11/23/02 17494'-7524' HWFD JET RJfvP STRAOa..E(10121AJ3) I I 7553' H3-1/2" HES X NIp, 10= 2.813" I I 7574' 1~7"X3-112"BKRS-3PKR,10=3.875" 1 I 7594' H3-1/2" HES XNIP,IO= 2.813" 1 -~ I 7612' HBTMOFUNQUEMACHOVERSHOT 1 I 761 T H 3-1/2" HES X NIP, MLLED 10 = 2.80" (03/31/01) 19-518" TAM PORT COLLAR H 1006' I ~ I = L I 9-518" CSG, 40#, L-80 BTC, 10 = 8.835" H 3571' ~ q I TOP OF 3-1/2' TBG STLB H7594' ELM I ~ . . Minimu m ID = 0" @ 7494' JET PUMP STRADDLE 8 &. 7639' H7"X3-112"BKRS-3PKR,10=3.875" 1 7664' H3-1/2" HESXNIp, 10=2.813" I 13-112" TBG, 9.2#, L-80, NSCT, .0087 bpf, 10= 2.992" H 7696' I 1 7685' H3-1/2' HES X NIP, 10= 2.813" 1 7697' HWLEG I 7696' H 8.MJ TT LOGGED ON 04l02AJ1 I . 7787' H TOPOF 20' PUPWI RA TAG I PERFORATION SUMI.1A RY RB= LOG: SFERRY -SUN MlVO MO ON 12124AJO AI\GLEA TTOP FERF: 27 @ 8000' I'Ibte: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz DA lE 2-1/2" 4 8000- 8010 0 07/02101 2-112" 4 8170- 8190 0 05119/01 2-1/8" 4 8320 - 8330 0 04102101 t 8097' K TOP OF 20' PlP W/RA TAG I I I 8605' HTOP OF SAND (04/16/02) I 17" CSG, 29#, L-80 BTC 1 HYO, 10= 6.182" H 8698' ~ DAlE 12J28100 08l12J01 05122101 07113/01 04116'02 06'26'02 11/23/02 REV BY COMM8'ITS PGS ORIGINAL COMPLETION CH RWO CS/KAK PERFS JLG/KA K AJ:FERFS 1 SA I'Ð aJMP CAOIfLH SAND DEPTH DTRn<K C/O lPPER ECL~JET" PLMP DTRITP GLV 00 DAlE 12102102 04108103 07108103 1 CY29103 REV BY COMf.ÆNìS JBIfLH SET UFPER ECl.P/JET PLMP ORSITP TVD'MJ OORR:CTIONS JJIfLP PULL lPPER ECLPSC'JET" PLMP BJkNI1LH SET JET" PLMP(10121/03) POLA RIS l-"'IT W8.L: $0216 PERm No: 2001970 API No: 50-029-22989-00 see 35, T12N, R12E. 4501' ÆL & 4317' FSL BP Exploration (Alas ka) f"":. r~\ t. l. ¡ I.'. ,,/ I "" 1\ ¡ S-216~~a-TopSch~derBlu~~pNaPen~~ion~in~ ';I' -- ~ " ~ / 612.000 614.000 s- 118 ~~ -17 - 25 I S-116 . -4889 S-215 . -4871 í~ '\ /" S-216 . -4IS5O ....... S-213A Multi-Lateral TW-C . -4855 616.000 618.000 . ~1 . -4882 . 5-48Þ4 . -4905 - 5.980.000 - 5.978.000 S-07 . -4927 5.976.000 S-18 . -4889 % Mile Radius - 5.974.000 , " ~ --' 5.972.000 620.000 622.000 ~ ~ BPEXPLORATION DailyOþerationsReport Event: DRILL +COMPLETE Field: PRUDHOE BAY Well Type: DEVELOPMENT Rig: NABORS 9ES ges Current Well Status Casing Size: 7.000 (in.) Costs in: USD Casing (MD): 8,698.39 (ft) AFE No: 5M1010 Next Casing Size: 7.000 (in) AFE Cost: 2,228,000 Next Casing (MD): 8,626.0 (ft) Daily Mud: Next Casing (TVD):5,572.0 (ft) Cum. Mud: 100,271 Liner (MD): Daily Well: 112,911 Liner Top (MD): Cum. Well: 1,834,504 #' ) Operator: BP EXPLORATION Well: S-216 Depth MD: Est. TVD: Progress: Auth Depth: Hole Size: DOUDFS/Target: 17.501/16.00 Geologist: David Stearns Engineer: Phil Smith Supervisor: Ferguson/Decker 8,712.0 (ft) 5,560.0 (ft) (ft) 8,656.0 (ft) ) Report: 18 Date: 12/25/2000 Rig Accept: 12:00 12/8/2000 Rig Release: Spud Date: 12/9/2000 Elev Ref: SEA LEVEL KB Elev: 64.50 (ft) Program: Tot. Personnel: 29 Cost Ahead USD, Days Ahead -1.00 Current Status: Testing BOPE. . .. / 24hr Summary: C/o rams to 7", Run csg & cement. 24hr Forecast: Test BOPE, run SWS US IT log, Test Csg, Freeze protect ann., Comments: NO ACCIDENTS, NO INCIDENTS, NO SPILLS Weather: Temp: - 7 deg., Wind: 25 mph. NE, CF: - 54 deg Last Accum. Drill (D4): 12/18/2000 Last Spill Drill: 12/25/2000 Regulatory Agency Insp: N Non-compliance Issued: N KICK WHILE DRILL (D2)12/19/2000 STRIPPING: 12/18/2000 Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Stroke Rate PressureO Days Since Last DAFWC: 767 Last Csg Press. Test: 12/25/2000 Last BOP Press. Test: 12/18/2000 Next BOP Press. Test: 12/25/2000 Last Divertor Drill (D3): 11/25/2000 No. Stop Cards: FIRE: 12/22/2000 FIT TVD 2,870.0 (ft) FIT EMW 12.61 (ppg) MMSSP 0 (psi) Test Pressure: 315 (psi) Kick Tolerance: 12.61 (ppg) Kick Volume: 55.5 (bbl) ROP Daily ROP Cum. WOB (min) WOB (max) RPM at Surface RPM at Bottom Torq. on Bottom Torq. off Bottom Rotating Weight Pick Up Wt. Slack Off Wt. Circ. Rate Riser Circ. Rate Hole Circ. Off Bottom Circ. On Bottom Type LSND 10 sec gels TimelLoc 18:00/PIT 10 min gels Depth 8,713.0 (ft) Fluid Loss Temp 75 (OF) HTHP Temp Density 10.60 (ppg) HTHP WL Funnel Visco 55 (s/qt) Cake ECD (ppg) MBT PV (cp) Lime YP (lb/100ft2) PM pH From-To Hrs Phase Task Activity hh:mm (hr) 00:00-00:30 0.50 PROD1 DRILL WEAR 00:30-02:00 1.50 PROD1! CASE RU 02:00-02:30 0.50 PROD1¡ CASE RU I I 02:30-04:30 12.00 PROD1 CASE TBHNDL I FEB 0 4 2005 HSE & Well Control All Free Days: 137 8/10/2000 ~..I.."'I..,lf'!i O. ,I ,",.:, (~~ç,,¡ '.r¡; I.,c" ..,.}.: ,-: "'.h.."A'~~ I': -'. ........ ' J:~ci;;f"lJ,,:: Last H2S Dn11:' - - - . Last Trip Drill (D1): Last Safety Meeting: Last Envir. Incident: f- .,";,\ ':';""12/21/2000 12/23/2000 12/25/2000 OperatioI'Ull..f'ararneters Rotating Hours (hr) Cum. Bit Hours Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 0 0 0 0 Ann. Vel. Riser (ftImin) Ann. Vel. DC (ftImin) Ann. Vel. DP (ftImin) Drilling Fluid (lb/10OO2) Ca (lb/10OO2) K+ 5.8 (ccl30min) CaCI2 (OF) NaCI (ccl30min) CI- 2 (/32") Sand (ppb) HGS (ppb) LGS (mL) Pf/Mf (mg/L) (mg/L) (%) (%) (mg/L) (%) (ppb) (ppb) 1 (mUmL) ES Solids Oil Water Oil/Water Daily Cuttings Cum. Cuttings Lost Downhole Lost Surface (mV) (%) (%) (%) 1 (bbl) (bbl) (bbl) (bbl) Operations Summary Code NPT Operation P Pull wear bushing. P Change top rams to 7" and test bonnets to 3500 psi. P Pick up 7" landing joint and make dummy run P Rig up to run 7" casing. PJSM Printed: 12/2612000 5:35:11 AM ) ) "" From-To Hrs Phase Task hh:mm (hr) 04:30-10:00 5.50 PROD1 CASE TBHNDL BP EXPLORATION Daily Operations. Report Event: DRILL +COMPLETE Field: PRUDHOE BAY Well Type: DEVELOPMENT Rig: NABORS 9ES ges Operations Summary Code NPT Page 2 of 2 Report: 18 Date: 12/25/2000 Operator: BP EXPLORATION Well: S-216 Activity Operation P Run 7" 29 # -80 BTC casing, check floats, install two pup joints with RA tags and RIH to 9 5/8" casing shoe. Circulate 1.5 times casing volume. 10:00-10:30 0.50 PROD1 CASE CIR P 10:30-17:00 6.50 PROD1 CASE TBHNDL 17:00-20:00 3.00 PROD1 CEMT CIR 20:00-22:30 2.50 PROD1 CEMT CMT P 22:30-00:00 1.50 PROD1 CEMT CMT P Run 100 jts BTC, pick up XO to HYD 563 thread. RUH with 7" 29 # L-80 HYD 563 to 8698' Circ. & condo mud for cement Reciprocate casing. Hold PJSM with rig crew, cementers and Peak drivers Pump 5 bbls water, test lines to 3500psi. Pump 5 more bbls followed by 20 bbls CW 100 Chemical Wash then 5~bbls MudPush spacer. Drop bottom plug. Mix and pump 135 bbls.,12.0ppg.,CemCRETE Cement Displace with 320bbls. seawater. Reciprocated casing until 240 bbls displacement pumped. Bump plug w/ 3500 psi. Hold for 5 minutes. Floats OK RID Dowell cmt head and equip. UD landing Jt P P 06:00 Update: Change bales and elevators. Run Packoff, RILDS, Test to 5000 psi, C/O top rams to 31/2" X6". Run test plug, Test BOPE. . Remarks Item Mud Log Information I Form. Top MD. 0 0 I Bkgmd Gas Form. Top TVD. 0 0 Conn. Gas Materials rConsurnption I Units I Usage I On Hand I Item GAL 1832 5256 Personnel No. Hours Company 2 24.00 NABORS 2 (ppm) I Trip Gas (ppm) Pore. Press (ppm) (ppg) Formation UGNU Lithology Units I Usage I On Hand DIESEL Company BP AMOCO BAROID No. Hours Company 23 24.00 SPERRY-SUN No. Hours 2 Phase PRE PROD1 SURF TOTALS Prod % Total 19.00 100.0% 180.75 100.0% 118.75 53.9% 318.50 75.8% Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total Total Cost USD CT OD (in) CT ID (in) Window Top (ft) 101.50 46.1% 101.50 24.2% 0.00 0.0% 0.00 0.0% 0.00 0.0% Window I Coiled Tubing Drilling CT Daily Ftg (ft) CT Strength (psi) CT Cum Ftg (ft) CT Length (ft) Window Desc: 0.00 0.0% Total Hours 19.00 180.75 220.25 420.00 0.00 Mud Sys Ftg (ft) Printed: 12/2612000 5:35:11 AM l \' Operator: BP EXPLORATION Well: S-216 Depth MD: Est. TVD: Progress: Auth Depth: Hole Size: DOUDFSlTarget: 18.501/16.00 Geologist: Engineer: Supervisor: 8,712.0 (ft) 5,560.0 (ft) (ft) 8,656.0 (ft) Phil Smith Ferguson/Williams BPEXPI...ORATION DailyQp'r;:1tiQI'1~.'Rep~rt Event: DRILL +COMPLETE Field: PRUDHOE BAY Well Type: DEVELOPMENT Rig: NABORS 9ES ges Current Well Status Casing Size: 7.000 (in.) Costs in: USD Casing (MD): 8,698.39 (ft) AFE No: 5M1010 Next Casing Size: 7.000 (in) AFE Cost: 2,228,000 Next Casing (MD): 8,626.0 (ft) Daily Mud: 740 Next Casing (TVD):5,572.0 (ft) Cum. Mud: 146,730 Liner (MD): Daily Well: 104,682 Liner Top (MD): Cum. Well: 1,935,064 ) ) PâgEr1()f2 Report: 19 Date: 12/26/2000 Rig Accept: 12:00 12/8/2000 Rig Release: Spud Date: 12/9/2000 Elev Ref: SEA LEVEL KB Elev: 64.50 (ft) Program: Tot. Personnel: 28 Cost Ahead 168,000 USD, Days Ahead -5.00 Current Status: Running 31/2" production tubing. 24hr Summary: Install 7" pack-off. Run US IT log. RIU & run 3.5" prod tbg. 24hr Forecast: Finish running 3.5" tbg. N/D BOP. N/U Tree. Comments: NO ACCIDENTS, NO INCIDENTS, NO SPILLS Weather: Temp: - 12deg., Wind: 11 mph. NE, CF: - 38 deg Days Since Last DAFWC: 768 Last Csg Press. Test: 12/26/2000 Last BOP Press. Test: 12/26/2000 Next BOP Press. Test: 1/2/2001 Last Divertor Drill (D3): 11/25/2000 No. Stop Cards: FIRE: WELL KILL (D5): 12/22/2000 12/26/2000 FIT TVD 2,870.0 (ft) FIT EMW 12.61 (ppg) MAASSP 0 (psi) Test Pressure: 315 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) ROP Daily ROP Cum. WOB (min) WOB (max) RPM at Surface RPM at Bottom Torq. on Bottom Torq. off Bottom Type Time/Loc Depth Temp Density Funnel Visco ECD PV YP pH LSND OO:OO/PIT 8,713.0 (ft) 75 (OF) 10.60 (ppg) 55 (s/qt) (ppg) (cp) (lb/10OO2) HSE&WeUContrOI All Free Days: 13EAh~T~rc\ Last Envir. Incident: 8/10/2000 fI"'~">r'?"r'iR! Last Trip 43Hit(tŸ1):Ó'" Last Safety Meeting: Last Accum. Drill (D4): 12/26/2000 Last Spill Drill: 12/25/2000 Regulatory Agency Insp: N KICK WHILE DRILL (D2)12/19/2000 FIB 0 4 Z005 12/23/2000 12/26/2000 Non-compliance Issued: N STRIPPING: 12/18/2000 Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Stroke Rate PressureO Rotating Weight Pick Up Wt. Slack Off Wt. Circ. Rate Riser Circ. Rate Hole Circ. Off Bottom Circ. On Bottom Operational Parameters Rotating Hours (hr) Cum. Bit Hours From-To Hrs Phase Task Activity hh:mm (hr) 00:00-00:30 0.50 PROD1 CEMT¡ CMT 00:30-01 :30 1.00 PROD1 WHSU PRESS 01 :30-02:30 1.00 PROD1 BOPSU PRESS 02:30-09:00 6.50 PROD1BOPSU PRESS I i Ann. Vel. Riser (ftImin) Ann. Vel. DC (ftImin) Ann. Vel. DP (ftImin) 10 sec gels 10 min gels Fluid Loss HTHP Temp HTHP WL Cake MBT Lime PM DriUingFluid (lb/100ft2) Ca (lb/10OO2) K+ (ccl30min) CaCI2 eF) NaCI (cc/30min) CI- (/32") Sand (ppb) HGS (ppb) LGS (mL) Pf/Mf Operations Summary Code NPT P Clear rig floor and clean up. Pump Status - and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 0 0 0 0 (mg/L) (mg/L) (0/0) (0/0) (mg/L) (0/0) (ppb) (ppb) / (mUmL) (mV) (0/0) (0/0) (0/0) / (bbl) (bbl) (bbl) (bbl) ES Solids Oil Water Oil/Water Daily Cuttings Cum. Cuttings Lost Downhole Lost Surface Operation P Install FMC 7" packing. Run in lock down screws. Test pack off to 5000 psi. OK Change rams to 3 1/2" X 6". Test BOP 250 psi low and 3500 psi high. AOGCC rep. John Spalding / P P Printed: 12/2712000 6:12:16 AM Operator: BP EXPLORATION Well: S-216 ) '\ ) " , '.1 BP.EXPLOAATION Daily Operations . Report Event: DRILL +COMPLETE Field: PRUDHOE BAY Well Type: DEVELOPMENT Rig: NABORS 9ES ges OperationsSÜmmary Code NPT Page.2 of 2 Report: 19 Date: 12/26/2000 Activity Operation From-To Hrs Phase Task hh:mm (hr) 02:30-09:00 6.50 PROD1 BOPSU PRESS P waived witnessing test. P Service rig. 09:30-19:00 9.50 PROD1 EVAL 09:00-09:30 0.50 PROD1 DRILL RIGSER LOG P Rig up Schlumberger logging unit. PJSM. Run US IT cement evaluation log from 8605' to 3450'. Run repeat log from 8600' to 8300' & 7800' to 7000'. Apply 500 psi & log from 7800' to 7000'. POOH with e-line & RID Schlumberger. RlU & pressure test 7" casing to 3500 psi for 30 minutes. Test was API. Bullhead 100 bbl of 10.6 ppg mud down 7" x 95/8" casing annulus. Stage rate up to 4 bpm with 800 psi final injection pressure ( formation broke down with 400 psi @ 1 bpm ). Line up Hot Oil & freeze protect 7" x 9 5/8" annulus with 60 bbl of crude oil. Pump rate 2.2 bpm with 1875 psi. Stop pumping. Had 850 psi back pressure. Secure annulus valve on wellhead. RID Hot Oil truck. Held PJSM with rig crews prior to running 3.5" production tubing. Pull wear bushing. Run 3.5" 9.2# L-80 NSCT Production tubing ( 2176' @ midnight ). 19:00-20:00 1.00 PROD1 CASE PRESS P 20:00-21 :30 1.50 PROD1 CASE FREEZE P 21 :30-22:00 0.50 COMP RUNCO SAFETY P 22:00-00:00 2.00 COMP RUNCO CMPSTG 06:00 Update: Run 31/2" production tubing Formation UGNU Lithology Item DIESEL Company BP AMOCO BAROID Phase COMP PRE PROD1 SURF TOTALS Prod % Total 2.50 100.0% 19.00 100.0% 202.25 100.0% 118.75 53.9% 342.50 77.1 % CT OD (in) CT ID (in) Window Top (ft) P Remarks Mud Loa Information I Form. Top MD. 0 0 I Bkgmd Gas Form. Top TVD. 0 0 Conn. Gas MaterialsI Consumption I Units I Usage I On Hand I Item GAL 1728 3528 Personnel No. Hours Company 2 24.00 NABORS 2 (ppm) ¡Trip Gas (ppm) Pore. Press (ppm) (ppg) Units I Usage I On Hand No. Hours 1 No. Hours Company 23 24.00 SPERRY-SUN Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total Total Hours 2.50 19.00 202.25 220.25 444.00 Total Cost USD 101.50 46.1% 101.50 22.9% 0.00 0.0% 0.00 0.0% 0.00 0.0% Window I Coiled Tubing Drilling CT Daily Ftg (ft) CT Strength (psi) CT Cum Ftg (ft) CT Length (ft) Window Desc: 0.00 0.0% 0.00 Mud Sys Ftg (ft) Printed: 12/2712000 6:12:16 AM Cement Integrity Details on Proposed Injector 8-216 Cement height above Na Calculated cement top (ft md) sand (ft) (7962' md) Cement pumped 30% over 30% over Bumped Full Pressure Well Field Current Service (bbls) Gauge Hole G~e Gauge Hole Ga,~ plug Reciprocated Returns Tested Bond Log Oil Producer S-216 Polaris Hydraulic Pump 135 3766 4905 4196 3057 Y Y Y Y Y ~J ~ f'.) c::;¡ c::J Uì . ) .) MECHANICAL INTEGRITY REPORT' ....... :: PUD D.-".'rE: IZ/oq / ZoOO OPER & FIELD BP. í)ßLL PrJ/¡:¿.ir¡Ç. k'"ELL NUMBER ~.- lilt> ?lG RELEJ._S'::: . Casing: 7 Ii TD: .1J7/l .HD.. Sfo 2 S TVD; ?BTD: ffolL MD 5'4"'5 TVD Shoe :8109 f HD 'SlPll TVD i DV: MD .Tvu 7~ !:;.LL DATA :..-:":ìe~: Shoe: HD TVD i :OP: t.m 7~¡D - . . . _.~o:!...:;g: ./ H '3,..' 2.. Packer 7G, ~.c/HD T'{D ¡Set: ë.t ::ole Size u '/ Sf '(J" L anå Perfs -'¡ooo to ~~.30 ::-SCèIANIC:'-L INTEGRITY - PART 11 Annulus Press Test: ~p 1 15 min 3 0 min COITmlents: ¡\llIT r(.Õ~~ J, ,..,- .' ~CHÞ_1\[ICÞ~ INTEGRITY - PART 42 Cement: Volumes :'. .Amt. Liner ; Csg 13S bb/~ DV C¡¡¡t 701 to cover Der::s ~S bbl ç, ~ C-t9-JJ2(' ~~, Theoretical TOC 4lðO' w I ~o % -f¥.C.Rsr;. Cement Bond Log (Yes or No) 'Lf ; In AOGCC File' .,,/" CEL Evaluation, ::one above perfs U ÇIT JiVt'~d 1 2-/2 "11t?O 0 j ;-U~'" A/ l.g h If ç. &c-ç-f e.y- Cr t~ ""L We. a.cLe7 ~( h () ""~:Î ^' 400' a.bov R piJ;j Produc.tion Log: Type' tJ!A-- Evaluation . i ¡ t COÑdLUSIONS: , .- .. ?art fl: MIl V'l't uA. ~J ?ar<;:, :2: U ~I~ ~J ~t \JO{ pld ,~dl~ie ~ckÔ~ ~+ bQ~, A-r ph7ilecl 2- {7/ z.oo S W6*~ . . -... -- Permit to Drill 2001970 MD 8712 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. PRUDHOE BAY UN POL S-2t6 Operator BP EXPLORATION (ALASKA) INC 5624 /' Completion Dat 12/22/2000 /~ Completion Statu l-OIL Current Status l-OIL APl No. 50-029-22989-00-00 UlC N .. REQUIRED INFORMATION Mud Log N.__~o Sample No Directional Survey Nc) DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No ~/eeak Detect Log 2 FINAL i~ N/EU/DEN/GR 2 FINAL r_.,,l:~D NEU/DEN/DGR 2 FINAL ~al Survey FINAL MWD L L L L L ~"~'~- D R R L L L L D D L L L R R ED D j Rpt k~-~Verification (data taken from Logs Portion of Master Well Data Maint Directional Survey FINAL ~~-nal Survey FINAL 5 on Static 1 FINAL emp 10235~ FINAL ~D~DuaI GR/RES/ROP 2 FINAL I GPJRES 2 FINAL ~ Survey MWD Interval Start Stop 3571 0 7650 0 8713 0 8713 86OO OH ! Dataset CH Received Number Comments CH 9/14/2001 0-7650 BL, Sepia- oh 8/20/2001 0-8713 BL, Sepia oh 8/20/2001 0-8713 BL, Sepia 2/21/2001 MWD Dir Survey Digital Data 2/21/2001 Dir Survey Paper Copy 2/21/2001 Dir Survey Digital Data CH 2/26/2001 3571-8600 Color Print FINAL 100 0 0 0 0 404 404 8320 ch 4/20/2001 7698 oh 7/16/2001 8713 oh 8/20/2001 8713 oh 8/20/2001 7698 Open 7/18/2001 2/21/2001 8684 C~/1/2001 8684 Case 6/1/2001 100-8320 BL, Sepia )./~//:,F ~J 10235(~0-7698 Digital Data 0-8713 BL, Sepia 74 3 BL, Sepia 10235c,,,'0-7698 MWD Dir Survey Paper 11196~ Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 111612003 Permit to Drill 2001970 Well Name/No. PRUDHOE BAY UN POL S-216 Operator BP EXPLORATION (ALASKA) INC MD 8712 TVD 5624 Well Cored? Y ~) Chips Received? ~ Analysis ~ R~.c~.iv~.d? Completion Dat 12/22/2000 Completion Statu 1-OIL Current Status Daily History Received? (~ N Formation Tops (~/N APl No. 50-029-22989-00-00 1-OIL UIC N Comments: Compliance Reviewed By: Date: _. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ RESIN COAT PERFS/JET PUMP Pu, tubing_ Alter casing_ Repair well_ Other_X RESIN COAT 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development mX Exploratorym Stratigraphicm Service_ 4. Location of well at surface 963' FNL, 4500' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 771' FNL, 665' FEL, Sec. 03, T11N, R12E, UM At effective depth 965' FNL, 715' FEL, Sec. 03, T11N, R12E, UM At total depth 991' FNL, 723' FEL, Sec. 03, T11N, R12E, UM (asp's 618930, 5980520) (asp's 617573, 5975410) (asp°s 617527, 5975216) (asp°s 617519, 5975190) 12. Present well condition summary Total depth: measured true vertical 8712 feet Plugs (measured) 5624 feet Effective depth: measured true vertical 8605 feet Junk (measured) 5521 feet Casing Length Conductor 110' Surface 3542' Production 8672' 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-216 9. Permit number / approval number 200-197 / 302-300 10. APl number 50-029-22989-00 11. Field / Pool Prudhoe Bay Field / Polaris Pool Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arcticset (Aprox) 139' 139' 9-5/8" 479 sx Arcticset Lite III, 3571' 2871' 421 sx 'G'. 7" 207 sx Class 'G' 8698' 5611' Perforation depth: measured Open Perforations 8000'-8010', 8170'-8190', 8320'-8330' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) RECEIVED true vertical Open Perforations 4948'-4957', 5105'-5124', 5248'-5257' 4-1/2" xo 3-1/2" e 71'. 3-1/2", 9.2#, L-SO NSCT TBG e 7639' MD.DEC 1 2002 3-1/2", 9.2#, L-80, Tubing Tail @ 7697' MD. A~I~I 0il & Gas Cons. Commission TWO --- 7" x 3-1/2" Baker S-3 Packers @ 7574' & 7639' MD. ,AllC[lorag8 3-1/2" HES 'X' Nipple @ 2098'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Shut-In Subsequent to operation 12/08/2002 OiI-Bbl Representative Daily Avera.qe Production or Iniection Data Gas-Mcf Water-Bbl 103 27 1410 Casing Pressure Tubing Pressure 312 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil MX Gas M Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~.~ ~~:~~e,~f.~ Title: Technical Assistant DeWayne R. Sc ~rr~I~ Date December 08, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88. SUBMIT IN DUPLICATE 10/29/2002 11/07/2002 11/07/2002 11/08/2002 11/09/2002 11/10/2002 11/11/2002 11/13/2002 11/14/2002 11/15/2002 11/16/2002 11/24/2002 11/24/2002 11/25/2002 12/O8/2002 1 O/29/O2 11/07/02 11/07/02 11/08/02 11/09/02 11/10/02 S-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ]ET PUMP / ]ET PUMP / ]ET PUMP / ]ET PUMP / lET PUMP / ]ET PUMP / ]ET PUMP / ]ET PUMP / ]ET PUMP / ]ET PUMP / ]ET PUMP / ]ET PUMP / ]ET PUMP / ESP: GAS LIFT--TO DUMMY VALVES ESP: AC-FLUID LEVEL ESP: PARAFFIN / ASPHALTENE REMOVAL ESP: DRIFT/TAG; GAS LIFT--TO DUMMY VALVES; MIT-IA ESP: FILL CLEAN OUT W/N2; SAND PLUG ESP ESP ESP ESP ESP ESP ESP ESP : FILL CLEAN OUT W/N;Z; SAND PLUG : MECHANICAL ZONE MODIFICATION : FILL CLEAN OUT W/N;~ : FILL CLEAN OUT W/N;Z; UNDERREAM : UNDERREAM : FILL CLEAN OUT W/N;Z : DRIFT/FAG; GAS LIFT--FOR RATE : BRUSH / BROACH ]ET PUMP / ESP: DRIFT/TAG TESTEVENT --- BOPD: 103, BWPD: 1,410, MCFPD: 27, AL Rate: 0 EVENT SUMMARY DRIFTW/2.69" CENT. TO 1400'. SAMPLE OF THICK TAR. <<< NOTIFY PAD OPERATOR >>> T/I/O = SI/VAC/200 IA FL (FOR WIRELINE) IA FL @ 180' (??) HARD TO GET IA FL, IA ON A STRONG VACUUM. CTU #9 HOT TUBING WASH. RIH JETTING TUBING WITH HOT CRUDE. COME DOWN ON PUMP AT 7300' CTMD AND RIH, DRY TAGGED FILL @ 7888' CTMD. POOH JETTING JEWELRY & GLM's AT 80%. WELL FREEZE PROTECTED TO 2500' WITH MEOH. SET 3-1/2 CATCHER SUB. PULLED FLOW SLEEVE FROM STATION #1. SET DGLV IN STATION #1, PT IA TO 2000# --- GOOD TEST. PULLED 3-1/2" CATCHER SUB. <<< LEFT WELL SHUT-IN >>> CTU #9, N2 FCO, SAND BACK. RIH WITH 2.25 JSN. CLEANED OUT FORMATION SAND FROM 7920' CTMD TO 8338' CTMD. POOH. RIH WITH 2.25" SAND DUMP NOZZLE. TAGGED TD @ 8347' CTMD. PREP TO SAND BACK. LAID IN 6500# OF 20/40 RIVER SAND FOR AN EST. TOP AT 8050'. RIH AND TAGGED TD AT FCC DEPTH OF 8347' CTMD. ALL SAND LOST TO FORMATION. CONSULT WITH TOWN. ATTEMPT SECOND SANDBACK. LAY IN AN ADDITIONAL 6500# OF 20/40 RIVER SAND. TAGGED SAND TOP AT 7993' AFTER ALLOWING SAND TO SETTLE. RIH WITH 2.25" JSN. CLEANED OUT SAND TO 8060' CTMD, CHASED TO SURFACE. RBIH WITH 2.25" JSN. CHECK INJECTIVITY, 0.25 BPM @ 1400 PSIG. BEGIN TREATMENT OF PERF INTERVAL 8000' TO 8010'. Page 1 11/11/02 11/13/02 11/14/02 11/15/02 11/16/02 11/24/02 S-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS CONTINUED TREATMENT OF PERF INTERVAL 8000' TO 8010'. RECIPROCATED THE FOLLOWING TREATMENT ACROSS PERFS; 12 BBLS - 7.5% HCL ACID, 40 BBLS - 2% KCL FLUSH, 38 BBLS - SOLVENT, 36 BBLS - PREFLUSH, 36 BBLS - RESIN, 122 BBLS - 2% KCL FLUSH. SHUT-DOWN. POOH. FP WELL TO 3000' AND THE FLOW LINE WITH 60/40 METHANOL. <<< JOB COMPLETE >>> N2 FCC. RIH WITH 2.5" DJ NOZZLE TO SAND TOP AT 8057' CTMD, UNABLE TO JET THROUGH THE RESIN INTERFACE. POOH. RIH WITH 2-5/8" BAKER DB UNDERREAMER WITH 6" BLADES, SAT DOWN GOING IN HOLE AT #3 GLM, (5173" CTMD). POOH. REMOVED THE HYD CENTRALIZER FROM MHA. RBIH WITH SAME UNDERREAMER, TAGGED SAND TOP @ 8059' CTMD. UNDERREAMED ON SAND/RESIN INTERFACE. VERY HARD UNDERREAMING. UNDERREAMING AT 8063.8" CTMD. UNDERREAMED TO 8066' CTMD. 3' OF PROGRESS IN 6.5 HRS UNDERREAMING. POOH TO INSPECT TOOLS. UNDERREAMER WAS IN GOOD CONDITION WITH NO EXCESSIVE WEAR ON BLADES. CUT 120' COIL. CHANGED OUT MILL ON THE UNDERREAMER TO A 2.70" 3 BLADE JUNK MILL & RIH WITH SAME MHA. TAGGED SAND TOP AT 8065". UNDERREAMED TO 8068' AND APPEARED TO HAVE BROKEN THROUGH, CONTINUED TO 8070'. POOH. RIH WITH 2" JSN. TAGGED SAND TOP AT 8069' CTMD, STILL UNABLE TO JET OUT SAND. POOH. RBIH WITH BAKER 'DB' UNDERREAMER. TAGGED BOTTOM AT 8070" CTMD. CONTINUED UNDERREAMING. UNDERREAMING AT 8071" CTMD, 3 HRS WITH SIGNIFICANT HEADWAY. POOH TO INSPECT TOOLS. CHANGED OUT UNDERREAMER TO A WFD 'REEVES' STYLE UNDERREAMER. STARTED SEEING MOTOR WORK AT 8066.6', AND AT 8069' WE BROKE THROUGH. RAN UNDERREAMER TO 8090'. POOH. RBIH WITH 2.25" JSN. BEGIN N2 ASSIST FCC. CONTINUED N2 FCC. CLEANED OUT TO 8620' CTMD USING HEC GEL SWEEPS. HAD GOOD RETURNS THROUGHOUT JOB. POOH. TAGGED UP ON INJECTOR 235' EARLY. COUNTER OFF DEPTH. RBIH TO CHECK ACTUAL TD. TAGGED SAND TOP AT 8365' CTMD. CLEANED OUT THE RAT HOLE FROM 8365' TO 8605' CTMD. FREEZE PROTECTED THE TUBING TO 2500' AND FLOW LINE WITH 60/40 MECH. <<< JOB COMPLETED >>> DRIFT & TAG W/2.50" CENT TEL, SB TO TD @ 8526' MD , SAMPLE OF FRAC SAND (196') RAT HOLE --- ATTEMPT TO RUN CATCHER. RAN INTO FRAC SAND, BITS OF METAL. PUMPED 91 BBLS DIESEL @ 80 DEGREES F TO ASSIST SLICKLINE. BRUSHED AND FLUSHED TBG. SET 3 1/2 X-LOCK CATCHER AT 7575'.--- PULL STA# 1 1 1/2" DGLV .... SET STA#1 1 1/2" FLOW SLEEVE .... START IN HOLE TO PULL C-SUB. JOB IN PROGRESS. Page 2 S-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/25/02 PULLED 3 1/2" X-LOCK C-SUB. DRIFT W/2.80" CENT ON 2.5" X 10' D-GUN W/ 2.79 ON TOP TO 7600' SLM --- LEAVE WELL SHUT IN .... ( PRE JET PUMP ) 12/08/02 TESTEVENT--- BOPD: 103, BWPD: 1,410, MCFPD: 27, AL Rate: 0 FLUIDS PUMPED BBLS I PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (1 TEST) 56 METHANOL 510 60/40 METHANOL WATER 121 DIESEL 106 CRUDE 435 2% KCL WATER 3252 EXTRA SLICK 2% KCL WATER 196 2% KCL WATER WITH ADDITIVES 120 HEC 12 7-1/2% HCL ACID 36 RESIN 13,000 LBS --- 20/40 RIVER SAND 8937 GAL NITROGEN 340 1% EXTRA SLICK KCL WATER 155 HEC GEL 534O TOTAL Page 3 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: RESIN CONSOLD CHG JET PUMP Abandon_ Suspend_ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ Re-enter suspended well _ RESIN CONSOLDIATION Time extension _ Stimulate _ CHANGE JET PUMP Variance _ Perforate _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service_ 4. Location of well at surface 963' FNL, 4500' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 771' FNL, 665' FEL, SEC 03, T11N, R12E, UM At effective depth 965' FNL, 715' FEL, Sec. 03, T11N, R12E, UM At total depth 991' FNL, 723' FEL, Sec 03 T11N, R12E, UM (asp's 618930, 5980520) (asp's 617573, 5975410) (asp's 617527, 5975216) (asp's 617519, 5975190) 6. Datum elevation (DF or KB feet) RKB 64.5 feet 7. Unit or Property name Prudhoe Ba~/Unit 8. Well number S-216 9. Permit number / approval number 200-197 10. APl number ' 50-029-22989-00 11. Field / Pool Prudhoe Bay Field / Polaris Pool 12. Present well condition summary ~ Total depth: measured 8712 feet Plugs (measured) Tagged top of sand @ 8605' (04/16/2002) true vertical 5624 feet Effective depth: measured 8605 feet Junk (measured) true vertical 5521 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 260 sx Arcticset (Aprox) 139' 139' Surface 3542' 9-5/8" 479 sx Arcticset Lite III, 3571' 2871' 421 sx 'G' Production 8672' 7" 207 sx Class 'G' 8698' 5611' Perforation depth: measured Open Perfs 8000'-8010', 8170'-8190', 8320'-8330' =....... ......... " true vertical Open Perfs 4948'-4957', 5105'-5124', 5248'-5257' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2" XO 3-1/2" @ 71'. 3-1/2", 9.2#, L-80 NSCT TBG @ 763.9' MD? ';-~ .......... v ........ 3-1/2", 9.2#, L-80, Tubing Tail @ 7697' MD. ~'""~":%"~ ~''' Two --- 7" x 3-1/2" Baker 'S-3' Packers @ 7574' & 7639' MD. , 3-1/2" HES X Nipple @ 2098' MD. 13. Attachments Description summary of proposal mX Detailed operations program 15. Status of well classification as: 14. Estimated date for commencing operation September 23, 2002 16. If proposal was verbally approved Name of approver Date approved Oil _X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: GPB Polaris/Orion Lead Engineer Don Schrnohr FOR COMMISSION USE ONLY Questions? Call Don Schmohr @ 564-5494. Date September 12, 2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness ~ Approval Plug integrity _ BOP Test _ Location clearance -- I Mechanicallntegrity Test_ Subsequent form required 10~ ~'~Oq 'T--~.[~. ~P5 ~L~ - , ,,C,,,,A,_ GIGNED D'¥ Approved by order of the Commission ~;) '¥a¥1or ,.~,~mq~.qt Commissioner Date Form 10-403 Rev 06/15/88 · DUPLICATE SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 12, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 · Dear Winton: Re: Sundry Notice for S-216 FCO and Resin Squeeze S-216 has not been able to produce consistently, having only produced 7 MBO in the 16 months since completion. The well has shown the potential to produce 500 BOPD, but has been mostly shut-in. Formation sand production from the OBa and N-Sands has resulted in five coiled tubing fill clean-outs due to bridges in the tubing or fill above the perfs. The tubing is currently bridged off with formation sand. The attached program is designed to resin consolidate the offending N-Sand perforations, thus allowing the well to produce normally. Resin consolidation of the OBa-Sands is an option in the future. The same program was implemented on S-200 N-Sands and completely shut-off the sand production, while maintaining most of the oil production. _-r-~,;,....... pro,mm ., ,.,,,.,....,.;----" "~'~ *~"-..... ~--"............~' .... .....,v.;'-- The procedure includes the following major steps: I Iii IIIII IJlll I IIIII I I I Step Category 1 S 350 2 T 350 2 C 350 3 T 350 3 C 350 4 S 350 5 E 350 IOR Description Pull Flow Sleeve & Dummy-off GLM #1. Underbalanced FCO to 8090'. U/B FCO w/N2 to 8090'. Resin consolidate perfs. Wait on resin. Underbalanced FCO with N2 to - 8600'. Underbalanced FCO with N2 to ~ 8600'. Pull DGLV & set Flow Sleeve in GLM #1. Set Eclipse tubing patch & Weatherford jet pump. POP. Last test: Max Inclination: Perf deviation: Min. ID: Last TD tag: Last Downhole Ops: Fluids in hole: Latest H2S value: Reference Log: BHT & BHP: 7/13/02 23 BOPD, 1680 BWPD, circulating power water, tubing bridged. 70° @ 3873'. 18° @ 8366'. 2.813" at XN nipples at 2107', 7617', 7665', 7685' MD 7/16/02 slickline bailed formation sand from tubing at 7553'. 7/16/02 slickline bailed formation sand from tubing at 7553'. Injection water, power fluid for hydraulic jet pump. Not Tested. Offset well S-200 10 ppm on 8/14/01. Sperry Sun MWD EWR 12/24/00 Estimated 101° F & 2200 psia @ 8315' MD (5178' TVDSS). '--('-ontacts "Office Home .;ell Donn Schmohr 564-5494 345-4861 529-8796 Steve Deckert 564-4128 338-1476 240-8046 1) Slickline work: a) Pull Flow Sleeve from GLM #1 and replace with DGLV. 2) CTU work: a) General Comments: i) Please have the PE discuss this job with Donn Schmohr or Steve Deckert prior to rigging up CT. The objective is to first clean out and expose the N (8000 - 8010') peris so that they may be resin consolidated, to reduce sand production while maintaining most oil production. Afterwards, the well will be cleaned out to expose the OBa and OBd peris (which don't need resin consolidation). Then the Eclipse packer & jet pump can be re-run and the well returned to production. ii) The treatment pumping stages are recommended to be pumped at 800, 1000, and 1200 psig. The formation parting pressure is known to be 1000 psig on the wellhead (CT x PT annulus, "dead string"). Conceptually, placing 50% of treatment fluids at below parting pressure, 25% at parting pressure, and 25% above parting pressure provides the greatest chance for all peris (prop'd or not) to take fluid. iii) It is recommended that the mix water be between 75°F & 100°F. This provides a reasonable compromise between resin working and setting time constraints. iv) Schlumberger will submit a separate resin mixing program. Have a pre-job meeting with Schlumberger to plan out fluid types, temperatures, and volumes. b) Perform under-balanced fill clean-out to - 8330'; using N2, HEC gel sweeps, and the flowback separator. Jet GLMs clean, on the way out of the hole. Plug back with sand to -8100ft. MD. Cap the plug back sand with impermeable cap of Calcium Carb. i) The objective is to expose the N (8000 - 8010') but to protect the and OBa-b (8170-8190') and OBd (8320- 8330') peris. ii) Underbalance is desired for the clean-out, to prevent plugging the peris. Plugged peris would prevent the resin from treating the unconsolidated formation. iii) HEC gel sweeps are preferred for the Schrader Bluff, since BioXan doesn't break at 100°F formation temperatures. c) Resin consolidate the N (8000 - 8010') peris as follows: i) Test injectivity with 2% KCl flush* at staged pressures of 800, 1000, and 1200 psig, not to exceed 1.5 BPM. ii) Reciprocate from 7090 - 8020' and jet 10 Bbls of acid* into the formation at staged pressures of 800, 1000, and 1200 psig, not to exceed 1.5 BPM. (1) The purpose of the acid treatment is to clean out as many peris as possible. iii) Reciprocate from 7090 - 8020' and jet 36 Bbls of KCl flush* into the formation at staged pressures of 800, 1000, and 1200 psig, not to exceed 1.5 BPM. iv) Reciprocate from 7090 - 8020' and jet 36 Bbls of solvent* into the formation at staged pressures of 800, 1000, and 1200 psig, not to exceed 1.5 BPM. (1) The purpose of the solvent* is to remove hydrocarbons from the near wellbore sand/proppant grains. Hydrocarbon removal is necessary to allow resin adhesion. v) Reciprocate from 7090 - 8020' and jet 36 Bbls of pre-flush* into the formation at staged pressures of 800, 1000, and 1200 psig, not to exceed 1.5 BPM. (1) The purpose of the pre-flush* is to chelate any loose cations and to oil wet oil the sand/proppant grains to be treated. The resin preferentially bonds to oil wet surfaces. vi) Reciprocate from 7090 - 8020' and jet 36 Bbls of resin* into the formation at staged pressures of 800, 1000, and 1200 psig, not to exceed 1.5 BPM. 3) d) e) (1) The w~"( .~g time of the resin is 3 hrs/75°F, 2 h~,'~' )°F, 1.6 hrs/100°F. Static formation temperatures are 90 - 100°F. An accelerator has been added to the resin to get a practical setting time at 90 - 100°F. (2) The purpose of the resin solution is to create a strong, but highly permeable consolidated pack to prevent the migration of proppant and formation sand. vii) Shut down 20-30 minutes. (1) Length of shutdown time controlled by ambient temperatures. Have Schlumberger determine this time based on resin working time and actual pumping time. viii) Reciprocate from 7090 - 8020' and jet 119 Bbls of flush* into formation at staged pressures of 800, 1000, and 1200 psig, not to exceed 1.5 BPM. (1) The final flush is designed to ensure that permeability is retained. ix) Jet the GLMs clean, on the way out of the hole. x) Freeze protect to 3000' with 60/40 Methanol. Wait 24 hours for resin to set. (1) Static formation temperatures are 90 - 100°F. (2) Curing times are 24 hrs/75°F, 14 hrs/90°F, 11 hrs/100°F. (3) Maximum strength times are 58 hrs/75°F, 34 hrs/90°F, 26 hrs/100°F. Perform under-balanced fill clean-out to - 8600' (Driller's PBTD); using N2, HE(3 gel sweeps, and the flowback separator. Jet GLMs clean, on the way out of the hole. Freeze protect to 3000' with 60/40 methanol. i) The objective is to expose the N (8000 - 8010'), OBa-b (8170-8190'), and the OBd (8320- 8330') perfs for production. ii) Underbalance is desired for the clean-out, to prevent plugging the perfs. iii) HE(3 gel sweeps are preferred for the Schrader Bluff, since BioXan doesn't break at 100°F formation temperatures. iv) Since this well has a history of producing sand and filling the wellbore, more rathole is better. Thus clean-out below the perfs to as close to Driller's PBTD as practical. Extraordinary efforts to obtain more rathole are not necessary. ,, Slickline work: a) Pull DGLV from GLM #1 and replace with Flow Sleeve. 4) Electric Line work: a) Set Eclipse straddle packer and Weatherford hydraulic jet pump. 5) POP well, unless otherwise instructed by Pad Operator. Sincerely, o. Don $¢hmohr GPB Polaris/Orion Lead Engineer 8/30/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. t42t Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite t00 . Anchorage, AK 99501 Field: Polaris Well Job # Log Description Data BL Sepia CD S-216 PSP-LEAK DETECTION LOG 07129101 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 SEP 1 4 2001 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Recoiv~~~/fi DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS ov °o? 550 WEST 7TM A VENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 September 6, 2001 BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612. Anchorage, Alaska 99519-6612 RECEIVED 2001 Alaska Oil & Gas Cons. Commission Anchorage Via Fax (564-4637) and Mail Attention: Oil Beuhler Central New Developments Manager Subject: Pmdhoe Bay Unit Tract Operations for Wells S-200, S-201 and S-213 on ADL 28258, W-200 (ADL 28263), S-216 (ADL 28261), and W-201 (ADL 28282) Dear Mr. Beuhler: Reference is made to your letter of August 31, 2001 regarding, a'request to continue Tract Operations for PBU .Wells S-200, S-201 and S-213 on ADL 28258, W-200 on ADL 28263, S-216 on ADL 2826.1, and W-201 on ADL 28263-1.. The Division approves your request to extend the Tract Operations. for the six wells' from September 1, 2001 until the fkst of the month following the issuance of the Polaris Participating Area final decision, but in no case, later than November 1,2001. Sincerely, Mark D. Myers Director cc: Cammy Taylor- AOGCC Wade Fennel- Chevron PBU. PolarisWELLS.TOExtension. doc "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." KA~(J STATE OF ALASKA (" ALAS IL AND GAS CONSERVATION COMMisSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing !'1 Alter Casing [] Repair Well [] Other .2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I~1 Development KBE = 64.52' 3. Address r'l Exploratory 7. Unit or Property Name I-1 Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface i8. Well Number 4316' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM S-216 At top of productive interval 9. Permit Number / Approval No. 200-197 4508' NSL, 665' WEL, SEC. 03, T11N, R12E, UM 10. APl Number At effective depth 50-029-22989-00 4460' NSL, 676' WEL, SEC. 03, T11N, R12E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Polaris Pool 4288' NSL, 722' WEL, SEC. 03, T11N, R12E, UM (Undefined) 12. Present well condition summary Total depth: measured 8712 feet Plugs (measured) Top of Sand is at (Approx) 8100' (07/01) true vertical 5624 feet Effective depth: measured 8100 feet Junk (measured) true vertical 5039 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 3542' 9-5/8" 479 sx Arcticset Lite III, 421 sx 'G' 3571' 2871' Intermediate Production 8672' 7" 207 sx Class 'G' 8698' 5611' Liner RECEIVED Perforation depth: measured 8000'- 8010', 8170' - 8190', 8320'- 8330' SEp 0 5 001 true vertical 4948' - 4957', 5105' - 5124', 5248' - 5257' Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 to 7697' Anchorage Packers and SSSV (type and measured depth) 7" x 3-1/2" Baker 'S-3' packer at 7639'; 3-1/2" HES SVLN at 2098' 13. Stimulation or cement squeeze summary Intervals treated (measured) 8170' - 8190'; 8000' - 8010' Treatment description including volumes used and final pressure See Attached Summary of Well Events 14. Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: I-I Copies of Logs and Surveys run [] Oil D Gas ~ Suspended Service I~ Daily Report of Well Operations ~ 7. I hereby certify that the fore. going is true ,an~l _correct to the best of my knowledge Signed TerrieHubble ~'"~ i~~r~. Title TechnicalAssistant Date 0~-0Li/-{~)( ':',.,i Prepared By Name/Number: Sondra Stewman, ~64-4750 , ~ ~ A JA . ~ AA*J I *AA Form 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicate..~ Well: S-216, RWO Field: Prudhoe Bay Field/Polaris Pool APl: 50-029-22989-00 Permit: 200-197 Rig Accept: 08/09/01 Rig Release: 08/12/01 Drilling Rig: Doyon 14 Summary of Well Event-= 05/12/01 & 05/13101 Set DGLV, SPMG, L&T IA. Pulled RK- OGLV at St//1. Pulled RK-LGLV at ST//4, set RK-DGLV at ST //4. Set Petredat SPMG at ST//1. Pulled 3-1/2" X-Lock C sub at 7617' MD. 05/14101 MIRU RIH with 2.25" nozzle. Tag bottom at 8467'. Batch mix 5000 lbs 20/40 River sand. Pump 3 clean / 25 bbls dirty / 2 clean. Lay in 20/40 sand. PUH to safety, wait for 1 hour. Tag TOS at 8238', perform Leak-Off test - lost 400 PSI in 10 minutes, retest with same results. Final Re-Tag TOS at 8243' (on target). POOH. 05/19/01 Shot 20 Interval (8170' - 8190') with 2-1/2" Hollow steel carrier, HSD 35B up RDX, 4 SPF, 180 Degree Phasing, rotated 90 Degree off bottom. Well was shot shut-in. Freeze protected well and flow line. 05/21/01 Fractured OB/A-B sands with YF-140D system, placed 71.7 K #s of 16/20 RCP behind pipe. Intentionally under flushed by 5 bbls, 879 #s left in casing. EST TOS = 8233' MD. Max treat 8550 PSI, AVG TREAT - 4177 PSI; load to recover - 1277 bbls tubing freeze protected to 2000' with Diesel, recovered all TREESAVER cups. 05/22/01 & 05/23/01 Tagged TD with 2.5" CENT at 8146' MD (RKB) no ELM available. Set 2.813" X-Lock C-SUB. Pulled STA//1 RK SPMG; STA//4 RK- DGLV. Set STA//4 RK-LGLV; STA//1 RK-OGLV. Bail 2 GAL of FRAC Sand above 3-1/2" X-Lock C-SUB with 10' x 2.50" Pump latch and pull 3-1/2" C-SUB. 05/25101 RIH while well flowing through APC test separator; clean out FRAC Sand / River Sand from 8137 CTM to 8390 CTM; POOH at 80%; Leave well flowing through APC separator to S-44; Rig down, well was flowing at 1000 BPD mostly water with 5% solids. 07/02/01 MIRU RIH with 10' 2.5" HSD gun, 4 spf, 180 Degree phasing.. Tie in with TEL. Position and shoot gun //1-8000- 8010 (REF. OH EWR Log dated 12/24/00). 07/04/01 & 07/05101 Attempt to set Catcher Set down on Hydrates at 4906' WLMD. Run sample bailer and 2.3 CENT to 7700' WLMD. Run 2.8 GR to 7700' WLMD. Set catcher at 7607' WLMD. Pull S/O GLV from GLM//1 at 7552' WLM, pull LGLV from STA # 3 at 5176' WLM, attempted to set DGLV in STA.//3 with no success. RIH with 10' 2.50" Roller stem, KJ, LSS, KJ, 3.5" OM- 1, with DGLV to ST^ # 3 at 5176, WLM - set Petredat side pocket gauge in ST^ # 1 at 7552' WLM - Pull 3.5" X-Catcher from X-Nipple at 7607' WLM. Dump 5 gallons of liquid latex at 8053' WLMD Final Depth 8050' WLMD. S-216 Summary of Well Events Page 2 07/07/01 Attempt to FRAC Schrader 'N' Sand. Pumped 128 Bbl B/D stage at 30 BPM. Formation Broke at 5700 PSI, average PSI = 3700 PSI. ISIP = 1170 PSI Performed step down test. Had 450 lb NWB Friction. Performed 60 Bbl YF140D data FRAC @ 25 BPM. AVE PSI = 3500 PSI. ISIP = 1176 PSI. Closure EST at 2.45 MIN 45% EFF Fluid. Re-Designed FRAC. Started FRAC Treatment at 25 BPM 30 bbl Pad. Started 1 PPA sand ramp. IA PSI started falling and tree saver failed in 7 PPA stage. A total of 16000 lb 16/20 C-Lite pumped. Isolated Treesaver relief line set new MAX PSI at 4000 PSI and went to flush. Back side pumping at 1.5 BPM to maintain POS pressure during flush. MAX PSI during FRAC = 3927 PSI. Well F/P down tubing with 30 bbls MeOH / Water IA / T Tracking pumped at 1.5 BPM 1800 PSI. 08/03/01 Set Baker 2.5" IBP with Mid Element at 7676'. 08/06/01 Cut 3.5", 9.2# tubing at 7594' with 2-3/8" Chemical cutter. 06/11101 & 06/12/01 Ran J.B. and 6.0" gauge ring to 7613' SLM. Drift through tubing stub and overshot with 2.77" Swage to 7680' SLM. Reset 3-1/2" RHC plug body. Set Ball and Rod. 08/16/01 - 08/20/01 Pulled Ball and Rod from 7654' SLM. Pulled STA # i RK-DGLV at 7506' SLIVl. Pulled STA # 4 RK-RP Shear VLV. Set STA # 4 RK-DGLV; STA # i RK-SPMG, M[TZA to 3500 PS]:--- Passed, bailed ~ 2-1/2 GAL Sluggers from top of [BP Pulled 2-1/2" [BP (Recovered both Elements). Tag TD with 2.5' CENT at 8067' ELM. 06/22/01 M:[RU Dowell - SLB FRAC CAT complete breakdown / step down with 20#, Linear (:;;EL, :[SIP EST = 1150 PS:[. WB Friction EST = 200 PS]:. Data FRAC with 40 Bbls 30# XL Gel closure time EST = 31 minutes Fluid EFF EST= 72%. Pump Fracture treatment; 18 BPM, 30# Gel with 12 Bbl Pad and 16/20 CARBO-LITE screen out with 8 PPA across perforations --- Suspect near Well bore problems. Total of 7800 lbs proppant behind pipe. 23000 lbs left in well bore EST Top Sand = 4600'. 06/25101 & 06/26/01 M::[RU DS CTU #3 PU 2.25" combo nozzle. R]:H and tagged sand at 450'. Begin reverse circulating out the sand. Reverse down to 7890' Clear coil, stand by for fluids. Tag PBTD at 8108' ELM. Sample of Sand and Carbolite. Pull STA 1, 1-1/2" side pocket memory gauge. Set STA 1, 1-1/2" side pocket memory gauge, RI<: latch. BP EXPLORATION Page 1 of 7 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Activity Code NPT Phase Description of Operations 12/8/2000 12:00 - 18:00 6.00 MOB P PRE Prepare for Rig move. Drive rig off S-201 and move sub-base and mud pit modules to S-216. Spot pits and sub-base. PJU and interconnect modules. Spot cuttings tank. Accept rig at 18:00 hrs on Dec 8, 00. 18:00 - 19:00 1.00 RIGU P PRE PJU Top-drive to handle 5" drill pipe. 19:00 - 19:30 0.50 RIGU P PRE Held Pre-spud meeting with Rig crews. 19:30 - 00:00 4.50 RIGU P PRE NIU 21 114" Hydril annular with no Diverter line onto 20" conductor. Take on drill water. Build spud mud. R/U to drill. 1219/2000 00:00 - 02:00 2.00 RIGU P PRE Finish installing Diverter turn buckles and mixing Spud mud. 02:00 - 07:00 5.00 RIGU P PRE PIU 140 joints of 5" S-135 drill pipe and rack in derrick. 07:00 - 09:30 2.50 DRILL P SURF M/U 12 1/4" drilling assembly. Orient UBHO sub. Adjust mud motor to 2.12 deg bend. 09:30 - 10:00 0.50 DRILL P SURF Fill up hole with seawater. Check surface equipment for leaks-OK. R/U Sperry-Sun Gyro equipment. 10:00 - 10:30 0.50 DRILL P SURF Held pre-spud meeting with rig crews. 10:30 - 20:30 10.00 DRILL P SURF Spud well. Circulate and clean out 20" conductor from 104' to 110'. Drill 12 1/4" hole from 110'. Kick-off well and drill directional building angle to 5 deg with a 254 deg azimuth as per gyro to 459' MD. 20:30 - 21:00 0.50 DRILL P SURF Circulate bottoms up from 459'. 21:00 - 22:00 1.00 DRILL P SURF POOH for BHA change. No hole problems encountered. 22:00 - 00:00 2.00 DRILL P SURF Inspect bit-OK. Adjust mud motor to 1.83 deg. P/U MWD. Orient same. PIU Flex drill collars to 295'. 12/1012000 00:00 - 01:00 1.00 DRILL P SURF Finish M/U BHA #2. Fill drill string. Break circulation. 01:00 - 00:00 23.00 DRILL P SURF Drill 12 1/4" directional hole from 459' to 1547'. WeB 10-30K, RPM 30-40 wl5k torq., GPM 430-450 w11200 psi. PIU 95K, S/O 93K, ROT WT 94K. ART = 9.25 hrs, AST = 8.5 hrs. No Drag. No Losses. 12/11/2000 00:00 - 00:00 24.00 DRILL P SURF Drill 12 1/4" directional hole from 1547' to 3227'. WeB 15-30k, RPM 30 wi 7k torque, GPM 503 w/1675 psi. P/U 11 lk, S/O 95k, Rot Wt 103k. ART = 7.75 hrs.AST = 9 hrs. No excess drag. No losses. 12112/2000 00:00 - 05:30 5.50 DRILL P SURF Directionally Drill 12.1/4 hole from 3,227 ft to 3,587 ft. No drag, No losses. Flowrate {~ 500 GPM with lower mud vis. Final Angle @ 69 degs inclin. ART= 3.75 hrs Top SV3 sand ~ 3,300 ff MD, 2,773 ft TVD 05:30 - 06:30 1.00 DRILL P SURF Circulate bottoms up @ 500 GPM/1570 psi. RPM ~ 5516,000 ftlbs. Shakers clean. 06:30 - 07:30 1.00 DRILL P SURF Make check trip to 1800 ft. Average Drag @ 20 klbs. Some 35 klbs @ 2400-2200 f. 07:30 - 09:15 1.75 DRILL P SURF RIH. taking weight @ 3,300 ff. Clean pick up weights. Work down. Acting like balled BHA. Rest of Hole good. 09:15 - 11:30 2.25 DRILL P SURF Sweep Hole clean @ 500 GPM. Spot 250 bbl Casing Pill w/5% Lubricant. Drop ESS. 11:30 - 17:00 5.50 DRILL P SURF POH. 25K overpull @ 2150'. Pump and Backream as necessary to 1600', Dry Wiping every stand until nornal overpull then shut down pumps and continue POH. 17:00 - 19:30 2.50 DRILL P SURF Stand back 5" HWDP & I_/D BHA. 19:30 - 22:00 2.50 CASE P SURF Clear Rig Floor. PJU 9 518" Casing Running Tools. Make Dummy Run with 9 5/8" Mandrel Hanger and Landing Joint. 22:00 - 00:00 2.00 CASE P SURF Hold PJSM with all personnel. M/U Shoe Track and RIH With 9 Printed: 8/21/2001 3:57:28 PM BP EXPLORATION page 2 of 7 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Activity Code NPT Phase Description of Operations ~12/12/2000 22:00 - 00:00 2.00 CASE P SURF 5/8" 40 ppf, L-80, BTC casing per program. ;12113/2000 00:00 - 02:00 2.00 CASE P SURF Run 9.5/8", 40 Ib/ft, BTC casing to 1,810 ft. Held Up. 02:00 - 05:30 3.50 CASE N DPRB SURF Attempt to work down pipe- No progress. Clean Pick ups. Attempt to circulate down- no go. 05:30 - 08:30 3.00 CASE N DPRB SURF Unable to progress pipe OOH. Connector hanging up on bottom of 20" conductor pipe. Rock pipe, Remove slips. No GO. Rig not centred correctly. Rotate casing. RIH to see if 9.518" would go to bottom with new orientation- No GO. POOH. Prepare to Pump Dry job and L/O joint. Hole conditions deterioating 08:30 - 14:30 6.00 CASE N STUC SURF Hole conditions deteriorate.Window of movement reduced from 15 ft to 2 ft- Loose all circulation. Work Pipe from 300 klbs ( 200 klbs overpull) down to 40 klbs. No further movement. 9./8" shoe @ 1,580 fi. Vis up mud system to 300. CBU with losses- no change. Pull up to 450 klbs ( 350 klbs overpull). Some minor indications of movement. 14:30 - 16:00 1.50 CASE N DPRB SURF Pull 9.5~8" casing free and regain full circulation. Circulate Bottoms Up. No excessive gravel seen {~ surface. L/O joint and gained 60 bbls while pumps off ( Formation giving losses back). 16:00 - 23:00 7.00 CASE N DPRB SURF Cont. working pipe, able to rotate. Pull 1 Jt. with minimum overpull. Pump Dry Job & Cont. POH. All 9 5~8" Casing collars hanging up on 20" Conductor shoe. Having to work and turn string to pass collars. Pulled total 23 Jts 9 5/8" casing. 23:00 - 00:00 1.00 CASE N RREP SURF Attempt to align Rig Closer to Center of Hole Prior to pulling 9 5~8" Casing Cetralizers through 20" Conductor Shoe. ,12114/2000 00:00 - 01:30 1.50 CASE N DPRB SURF Continue to align rig. 01:30 - 06:00 4.50 CASE N DPRB SURF Lay out remainder of 9.5/8" casing. Heat Float collar. Standback First two joints. One centraliser missing. Total 40 joints Laid out and placed to one side for inspection. 06:00 - 08:30 2.50 CASE N DPRB SURF Rig down casing handling equipment. Clear rigfloor and clean up rig. 08:30 - 10:30 2.00 CASE N DPRB SURF Make up 12" Hole Opener assembly. 10:30 - 11:30 1.00 CASE P SURF Injury to Thoma Palm. Shut down rig and debrief incident. Hold Safety meeting with both crews. 11:30 - 15:00 3.50 CASE N DPRB SURF RIH to 1400 ft. Wash/Ream down to 1540 ft. No progress. Vary RPM (0-110), Vary Flowrate ( 0 to 550 GPM). Appears as if bullnose burying into side of hole. No rapid flucuations in torque. 15:00 - 18:00 3.00 CASE N DPRB SURF POH wi 12 1/4" Hole OpenerAssy. 18:00 - 20:30 2.50 CASE N !DPRB SURF RIH with 12 1/4" Bit and Directional Assy. Survey and Orient @ 1450' Cont. RIH to 1530'- Held Up. 20:30 - 00:00 3.50 CASE N DPRB SURF Oriented and washed 12 1/4" Hole from 1530' to1565', Washed and Reamed from 1565' to 2169'. Some tight spots - Correlated very well with shale stringers on Sperry LWD Gamma Ray Log. Worked through all tight spots thoroughly. 12/15/2000 00:00 - 02:30 2.50 CASE N DPRB SURF Wash/Ream to bottom @ 3,587 ft. Minor tight spots correlating with clays. 02:30 - 05:00 2.50 CASE N DPRB SURF Circulate bottoms up @ 500 GPM/1600 psi. Not much back across shakers. 05:00 - 06:30 1.50 CASE N DPRB SURF POOH to 2,600 ft. Average drag ~ 20 klbs. 06:30 - 10:30 4.00 CASE N DPRB SURF Unable to progress OOH without pumps/RPM. Appears to be Printed: 8/21/2001 3:57:28 PM BP EXPLORATION Page 3 of 7 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Activity Code NPT Phase Description of Operations 12/15/2000 06:30 - 10:30 4.00 CASE N DPRB SURF combination of Swelling clays and/or Cutting beds (gravels). Pump required back to 1700 ft. 10:30 - 13:00 2.50 CASE N DPRB SURF Lay down Drilling/Cleanout assembly. 13:00 - 15:00 2.00 CASE N DPRB SURF M/U Smith 12.1/4" Hole opener assembly. 15:00 - 16:30 1.50 CASE P SURF Slip & Cut Drilling Line and Service Top Drive 16:30 - 17:30 1.00 CASE N DPRB SURF Cont. RIH w/H/O, HWDP & 5' DP to 1925- Held Up could not work through dry. 17:30 - 23:00 5.50 CASE N DPRB SURF Wash & Ream with Hole Opener fron 1925' to TD @ 3587' with 616 gpm of 10 ppg, 300 Vis.,68 yield point Mud at 135 to 140 RPM. Large amount of cuttings seen over the shakers while reaming. 23:00 - 00:00 1.00 CASE N DPRB SURF Circulate 10.3 ppg Hi Vis Baroflbre Sweep. Work and rotate pipe @ 140-145/3000 ftlbs. 620 GPM/1300 psi. Cuttings seen at surface. 12/16/2000 00:00 - 02:30 2.50 CASE N DPRB SURF Circulate and condition hole @ 620 GPM/1300 psi w/Hi Vis, I Barofibre sweep. Circulate shakers clean. Work and rotate pipe @ 145 RPM/3000 ftlbs. Spot Casing pill w/5% lubricants. 'Final Vis = 200. 02:30 - 04:00 1.50 CASE N DPRB : SURF POOH. Work/Wipe out one tight spot @ 2,600 ft. Rest of hole slick. 04:00 - 06:30 2.50 CASE N DPRB SURF L/O Smith 12.1/4" Hole Opener and flex collars. Clear rigfloor. 06:30 - 09:00 2.50 CASE P SURF R/U to run 9.5/8" Casing. M/U Franks Fill Up Tool and casing equipment. PJSM. 09:00 - 14:30 5.50 CASE P SURF Run 9.5/8", 40 lb/fi, BTC casing. Check floats and bakerlock shoetrack. No resistance until 2,700 ft. 14:30 - 18:30 4.00 CASE N DPRB SURF Work 9.518" casing with/without circulation. Slack off everything but Top drive weight and vary circulation rates from 100-240 GPM/350 psi. Broke thru @ 3,165 ft. Suspect hole geometry ( 52 degs @ 2,700 ft to 69 degs @ 3,100 ft). Clean pick ups. ,18:30 - 19:30 1.00 CASE P SURF Run remander of 9.5/8" casing washing down last two joints. Land 9.5/8" casing @ 1930 hrs. 87 joints, 40 Ib/ft, L-80, BTC casing. Shoe ~ 3,572 ft MD/2,872 ft 'I'VD. '19:30 - 22:00 2.50 CASE P SURF Circulate & Condition Mud for Casing. R/U Dowell. Circulate @ 10 BPM/600 psi. Drop vis to 70. 22:00 - 22:30 0.50 CASE P SURF Hold PJSM - Rig Crew & all Service Company Personnel. 22:30 - 00:00 1.50 CASE P SURF Test Dowell lines to 3500 psi Batch Mix & Pump 75 bbls 10.4 ppg. MudPush Spacer then Mix & Pump 378 bbls, 10.7 ppg Lead Slurry followed by 20 bbls, 15.8 ppg Tail Slurry ( Incomplete ). 12/17/2000 00:00 - 01:00 1.00 CEMT P SURF Completed pumping Tail slurry: total - 83 bbls, 15.8 ppg. Dropped plug and displaced: 2 bbls cmt and 8 bbls water with Dowell followed by 257 bbls mud with Rig. Bumped plug w/ 3500 psi. Fullreturns throughout job. 35 bbls cement - contaminated mud followed by 40 bbls Good 10.7ppg. Lead Slurry to Surface. 01:00 - 05:30 4.50 BOPSUF P SURF L/D Landing Jt., Clean out Riser, Diverter. Clean Floor and cellar. Ship out Cmt. tools, change bails,N/D 20" Riser, 05:30 - 11:00 5.50 WHSUR N HMAN SURF While attempting to remove 20" Diverter from cellar;Forklift hit Diverter Skid sending it falling into the cellar: striking and damaging the 9 5/8" casing mandrel seal assembly. Shut down Rig for incident investigation then formulate plan and carry out subsequent removal of Diverter. Printed: 8/21/2001 3:57:28 PM BP EXPLORATION Page 4 of 7 Operations Summa Report Legal Well Name: S-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Activity Code NPT Phase Description of Operations 12/17/2000 05:30-11:00 5.50 WHSUR N HMAN SURF 11:00- 18:00 7.00 WHSUR N HMAN SURF Coordinate with FMC Representative re. Repair. Got Wayne Simmons, Arctic Fabricators on site to facilitate repair; heated ,straightened mandrel, installed csg.head & made 4 welding passes on inside seal area. Post heated and blanketed csg.head. 18:00 - 00:00 6.00 WHSUR N HMAN SURF Slowly cool csg.head - Temp ~ 00:00 Hrs.- 195 deg. 12/18/2000 !00:00 - 05:00 5.00 WHSUR N HMAN SURF Wait on Casing head to cool checking hourly. 05:00 - 10:00 5.00 BOPSUI~ P SURF Nipple up Tubing spool, BOPE and bell nipple. 10:00 - 11:15 1.25 BOPSUI~ P SURF Test 9.5/8" casing and wellhead weld in stages up to 3500 psi- Good Test. 3.6 bbls pumped/returned. 30 minute test. 11:15 - 15:00 3.75 BOPSUI~ P PROD1 Test BOPE - 250 psi Low / 3500 psi High - Hydril, Rams, choke & kill lines and valves, Top Drive and all surface equip. Witness of BOP Test waived by Chuck Scheve, AOGCC 15:00 - 15:30 0.50 BOPSUI~ P PROD1 Rig down test equip., install wear ring. 15:30 - 19:30 4.00 DRILL P PROD1 M/U BHA # 6, 8 3/4" Steerable w/1 deg. fixed bent housing. PJSM prior to Sperry installing nuclear source. 19:30 - 23:00 3.50 DRILL P PROD1 RIH w/HWDP and 5" DP past Tam Port Collar, no problem, P/U 60 5" DP singles and stand back. Bit ~ 3000 ft. 23:00 - 00:00 1.00 DRILL P PROD1 Held Stripping Drill 12/1912000 00:00 - 01:30 1.50 DRILL P PROD1 RIH, P/U 5" DP singles and run to 3293'. 01:30 - 02:00 0.50 DRILL P PROD1 Service top drive 02:00 - 04:30 2.50 DRILL P PROD1 Drill float collar at 3487', cement and float shoe at 3571'. Drill 20' of new hole to 3607'. 04:30 - 06:30 2.00 DRILL P PROD1 CBU & displace hole with new 10.5 ppg LSND Mud. 06:30 - 07:00 0.50 DRILL P PROD1 Perform FIT with 10.5 ppg. mud in hole. Pressure 315 psi = EMW of 12.61. 07:00 - 21:30 14.50 DRILL P PROD1 Directional Drill 8 3/4" Hole from 3607' to 5070'. WOB= 5-10 K RPM= 80. GPM= 550. PSI= 1790 AST - 2.5 hrs, ART - 8.5 hrs. 21:30 - 22:30 1.00 DRILL P PROD1 Circ. 30 bbl Hi Vis wieghted sweep 22:30 - 00:00 1.50 DRILL P PROD1 Make 16 stand wiper trip to 9 5/8" Csg. shoe. 30K to 40K overpull between 4220 and 4178; worked through and wiped clean. Rest of hole very smooth - max overpul120K. 12/20/2000 00:00 - 00:30 0.50 DRILL P PROD1 RIH after 16 stand wiper trip to shoe. No fill 00:30 - 18:30 18.00 DRILL P PROD1 Directional Drill 8 3/4" Hole from 5070' to 6752'. WOB= 5-10 K RPM= 80-85. GPM= 550. PS1=1950 AST - 1 hrs, ART - 5.5 hrs. 18:30 - 19:00 0.50 DRILL P PROD1 CBU with wieghted HI Vis sweep. 19:00 - 21:00 2.00 DRILL P PROD1 Wiper trip to 5000', max pull - 40K over from 4220' to 4178' wiped clean with one dry pass. Normal drag - only 10 -20 K, Smooth hole. RIH to 6659, wash to 6752 -no fill. Slick Hole. 21:00 - 00:00 3.00 DRILL P PROD1 Directional Drill 8 3/4" Hole from 6752' to 6938". WOB: 5-15, RPM: 80-85, GPM: 575, PSh 2220 AST: 1 ART:5.5 12/21/2000 00:00 - 00:00 24.00 DRILL P PROD1 Drill 8 3/4" directional hole from 6938' to 8254' WOB: 5 -15 K, RPM: 80 - 90, GPM: 550 - 575 PSI: 2220 -2600. AST: 7 HRS, ART: 8 HRS. 12/22/2000 00:00 - 06:30 6.50 DRILL P PROD1 Drill 8 3/4" directional hole from 8254' to 8712' TD WOB: 5 -15 K, RPM: 80 - 90, GPM: 550 - 575 PSI: 2220 -2600. AST: 1 HRS, ART: 4 1/2" HRS. Printed: 8/21/2001 3:57:28 PM BP EXPLORATION Page 5 of 7 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Activity Code NPT Phase Description of Operations !12/22/2000 06:30 - 08:30 2.00 DRILL P PROD1 Circulate and condition mud. Sweep hole with high vis weighted pill. 08:30 - 12:30 4.00 DRILL P PROD1 POH to 9 5/8" casing shoe. 25K over pull 8712' to 7500' 12:30 - 14:00 1.50 DRILL P PROD1 Slip and cut drilling line. Service rig. 14:00 - 16:30 2.50 DRILL P PROD1 RIH from 3570' to 8500'. Wash to TD ~ 8712 - No Fill. No Tight spots. No reaming necessary 16:30 - 19:30 3.00 DRILL P PROD1 Pump Hi Vis weighted sweep, circ. & cond. mud for logs. Drop Sperry ESS. Pump slug. 19:30 - 00:00 4.50 DRILL P PROD1 POH. Hole slick, minimum overpull of 10 to 20 K. inc. 12/23/2000 00:00 - 01:00 1.00 DRILL P PROD1 POH. SLM. Stand back HWDP. 01:00 - 04:00 3.00 DRILL P PROD1 Lay down BHA. Down load MWD. PJSM. remove radio active sauces. Lay down BHA. Clear floor. 04:00 - 07:30 3.50 EVAL P PROD1 PJSM. With rig and Schlumberger crews. Pick up Schlumberger Platform Express logging tools. Make up Down Hole wet Connect and connect to 5" drill pipe. 07:30 - 09:30 2.00 EVAL P PROD1 RIH with 5" drill pipe and logging tools to 9 518" casing shoe. 09:30 - 10:30 1.00 EVAL P PROD1 Circulate at casing shoe. Rig up Schlumberger upper sheav and E-line. 10:30 - 13:00 2.50 EVAL P PROD1. RIH slowly to 5200'. Fill pipe and circulate every 5 stands. 13:00 - 14:30 1.50 EVAL P PROD1 Connect Side Door Entry Sub to 5" drill pipe. PJSM. RIH with E-line and latch into wet conect. Good connection. 14:30 - 00:00 9.50 EVAL P PROD1 RIH with 5" drill pipe and logging tools DPC (TLC) log down from 5199' to 8694'. Log POH. Repeat from 8100 back down to 8600'. Continue logging up to 5800' ( Incomplete).Good Logs. No tool or hole problems. 12/24/2000 00:00 - 00:30 0.50 EVAL P PROD1 POH 5" drill pipe with logs to SDES. 00:30 - 02:00 1.50 EVAL P PROD1 Remove cable clamp. Pull out of down hole wet connect and POH with E-line. Rig down E-line and sheaves. 02:00 - 04:00 2.00 EVAL P PROD1 POH 5" drill pipe with logging tools. 04:00 - 06:00 2.00 EVAL P :PROD1 PJSM. Lay down logging tools. 06:00 - 07:00 1.00 DRILL P PROD1 Make up BHA # 7 for clean out trip. 07:00 - 11:30 4.501 DRILL P PROD1 RIH with clean out assembly. Fill pipe at shoe and at 6500'. Wash last 68' to bottom as precaution. No fill. 11:30 - 16:30 5.00 DRILL P PROD1 Circulate and condition mud. Spot 382 bbl casing pill in open hole. 16:30 - 20:30 4.00 DRILL P PROD1 POH, Stand back 34 stands, lay down remainder. 20:30 - 21:30 1.00 DRILL P PROD1 Slip & Cut Drilling Line. 21:30 - 00:00 2.50 DRILL P PROD1 Continue POH L/D 5" DP, Stand back HWDP, L/D BHA 12/25/2000 00:00 - 00:30 0.50 DRILL P PROD1 Pull wear bushing. 00:30 - 02:00 1.50 CASE :~ PROD1 Change top rams to 7" and test bonnets to 3500 psi. ,02:00 - 02:30 0.50 CASE :) PROD1 Pick up 7" landing joint and make dummy run .02:30 - 04:30 2.00 CASE ~ PROD1 Rig up to run 7" casing. PJSM 04:30 - 10:00 5.50 CASE :~ PROD1 Run 7" 29 # -80 BTC casing, check floats, install two pup joints with RA tags and RIH to 9 5/8" casing shoe. 10:00 - 10:30 0.50 CASE ~ PROD1 Circulate 1.5 times casing volume. 10:30 - 17:00 6.50 CASE ~ PROD1 Run 100 its BTC, pick up XO to HYD 563 thread. RUH with 7" 29 # L-80 HYD 563 to 8698' 17:00 - 20:00 3.00 CEMT ~ PROD1 Circ. & cond. mud for cement. Reciprocate casing. Hold PJSM with rig crew, cementers and Peak drivers 20:00 - 22:30 2.50 CEMT :~ PROD1 Pump 5 bbls water, test lines to 3500psi. Pump 5 more bbls followed by 20 bbls CW 100 Chemical Wash then 50 bbls MudPush spacer. Drop bottom plug. Mix and pump 135 bbls., 12.0ppg.,CemCRETE Cement. Displace with 320bbls. Printed: 8/21/2001 3:57:28 PM BP EXPLORATION Page 6 of 7 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Activity Code NPT Phase Description of Operations 12125/2000 20:00 - 22:30 2.50 CEMT P PROD1 seawater. Reciprocated casing until 240 bbls displacement pumped. Bump plug wi 3500 psi. Hold for 5 minutes. Floats OK 22:30 - 00:00 1.50 CEMT P PROD1 PJD Dowell cmt head and equip. L/D landing Jt. 12/26/2000 00:00 - 00:30 0.50 CEMT P PROD1 Clear rig floor and clean up. 00:30 - 01:30 1.00 WHSUR P PROD1 Install FMC 7" packing. Run in lock down screws. Test pack off to 5000 psi. OK 01:30 - 02:30 1.00 BOPSUI;.P PROD1 Change rams to 3 1/2" X 6". 02:30 - 09:00 6.50 BOPSUI~ P PROD1 Test BOP 250 psi Iow and 3500 psi high. AOGCC rep. John Spalding waived witnessing test. 09:00 - 09:30 0.50 DRILL P PROD1 Service rig. 09:30 - 19:00 9.50 EVAL P PROD1 Rig up Schlumberger logging unit. PJSM. Run USlT cement evaluation log from 8605' to 3450'. Run repeat log from 8600' to 8300' & 7800' to 7000'. Apply 500 psi & log from 7800' to 7000'. POOH with e-line & PJD Schlumberger. 19:00 - 20:00 1.00 CASE P PROD1 PJU & pressure test 7" casing to 3500 psi for 30 minutes. Test was APl. 20:00 - 21:30 1.50 CASE P PROD1 Bullhead 100 bbl of 10.6 ppg mud down 7" x 9 5~8" casing annulus. Stage rate up to 4 bpm with 800 psi final injection pressure ( formation broke down with 400 psi ~ 1 bpm ). Line up Hot Oil & freeze protect 7" x 9 5/8" annulus with 60 bbl of crude oil. Pump rate 2.2 bpm with 1875 psi. Stop pumping. Had 850 psi back pressure. Secure annulus valve on wellhead. R/D Hot Oil truck. 21:30 - 22:00 0.50 RUNCOI~P COMP Held PJSM with rig crews prior to running 3.5" production tubing. Pull wear bushing. 22:00 - 00:00 2.00 RUNCOI~P COMP Run 3.5" 9.2~ L-80 NSCT Production tubing ( 2176' {~ midnight ). 12/2712000 00:00 - 06:00 6.00 RUNCOI~P COMP Run 3.5" 9.2# L-80 NSCT completion string as per program with 175 jts tubing, 4 GLM, 3 X-nipples, Baker "S-3" production packer. 06:00 - 08:30 2.50 RUNCO! P COMP P/U FMC 4.5" x 11" tubing hanger with one jt of 4.5" 12.6# L-80 MBTC tubing below hanger with XO to 3.5" NSCT. M/U in 3.5" tubing string. Land hanger with WLIG (~ 7696', top of Baker "S-3" packer @ 7639' RKB. RILDS. I./D Tubing landing joint. Install TWC in Tubing hanger. Test to 500 psi above & 1000 psi below with no problems. 08:30 - 12:00 3.50 BOPSUI: P COMP Nipple Down 13 5~8" 10M BOP and DSA flange. 12:00 - 14:30 2.50 WHSUR P COMP Nipple Up FMC 4 1/16" 5M Production Tree assembly. Test void to 5000 psi. Shell test tree with water to 5000 psi. All test were APl. 14:30 - 16:00 1.50 WHSUR P COMP R/U DSM Lubricator. Pull TWC valve. PJD Lubricator. 16:00 - 19:30 3.50 CHEM P COMP R/U circulating lines to wellhead & production tree. Test to 3500 psi. Reverse circulate seawater @ 3 bpm w/380 psi. Pumped 260 bbl of clean seawater + 139 bbl of corexit treated seawater. 19:30 - 20:30 1.00. CHEM P COMP Freeze protect 3.5" x 7" annulus. Reverse circulate 75 bbl of diesel down annulus @ 2.5 bpm. Stop pumping. Had 250 psi differential pressure. Let well U-Tube & equalize. 20:30 - 21:30 1.00 RUNCOI~ COMP Drop 1 5/16" packer setting ball-rod down 3.5" tubing and let gravitate to packer. 21:30 - 22:30 1.00 RUNCOI~ COMP Attempt to set packer. Pump down 3.5" tubing @ 3 bpm ( 5 bbl total ). Packer setting ball not seated. Printed: 8/21/2001 3:57:28 PM BP EXPLORATION Page 7 of 7 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Rig Name: NABORS 9E$ Rig Number: 9es Date From - To Hours ActivityCode l NPT Phase Description of Operations 12/2712000 22:30 - 00:00 1.50 RUNCOI~I WAIT COMP Wait on HES Slick line equipment to arrive at location ( Slick line will push packer setting ball to packer seat ). 12/28/2000 00:00 - 00:30 0.50 RUNCOI~I WAIT COMP Wait on slick line unit. 00:30 - 03:30 3.00 RUNCOI~P COMP Rig up HES slick line unit. 03:30 - 06:00 2.50 RUNCOI~ COMP RIH with 2.6" bell guide on 1 3/4" impression block + 9' of 1 7/8" wt bar + spang jar. Tag up ~ 3900' ( 70 deg inc ). Push packer setting ball-rod down to 7727' wlm. POOH. Hang off slick line tools. 06:00 - 07:30 1.50 RUNCOI~!3 COMP PJU Hot Oil Pump truck to well. Pressure up on 3.5" tubing to 3500 psi. Set BOT "S-3" packer & hold test on 3.5" tubing for 30 minutes. Line up on 7" x 9 5~8" annulus. Test same against packer to 3500 psi for 30 minutes. Both pressure test were APl. PJD Hot Oil. 07:30 - 08:30 1.00 RUNCOI~P COMP R/D Slick line equipment. Set BPV & Secure wellhead & tree. 08:30 - 10:00 1.50 MOB P PRE PJD & prepare for Rig Move. Released Nabors 9ES from well S-216 ~ 10:00 hrs on 12-28-00, Printed: 8/21/2001 3:57:28 PM 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 August 14, 2001 MWD Formation Evaluation Logs: S-216 POLARIS, AK-MM-00296 S-216 Polaris: 2"x 5" MD Gamma Ray Logs: 50-029-22989-00 1 Blueline 1 Rolled Sepia 2"x 5" TVD Gamma Ray Logs: 50-029-22989-00 2"x 5" MD Neutron & Density Logs: 50-029-22989-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 2"x 5" TVD Neutron & Density Logs: 50-029-22989-00 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim. Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED AU Z0 2001 Ala~ 011 & C.~s Cons. Cemmisa~ Well' S-216 Workover AFE:5M1012.1 Doyon 14 Classification: Rig Work Over AFE Amount: $ 560 M BP Exploration Days: 4.0 Estimated Workover Date: 8107/2001 Prepared By: Dave Wesley WELL OBJECTIVES: 1. Cut and pull the existing tubing from 7625'. 2. Replace the completion to restore mechanical integrity. 3. Change the tubing connection from NSCT to EUE 8RD- Mod, during completion. No portion of this work is so urgent that the time cannot be taken to do it without injuring yourself or others Approved By: Drilling Engineer (~ ~' Date- Distribution: Dan Stone Tony Bunch Phil Smith Well File Rig Doyon 14 Baker- Mail Slot Baroid - Mail Slot Doyon - Mail Slot Schlumberger- Mail Slot Contacts Drlg. Superintendent Senior Drilling Engr. Drilling Engineer Drilling Engineer Pad Engineer Name Tony Bunch Dan Stone Dave Wesley Phil Smith Donn Schmohr Senior Drilling Engineer Date 1 Copy 1 Copy 1 Copy 1 Copy Original 6 Full copies 1 Copy 1 Copy 1 Copy 1 Copy Work 564-5219 564-4002 564-5773 564-4897 Drilling Superintendent Date Attachments: Proposed Well Schematic Home 348-6683 348-0239 646-7873 783-2401 Cell 240-8051 240-8075 440-8631 240-8072 S-216 Sundry Subject: S.2t6 Sundry Date: Fri, 3 Aug 2001 13:17:45 -0500 From: "Stone, Dan M" <StoneDM@BP.com> To: "AOGCC-Tom Maunder (E-mail)" <tom_maunder~admin.state.ak.us> CC: "Wesley, Dave E" <WesleyDE@BP.com> Tom, sorry about the rush to get approval on the S-216 RWO sundry notice. This well came up quick due to the following: 1. The tree saver failed on the frac a couple weeks ago and frac fluid eroded a hole in the tubing just below the hanger. 2. At that time, it didn't look like we'd still be on "S" pad at this time so didn't think we'd do the workover to replace the tubing this round. 3. The Kuparuk river bridge repair project has experienced some schedule slippage so Doyon 14 will now be on "S" pad with sufficient time to do the workover. We anticipate moving Doyon 14 off the S-107i injection well 8/6 and would like to move to S-216 for the workover. Should be about a 4-5 day job. Appreciate your help in securing approval of the sundry for the S-216 workover to be able to start the workover operations 8~7. Thanks, Dan Stone I of 1 813101 9:24 AM (" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I-I Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown , Name of Operator BP Exploration (Alaska) Inc. , . Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface ,/' 4316' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 4508' NSL, 665' WEL, SEC. 03, T11N, R12E, UM At effective depth 4460' NSL, 676' WEL, SEC. 03, T11N, R12E, UM At total depth 4288' NSL, 722' WEL, SEC. 03, T11 N, R12E, UM [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate 5. Type of well: [] Development I-I Exploratory [] Stratigraphic I"1 Service [] Perforate [] Other 6. Datum Elevation (DF or KB) KBE = 64.52' 7. Unit or Property Name Prudhoe Bay Unit :8. Well Number S-216 9. Permit Number 200-197 v'" 10. APl Number 50- 029-22989-00 1. Field and Pool Prudhoe Bay Field / Polaris Pool 12. Casing Present well condition summary Total depth: measured 8712 feet V/ Plugs (measured) Top of Sand is at 8100' (07/01) true vertical 5624 feet Effective depth: measured 8100 feet Junk (measured) true vertical 5039 feet Length Size Cemented M D Structural Conductor 110' 20" 260 sx Arcticset (Approx.) 110' Surface 3542' 9-5/8" 479 sx Arcticset Lite III, 421 sx 'G' 3571' Intermediate Production 8672' 7" 207 sx Class 'G' 8698' Liner TVD 110' 2871' 5611' Perforation depth: measured 8000' - 8010', 8170'- 8190', 8320' - 8330' true vertical 4948' - 4957', 5105' - 5124', 5248' - 5257' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 to 7697' RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 7" x 3-1/2" Baker 'S-3' packer at 7639'; 3-1/2" HES SVLN at 2106' 13. Attachments [] Description Summary of Proposal I-I Detailed Operations Program [] BOP Sketch 4. Estimated date for commencing operation ~ 15. Status of well classifications as: August 4, 2001 16. If proposal was verbally approved [] Oil I-I Gas [] Suspended Service Name of approver Date Approved Contact Engineer Name/Number: Dave Wesley, 564-5773 Prepared By Name/Number: Terrie Hubble, 564.4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~---------"~__ ~ ,~=====~. Title Senior Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness Plug integrity BOP Test .~. Location clearance[ Approval Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission ~ ~.~..~ ~_~__'""~a~ ~ L Commissioner Date Submit In ~riplicate Current Well Information Well Name: APl Number: Well Type: Current Status: BHP: BHT: S-216 50-029-22989-00 Producer Tubing will be cut in full joint above packer at 7639'MD. 2516 psi @ 8315' MD / 5178' TVDss 101° F @ 8315' MD/5178'TVDss. Mechanical Condition: Tubing: 3-1/2" 9.2 ppf L80 NSCT TD / PBTD / Fill: TD 8713' MD/PBTD 8698' MD. Last tag was to 8067 ELM (FRAC overflush). Maximum Angle: Max Dogleg of interest: Well Head: Tbg. Spool: Tbg, Hanger: Tbg. Head Adapter: Tree: BPV Profile: SSSV: Control line clamps SS Control line bands: Open Peris: Tubing Fluids: Annulus Fluids: 7" Pack-off Test: MIT T x IA: 70.28° at 3873' MD. Well is S-shaped back to 14.82° at TD of 8713' MD. 7.15°/100' at 2411' MD FMC Gen 5; 11" 4%" 4 1/16" 5K CIW HES 3 %" 'X' Nipple (2.813") N/A N/A 8000 - 8010(open);( 8170 - 8190; 8320 - 8330 are sanded over) Sea water Sea water CMIT to 2500 psi conducted 7/29/01; passed. Completion: Materials Required for Workover Operations 7630' 1 - 7" x 4-1/2" 4 2 1 1 3.5", 9.2# L-80 EUE-8RD Mod Tbg Baker 'S-3' production packer 3 1/2" x 1-1/2" Camco 'MMG' 'GLM 3-1/2" 'X' Nipples 3-1/2" Custom overshot 4 %" Tubing Hanger; dressed w/NSCT Premium. Carbon adapter flange (If needed) Carbon tree (if needed) S-216 RWO Page 2 Short Scope S-216 failed during a FRAC stimulation on 7/07/01. The FRAC was aborted and over-flushed due to a loss in inner annular pressure and a subsequent tree saver failure. Diagnostics has identified a hole in the tubing pup just below the hanger. A deep mechanical failure is suspected as the cause of the inner annular pressure loss. Drilling Hazards and Contingencies ***See Pad Data Sheet for details of previous wells drilled on S Pad*** 1) Hydrogen Sulfide · S-Pad is not considered a H2S drill site. However, Standard Operating Procedures for H2S precautions should be reviewed and followed at all times. The most recent level of H2S measured on S-pad was 10 ppm; however, the highest H2S to date on S pad is 160 ppm. (See Pad Data Sheet). Reference: Hydrogen Sulfide under Standard Operating Procedures 2) Well Control Pressures · Production Section max anticipated BHP: · Production Section max surface pressure: · Planned completion fluid: 2516 psi (9.3 ppg EMW)@ 5178' TVDss 2000 psi (based on BHP & full gas column at 0.1 psi/fi) 9.8 ppg Brine Drilling Program Overview Surface Issues Rig Move Issues and Shut-in Requirements: The two neighboring wells to S-216 are S-200 (SB-01) which is 15' to the South and S-213, which is 30' to the North. Shut-in will be required of S-200 during rig move in and work over operations. Workover Fluid Program and Properties I Brine J Present Gasing/Tubing Program: Csgl Wt/Ft Grade Conn Length Top Btm Tbl] OD MD MD 9-5/8" 40# L-80 BTC 3573' Surface 3573' 7" Long Str. 29# L-80 BTC-M 8698' Surface 8698' 3 %" Tubing 9.2# L-80 NSCT 7696' Surface 7696' Proposed Tubing Program' -7600' S-216 RWO Page 3 . 2. 3. 4. 5. 6. ¢ S-216 RWO Detailed Operations Pre-Ri.q Operations Test the 7" mandrel packoff. Pull lowermost GLM valve. Circulate around seawater; load and kill tubing and inner annulus. Drift 3-112" tubing down to WLEG at 7697' MD. , 8. 9. 10. Set a plug in the 'X' nipple at 7685' MD. Test casing, tubing, annulus, plug to 2500 psi for 30 minutes. Record test. Chemical cut the 3-1/2" tubing @ 7625' MD (just above the packer @ 7639'md.) Freeze protect tubing & casing with diesel from 2000' to surface. Set a BPV and remove wellhouse. Clear and level pad in preparation of the rig move. Ri_~ Operations * Review the Hydrogen Sulfide Standard Operating Procedures prior to opening the well * * Complete a prs-rig inspection with the Pad Operator prior to the rig moving on the well * * Notify the AOGCC representative 24 hours in advance to witness BOP testing * 1. Note tubing and annular pressures and bleed-off as required prior to MIRU. 2. MIRU. RU to the tree to circulate out the diesel freeze protection. Pull BPV with lubricator. Confirm the amount of diesel used to freeze protect on the hand over form. Circulate out the diesel freeze protection and displace it with seawater. Confirm the well is dead. Install TWC and test from below to 1000 psi. Nipple down tree and adapter. Send tree and adapter in for inspection. The tree will be reused on this well if possible. NORM test all well head and retrieved completion equipment. Reference 'De-Completions' RP for details. 3. Nipple up and test the BOPE. Test the BOP equipment to 250 psi Iow, 4000 psi high. Test the annular to 250 psi Iow, 3500 psi high. Pull TWC with DSM lubricator. 4. Due to the washed out / eroded tubing pup just below the tubing hanger, it is recommended that the tubing be pulled via spear, rather than screwing into tubing hanger and subjecting the entire weight of the tubing string to the weakened pup joint. Pull tubing free from the pre rig cut at _ 7625' MD. Do not exceed 70% of the 3-1/2" tubing body tensile rating (141,500 lbs). NOTE: Estimated buoyed string weight in seawater down to the tubing cut is -62,000 lbs. If tubing cannot be pulled, work the tubing repeatedly in attempt to weaken the cut, and prepare for a second chemical cut if unable to pull free. 3-112" 9.2#, L-80 M-BTC Collapse Burst Tensile ID Make-up Torque 100% 10530 psi 10160 psi 202,220 lb 2.992" ID 70% 7371 psi 7112 psi 141,500 lb 2.867" drift 5. Pull and lay down the 4 1/2" tubing hanger. Send in hanger for replacement. Pull and LD the tubing from above the cut at +_ 7625' MD. Inspect all completion equipment for NORM. Reference: SSD Decompletion RP 6. RU Slickline 6" GR/JB and RIH to the top of cut tubing stub. Re-run as required if excessive debris is recovered. 7. Run +_ 7625' of 3-%" completion; 9.2 lb/fi, L-80 M-BTC tubing with custom overshot. Overshot should have at least 3' of swallow (6' preferred). References: SSD Custom Tubing Overshot Installation and Completion Design & Running RP's 8. See attached 'Proposed Completion Schematic for details. Reference: 'SSD RP Completion Design and Running S-216 RWO Page 4 3.112" 9.2#, L-80 M-BTC Collapse Burst Tensile ID Make-up Torque 100% 10530 psi 10160 psi 202,220 lb 2.992" ID 70% 7371 psi 7112 psi 141,500 lb 2.867" drift ** Use whatever thread compound is on the tubing, either "Mercasol Multi-Make White" or "Best-o-Life 2000" ** 9. Circulate at minimum rate while swallowing the tubing stub with the overshot and verify going over the stub by watching the pressure increase as the stub is swallowed by the packoff. Pick up off stub. 10. Slack off and swallow the tubing stub with the overshot and verify going over the stub by watching the pressure increase as the stub is swallowed by the packoff. Mark pipe when pressure increase is seen and when overshot no-goes on stub. 11. Space out the tubing on the down stroke to land in the wellhead with the overshot swallowing the tubing stub. Allow 2' of downward travel for when the packer sets when calculating the space out and marking the pipe. 12. Pick up off the stub and reverse circulate at least one full circulation clean seawater with corrosion inhibitor into the annulus, to ensure the returns are clean. 13. Set down and swallow the tubing stub with the overshot and land the tubing in the wellhead. RILDS. 14. PRIOR to setting the packer, make a drift run THROUGH the overshot, down to the WLEG to ensure clearance. 15. Run RHC ball seat to X nipple. The Sleeve should be set not to shear. RD slickline. 16, Prepare to set packer and shear RP valve. Drop ball / rod to RHC plug. The minimum packer setting pressure is 3,500 psi. Set the packer and test the tubing to 4,000 psi for 30 minutes. Slowly bleed the tubing down to 2,000 psi and pressure test the IA to 4000 psi. Bleed off the tubing pressure and shear the RP valve (set at 2500 psi). 17. Install two-way check. Test from below to 2500 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Pull two-way check with a lubricator. 19. Rig up to the tree to freeze protect well to +/-2200' MD. Reverse in freeze protection through the sheared RP valve. Hook up lines to the freeze protection manifold and allow diesel to u-tube. 20. 21. 22. Set and test BPV. Secure well. Rig down and release the rig. * Complete a post-rig inspection with the S Pad Operator prior to the rig moving off the well S-216 RWO Page 5 TREE= 4-1/16" CIW WELLHEAD= FMC 11" GEN 5 ACTUATOR= ? i~a. ELEV' = ....... 6415' BF. ELEV = ' ....... 36" KOP= .... '883' Max A'ngle = '- '70'@ 3873,' DatUm'MD 2- ' 8713' Datum TVD= 5626' 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" Id 3573' IMinimum ID = 2.813" (~ 2106' 3-1/2" HES X NIPPLE S-216 SAFETY NOTES 56' 1-14-1/2'x 3-1/2' XO, ID = 2.992" 2106' I-~3-~/2' HES X NiP, ID = 2.813" GAS LIFT MANDRELS I 3-1/2" 'I'BG, 9.2#, L-80 EUE-8RD MOD ID = 2.992" Id 7625' I3'1/2'' OvershOt I-I --~1 7605' 7615' Id7" x 4-1/2" BKR S-3 PKR, ID = 3.875"I Id 3-1/2" HES X NIP, ID: 2.813" 7639' Id7" x 4-1/2" BKR S-3 PKR, ID = 3.875"I 7664' l~3-1/2" HES X NIP, ID = 2.813" I 7685' I--~3-1/2" HES X NIP, ID = 2.813" I I 3-1/2" TBG, 9.2#, L-80 NSCT, .0087 bpf, ID = 2.992" Id 7696' PERFORATION SUMMARY REF LOG: SI=B~RY-SUN MWD MD ON 12/24100 ANGLE AT TOP PERF: 18 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 8000 - 8010 O 07102/01 2-1/2" 4 8170 - 8190 O 05/19/01 2-1/8" 4 8320 - 8330 O 04/02/01 I I-t 8698' 7696' I'~ ELMD'Ir LOGGED ON 04/02/01 I 7787' 8097' I-I 'ro. w/P,A I Id TOPOF20' PUPW/RA TAG I .0371 bpf, ID = 6.182" DATE REV .BY COMMI~I3S DATE REV BY COMMi~ITS 12/28/00 PGS ORIGINAL COMPLETION 07/13101 JLG/KAK ADI=EF~S I SAND DUMP 01/15101 SIS-SLT CONVERTED TO CANVAS 07/21/01 CH/TP CORRE-CTIONS 01/26/01 SIS-MD FINAL 07/31/01 DEW Proposed RWO Completion 04/08101 CH-RN/T~ CORRECTIONS 05/22/01 CS/KAK PERFS PRUDHOE BAY UNIT WELL: S-216 PIE~VIIT No: 200-197 APl No: 50-029-22989-00 Sec. 35, T12N, R12E, 4501' FEL, 4317' FSL BP Exploration (Alas ka) . L LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print{s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S} OR CD-ROM FILM COLOR Open Hole I I 1 , Res. Eval. CH I I 1 Mech. CH 1 2c0-1'~ 7 Caliper SurVey Signed' Print Name: Date · EECEIVED 'JUL 1 d 2o01 Alamlm Oil & Ga~ ~0ns. ~mammelon Anchorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memorvlog, com DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS TONY KNOWLES, GOVERNOR 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) £69-8800 FAX: (907) 269-8938 July 11,2001 ,ECEIVED JUL. 13 ~.001 Alaska Oil & Gas Cons. /~chorage BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, Alaska 99519-6612 Via Fax (564-4637) and Mail Attention: Gil Beuhler Central New Developments Manager Subject: Prudhoe Bay Unit Tract Operations for Wells S-201 and S-213 on ADL 28258, and'S-216'on ADL 28261 Dear Mr. Beuhler: Reference is made to your letter of July 10, 2001 regarding a request to continue Tract Operations for PBU Wells S-201 and S-213 on ADL 28258, and S-216 on ADL 28261. The Division approves your request to extend the Tract Operations for the three wells from July 11, 2001 until the first of the month following the issuance of the Polaris Participating Area final decision, but in no ease, later than September 1,2001. Sincerely, Mark D. Myers Director cc: Cammy Taylor- AOGCC Wade Fennel- Chevron PBU.PolarisWELLS.TOExtension.doc CO~'~M [(~1 _COMM COMM _SR RES;.EN.G RES LNG SR LNG -- _EENG NRO _ I SR GEOL GEOL _ GEOL ASST 'STAT TECH STAT TECH , · _ FILE __ "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." WELL LOG TRANSMITTAL To: State of Alaska May 30, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs S-216, AK-MM-00296 1 LDWG formatted Disc with verification listing. API#: 50-029-22989-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED 'JUN 01 2001 NaakaOil &Gas Coas.~ Anchorage OIL GAS May 24, 2001 Gil Beuhler Central New Development Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Subject: Application for Extension of Pilot Production Operations Well S-200; and Initial Production Operations at S-201, 213, and S-216 Prudhoe Bay Unit, Polaris Accumulation (Schrader Bluff Formation), ADL-028258 & 028261 File: Prudhoe Bay Field - Polaris Pool Dear Mr. Beuhler: The AOGCC has received an application from BP Exploration (Alaska) Inc. "(BP)" to .extend pilot production operations at the Polaris prospect, Prudhoe Bay Unit, at Well S-200 through July 31,2001 and to initiate pilot production operations at wells S~201, S-213, and S-216 for a period of six months from the start of production. The' request is based on the need for additional information to evaluate primary development and establish a depletion plan. On February 22, 2001, BP provided additional information to Jack Hartz, AOGCC Sr. Reservoir Engineer, regarding primary production and the anticipated pressure response during the extended production period. The AOGCC approved the original request for a waiver of the 'GOR limitations of 20 AAC 25.240 for production operations on S-200. The waiver of the GOR limitations is necessary to continue ~act and production operations at S-200, and for the initial tract and production operations at S-201, 213 and 216. Prior production reporting and allocation procedures are still applicable. Production should be reported to the 'Polaris Undefined Pool, number 640160. Your commitment to gather pressure data 'and maintain reservoir pressure above bubble point will ensure reservoir energy is not diminished prematurely. · The .evaluation work done, in progress, and planned surveillance will be sufficient to monitor well and reservoir performance for any adverse behavior. We anticipate you will keep the Commission informed about any significant developments. Therefore the Commission approves an extension of the Gas-Oil ratio variance through the end of July 2001 for well S-200, and for a period of six .months.from the start of production at wells S-201,213 and 216, conditioned on reservoir pressure performance.. AOGCC approval is coincident 'with any restrictions imposed by The Division of Oil & Gas on Tract or PA operations. Pressure data should be forwarded to the AOGCC after each survey or pressure test. If there are any questions please contact Jack Hartz at 279- 1433 ext. 232. Sincerely, ,' Copy: Mark Myers, DNR/DOG D.E. Dickinson, DOR Oil & Gas Audit PbuPolafisPilotOperations-RenewalSPad.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-197 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22989-00 4. Location of well at surface 9. Unit or Lease Name 4316' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM ""~'.... · Prudhoe Bay Unit At top of productive interval 4508' NSL, 665' WEL, SEC. 03, T11N, R12E, UM ' . 10. Well Number At total depth ,I-~;~'~'~;~' ''~;''' ~ ~,-J~ S-216 ~'"~ f"~-'-~ .......... 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Prudhoe Bay Field / Polaris Pool KBE = 64.52' ADL 028261 12. Date Spudded12/09/2000 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'l 2/22/2000 04/02/2001 115' water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 1 18. Plug Back Depth (MD+TVD) 119. Directional Survey120. Depth where SSSV set1 21. Thickness of Permafrost 8712 5624 FTI 8612 5528 FTI [] Yes [] NoI (Nipple) 2107' MDI 1900' (Approx.) '22. Type Electdc or Other Logs Run MWD, NEU, DEN, PWD, RES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES, USIT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 3571' 12-1/4" 479 sx Articset Lite III, 421 sx 'G' 7" 26# L-80 26' 8698' 8-3/4" 207 sx Class 'G' 24. Perforations ppen to. P.roducti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~nterva~, raze an(3 numoer~ SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/8" Gun Diameter, 2 spf 3-1/2", 9.2#, L-80 5216' 5159' MD TVD MD TVD 8320' - 8380' 5248' - 5257' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 bbls of Diesel 8320' - 8330' Frac'd w/39,561# of 16/20 Resin Polar Proppant 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 04/13/01 Gas Lift ~ate of Test Hours Tested PRODUCTION FOR OIL'BBL GAS'MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 4/28/2001 4 TEST PERIOD 0 360 20 176I 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-API (CORR) Press. 24-Hour RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit ¢o~¢~lpt E i V ED MAY 1 8 200l ORIGINAL Alaska 0il & Gas O0r'.,s. C0mmissi0n Anchorage , Form 10-407 Rev. 07-01-80 Submit In Duplicate ~29' Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Ugnu Ma Sand 7719' 4713' Na 7962' 4914' Nb 7981' 4931' Nc 8021' 4967' OA 8095' 5034' OBa 8147' 5083' OBf-Base 8450' 5372' 31. List of Attachmer~ts: Summary of Daily Ddlling Reports, SurveY, s, Formation Iniegrity Test ' ' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble~~ ~~_ Title TechnicalAssistant . Date S-216 200-197 Prepared By Name4Vumbec Sondra Stewman, 564 -4750 Well Number Permit No. /Approval N0. . . . 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 (DF, KB, etc.). I'ma 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 ORIGINAL '.~ :.. :"::.:""~'.~'.'". :.:~'-'~-'. :":':-.~.~<'.".':'.:'. "!:~. ':".-.:~..~.~'~::.'~'-:?!i'~?~:::':';:~i~':;, .'.'.== .. :. =,. i '...=',. ~'"..,.=.:.' ..'..' .' "'.".=... '....=~.. '. ......... . ,... '.." ":.:'=.. :'" ..:~: ':'=..!..i:':.' ..... . . ":' ..." '.- ' ' :~:~i~i::'i:i:: :i, ili.:.-.':i.:::i.: ii!i.". ::'i:..' i'!!!~:)?:'i!?:.:::?!'?i.- !::!!~i;:?~!:'i"!i!~:i"i:.'ii~'.'i~'~:-i~!~(i~~i~'.:':.' ''':':'~;''':': '".~:": ': ':?':"?:" :.'.:,i .=, .i.?~:,Le:a:k~Offi ':; TeS:t:. su.mm a ry ::-.,. ?':: ::: :-': .': Legal Name: S-216 Common Name: S-216 =. ' . ................. . .......... . .......... . .... , ....... 'AMW .' Surface Pressure Leak Off Pressure (BHP) EMW :.TeSt :Date ..: Test Type . ' ..... :'~' :='Te~ti';De'~ti1'i(TMD),,,',,ii,,,,i i.'.i..Test Depth (TV'D) ....... . ...!'. 12/19/2000 FIT 3,571.0 (ft) 2,870.0 (ft) 10.50 (ppg) 315 (psi) 1,880 (psi) 12.61 (ppg) Printed: 511/2001 1:41:18 PM BP EXPLORATION Page 1 of 6 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 12/8/2000 12:00 - 18:00 6.00 MOB PRE Prepare for Rig move. Drive rig off S-201 and move sub-base and mud pit modules to S-216. Spot pits and sub-base. R/U and interconnect modules. Spot cuttings tank. Accept rig at 18:00 hrs on Dec 8, 00. 18:00 - 19:00 1.00 RIGU PRE FUU Top-drive to handle 5" drill pipe. 19:00 - 19:30 0.50 RIGU PRE Held Pre-spud meeting with Rig crews. 19:30 - 00:00 4.50 RIGU PRE N/U 21 1/4" Hydril annular with no Diverter line onto 20" conductor. Take on drill water. Build spud mud. R/U to drill. 12/9/2000 00:00 - 02:00 2.00 RIGU PRE Finish installing Diverter turn buckles and mixing Spud mud. 02:00 - 07:00 5.00 RIGU PRE P/U 140 joints of 5" S-135 drill pipe and rack in derrick. 07:00 - 09:30 2.50 DRILL SURF M/U 12 1/4" drilling assembly. Orient UBHO sub. Adjust mud motor to 2.12 deg bend. 09:30 - 10:00 0.50 DRILL SURF Fill up hole with seawater. Check surface equipment for leaks-OK. R/U Sperry-Sun Gyre equipment. 10:00 - 10:30 0.50 DRILL SURF Held pre-spud meeting with rig crews. 10:30 - 20:30 10.00 DRILL SURF Spud well. Circulate and clean out 20" conductor from 104' to 110'. Drill 12 1/4" hole from 110'. Kick-offwell and drill directional building angle to 5 deg with a 254 deg azimuth as per gyre to 459' MD. 20:30 - 21:00 0.50 DRILL SURF Circulate bottoms up from 459'. 21:00 - 22:00 1.00 DRILL SURF POOH for BHA change. No hole preblems encountered. 22:00 - 00:00 2.00 DRILL SURF Inspect bit-OK. Adjust mud motor to 1.83 deg. P/U MWD. Orient same. P/U Flex drill collars to 295'. 12/1012000 00:00 - 01:00 1.00 DRILL SURF Finish M/U BHA #2. Fill drill string. Break cireulation. 01:00 - 00:00 23.00 DRILL SURF Drill 12 1/4" directional hole from 459' to 1547'. WOB 10-30K, RPM 30-40 w/5k torq., GPM 430-450 w11200 psi. P/U 95K, S/O 93K, ROT WT 94K. ART = 9.25 hrs, AST = 8.5 hrs. No Drag. No Losses. 12/11/2000 00:00 - 00:00 24.00 DRILL SURF Drill 12 1/4" directional hole from 1547' to 3227'. WOB 15-30k, RPM 30 wi 7k torque, GPM 503 w/1675 psi. P/U 11 lk, S/O 95k, Rot Wt 103k. ART = 7.75 hrs.AST = 9 hrs. No excess dreg. No losses. 12112/2000 00:00 - 05:30 5.50 DRILL SURF Directionally Drill 12.1/4 hole from 3,227 ft to 3,587 ft. No drag, No losses. Flowrate @ 500 GPM with lower mud vis. Final Angle (~ 69 degs inclin. ART= 3.75 hrs Top SV3 sand @ 3,300 ft MD, 2,773 ft TVD 05:30 - 06:30 1.00 DRILL SURF Circulate bottoms up @ 500 GPM/1570 psi. RPM @ 55/6,000 fflbs. Shakers clean. 06:30 - 07:30 1.00 DRILL SURF Make check trip to 1800 ft. Average Drag @ 20 klbs. Some 35 klbs @ 2400-2200 ft. 07:30 - 09:15 1.75 DRILL SURF RIH. taking weight @ 3,300 ft. Clean pick up weights. Work down. Acting like balled BHA. Rest of Hole good. 09:15 - 11:30 2.25 DRILL SURF Sweep Hole clean @ 500 GPM. Spot 250 bbl Casing Pill w! 5% Lubricant. Drop ESS. 11:30 - 17:00 5.50 DRILL SURF POH. 25K overpull @ 2150'. Pump and Backream as necessary to 1600', Dry Wiping every stand until nornal overpull then shut down pumps and continue POH. 17:00 - 19:30 2.50 DRILL SURF Stand back 5" HWDP & I./D BHA. 19:30 - 22:00 2.50 CASE SURF Clear Rig Floor. RJU 9 5/8 "Casing Running Tools. Make Dummy Run with 9 5~8" Mandrel Hanger and Landing Joint. 22:00 - 00:00 2.00 CASE SURF Hold PJSM with all personnel. M/U Shoe Track and RIH With 9 5/8" 40 !ppf, L-80, BTC casing per program. 12/13/2000 00:00 - 02:00 2.00 CASE SURF Run 9.5~8", 40 Ib/ft, BTC casing to 1,610 ft. Held Up. 02:00 - 05:30 3.50 CASE TGHT SURF Attempt to work down pipe- No progress. Clean Pick ups. Attempt to cireulate down- no go. 05:30 - 08:30 3.00 CASE TGHT SURF Unable to progress pipe OOH. Connector hanging up on bottom of 20" conductor pipe. Rock pipe, Remove slips. No GO. Rig not centred Printed: 1/2612001 4:33:18PM BP EXPLORATION Page 2 of 6 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Phase Description of Operations Date From-To Hours Task Code 12/13/2000 .05:30 - 08:30 3.00 CASE TGHT SURF correctly. Rotate casing. RIH to see if 9.5/8" would go to bottom with new orientation- No GO. POOH. Prepare to Pump Dry job and L/O joint. Hole conditions deterioating 08:30 - 14:30 6.00 CASE REAC SURF Hole conditions deteriorate.Window of movement reduced from 15 ft to 2 ft- Loose all circulation. Work Pipe from 300 klbs ( 200 klbs overpull) down to 40 klbs. No further movement. 9./8" shoe @ 1,580 ft.Vis up mud system to 300. CBU with losses- no change. Pull up to 450 klbs ( :350 klbs overpull). Some minor indications of movement. 14:30 - 16:00 1.50 CASE TGHT SURF Pull 9.5/8" casing free and regain ful circulation. Circulate Bottoms Up. No excessive gravel seen @ surface. L/O joint and gained 60 bbls while pumps off ( Formation giving losses back). 16:00 - 23:00 7.00 CASE FILL SURF Cont. working pipe, able to rotate. Pull 1 Jt. with minimum overpull. Pump Dry Job & Cont. POH. All 9 5/8" Casing collars hanging up on 20" Conductor shoe. Having to work and turn string to pass collars. Pulled total 23 Jts 9 5/8" casing. 23:00 - 00:00 1.00 CASE SKID SURF Attempt to align Rig Closer to Center of Hole Prior to pulling 9 5/8" Casing Cetralizers through 20" Conductor Shoe. 12/14/2000 00:00 - 01:30 1.50 CASE TGHT SURF Continue to align rig. 01:30 - 06:00 4.50 CASE TGHT SURF Lay out remainder of 9.5/8" casing. Heat Float collar. Standback First two joints. One centraliser missing. Total 40 joints Laid out and placed to one side for inspection. 06:00 - 08:30 2.50 CASE TGHT SURF Rig down casing handling equipment. Clear rigfloor and clean up rig. 08:30- 10:30 2.00 CASE :TGHT SURF Make up 12" Hole Opener assembly. 10:30 - 11:30 1.00 CASE SURF Injury to Thoma Palm. Shut down rig and debrief incident. Hold Safety meeting with both crews. 11:30-15:00 3.50 CASE ~TGHT SURF RIH to1400 ft. Wash/ Ream down to1540 ft. No progress. VaryRPM( 0-110), Vary Flowrate ( 0 to 550 GPM). Appears as if bullnose burying into side of hole. No rapid flucuations in torque. 15:00 - 18:00 3.00 CASE TGHT SURF POH w/12 1/4" Hole OpenerAssy. 18:00 - 20:30 2.50 CASE TGHT SURF RIH with 12 1/4" Bit and Directional Assy. Survey and Orient @ 1450' Cont. RIH to 1530' - Held Up. 20:30 - 00:00 3.50 CASE TGHT SURF Oriented and washed 12 1/4" Hole from 1530' to1565', Washed and Reamed from 1565' to 2169'. Some tight spots - Correlated very well with shale stringers on Sperry LWD Gamma Ray Log. Worked through all tight spots thoroughly. 12/15/2000 00:00 - 02:30 2.50 CASE STAB SURF Wash/Ream to bottom @ 3,587 ft. Minor tight spots correlating with clays. 02:30 - 05:00 2.50 CASE STAB SURF Circulate bottoms up @ 500 GPM/1600 psi. Not much back across shakers. 05:00 - 06:30 1.50 CASE STAB SURF POOH to 2,600 ft. Average drag ~ 20 klbs. 06:30 - 10:30 4.00 CASE STAB SURF Unable to progress OOH without pumps/RPM. Appears to be combination of Swelling clays and/or Cutting beds (gravels). Pump required back to 1700 ft. 10:30 - 13:00 2.50 CASE STAB SURF Lay down Drilling/Cleanout assembly. 13:00 - 15:00 2.00 CASE STAB SURF M/U Smith 12.1/4" Hole opener assembly. 15:00 - 16:30 1.50 CASE SURF Slip & Cut Drilling Line and Service Top Drive 16:30 - 17:30 1.00 CASE STAB SURF Cont. RIH w/H/O, HWDP & 5' DP to 1925- Held Up could not work through dry. 17:30 - 23:00 5.50 CASE STAB SURF Wash & Ream with Hole Opener fron 1925' to TD @ 3587' with 616 gpm of 10 ppg, 300 Vis.,68 yield point Mud at 135 to 140 RPM. Large amount of cuttings seen over the shakers while reaming. 23:00 - 00:00 1.00 CASE STAB SURF Circulate 10.3 ppg Hi Vis Barofibre Sweep. Work and rotate pipe @ Printed: 1/26/2001 4:33:18PM BP EXPLORATION Page 3 of 6 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 12/15/2000 23:00 - 00:00 1.00 CASE STAB SURF 140-145/3000 ftlbs. 620 GPM/1300 psi. Cuffings seen at surface. 12/1612000 00:00 - 02:30 2.50 CASE STAB SURF Circulate and condition hole @ 620 GPM/1300 psi w/Hi Vis, Barofibre sweep. Circulate shakers clean. Work and rotate pipe @ 145 RPMI ;3000 ftlbs. Spot Casing pill wi 5% lubricants. Final Vis = 200. 02:30 - 04:00 1.50 CASE STAB SURF POOH. Work/Wipe out one tight spot @ 2,600 ft. Rest of hole slick. 04:00 - 06:30 2.50 CASE STAB SURF L/O Smith 12.1/4" Hole Opener and flex collars. Clear rigfloor. 06:30 - 09:00 2.50 CASE SURF PJU to run 9.5/8" Casing. M/U Franks Fill Up Tool and casing !equipment. PJSM. 09:00 - 14:30 5.50 CASE SURF Run 9.5/8", 40 Ib/ft, BTC casing. Check floats and bakerlock shoetrack. . No resistance until 2,700 ft. 14:30 - 18:30 4.00 CASE TGHT SURF Work 9.5~8" casing with/without circulation. Slack off everything but Top i drive weight and vary circulation rates from 100-240 GPM/350 psi. Broke thru @ 3,165 ft. Suspect hole geometry ( 52 degs ~ 2,700 ft to 69 degs @ 3,100 ft). Clean pick ups. 18:30 - 19:30 1.00 CASE SURF Run remander of 9.5/8" casing washing down last two joints. Land 9.5~8" casing @ 1930 hrs. 87 joints, 40 Iblft, L-80, BTC casing. Shoe @ 3,572 ft MD/2,872 ft TVD. 19:30 - 22:00 2.50 CASE SURF Circulate & Condition Mud for Casing. PJU Dowell. Circulate @ 10 BPM1600 psi. Drop vis to 70. 22:00 - 22:30 0.50 CASE SURF Hold PJSM - Rig Crew & all Service Company Personnel. 22:30 - 00:00 1.50 CASE SURF Test Dowell lines to 3500 psi Batch Mix & Pump 75 bbls 10.4 ppg. MudPush Spacer then Mix & Pump 378 bbls, 10.7 ppg Lead Slurry followed by 20 bbls, 15.8 ppg Tail Slurry ( Incomplete ). 12/17/2000 00:00 - 01:00 1.00 CEMT SURF Completed pumping Tail slurry: total - 83 bbls, 15.8 ppg. Dropped plug and displaced: 2 bbls cmt and 8 bbls water with Dowell followed by 257 bbls mud with Rig. Bumped plug w/3500 psi. Fullreturns throughout job. 35 bbls cement - contaminated mud followed by 40 bbls Good 10.7ppg. Lead Slurry to Surface. 01:00 - 05:30 4.50 BOPSUIq SURF I. JD Landing Jt., Clean out Riser, Diverter. Clean Floor and cellar. Ship out Cmt. tools, change bails,N/D 20" Riser, 05:30 - 11:00 5.50 WHSUR COMM SURF While attempting to remove 20" Diverter from cellar;Forklift hit Diverter Skid sending it falling into the cellar: striking and damaging the 9 5~8" casing mandrel seal assembly. Shut down Rig for incident investigation then formulate plan and carry out subsequent removal of Diverter. 11:00 - 18:00 7.00 WHSUR COMM SURF Coordinate with FMC Representative re. Repair. Got Wayne Simmons, Arctic Fabricators on site to facilitate repair; heated ,straightened mandrel, installed csg.head & made 4 welding passes on inside seal area. Post heated and blanketed csg.head. 18:00 - 00:00 6.00 WHSUR COMM SURF Slowly cool csg.head - Temp @ 00:00 Hrs.- 195 deg. 12/1812000 00:00 - 05:00 5.00 WHSUR COMM SURF Wait on Casing head to cool checking hourly. 05:00 - 10:00 5.00 BOPSUI~ SURF Nipple up Tubing spool, BOPE and bell nipple. 10:00 - 11:15 1.25 BOPSUI~ SURF Test 9.5/8" casing and wellhead weld in stages up to 3500 psi- Good Test. 3.6 bbls pumped/returned. 30 minute test. 11:15 - 15:00 3.75 BOPSUF PROD1 Test BOPE - 250 psi Low / 3500 psi High - Hydril, Rams, choke & kill lines and valves, Top Drive and all surface equip. Witness of BOP Test waived by Chuck Scheve, AOGCC 15:00 - 15:30 0.50 BOPSUI: PROD1 Rig down test equip., install wear ring. 15:30 - 19:30 4.00 DRILL PROD1 M/U BHA # 6, 8 3/4" Steerable wi 1 deg. fixed bent housing. PJSM prior to Sperry installing nuclear source. 19:30 - 23:00 3.50 DRILL PROD1 RIH w/HWDP and 5" DP past Tam Port Collar, no problem, P/U 60 5" Printed: 1/26/2001 4:33:18 PM BP EXPLORATION Page 4 of 6 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Task Sub Phase Description of Operations Code 12/18/2000 19:30 - 23:00 3.50 DRILL PROD1 DP singles and stand back. Bit @ 3000 ft. 23:00 - 00:00 1.00 DRILL PROD1 Held Stripping Drill 12/1912000 00:00 - 01:30 1.50 DRILL PROD1 RIH, PIU 5" DP singles and run to 3293'. 01:30 - 02:00 0.50 DRILL PROD1 Service top drive 02:00 - 04:30 2.50 DRILL PROD1 Drill float collar at 3487', cement and float shoe at 3571'. Drill 20' of new hole to 3607'. 04:30 - 06:30 2.00 DRILL PROD1 CBU & displace hole with new 10.5 ppg LSND Mud. 06:30 ~ 07:00 0.50 DRILL PROD1 Perform FIT with 10.5 ppg. mud in hole. Pressure 315 psi = EMW of 12.61. 07:00 - 21:30 14.50 DRILL PROD1 Directional Drill 8 3~4" Hole from 3607' to 5070'. WOB= 5-10 K RPM-- 80. GPM= 550. PSI--1790 AST - 2.5 hrs, ART - 8.5 hrs. 21:30 - 22:30 1.00 DRILL PROD1 Circ. 30 bbl Hi Vis wieghted sweep 22:30 - 00:00 1.50 DRILL PROD1 Make 16 stand wiper trip to 9 5~8" Csg. shoe. 30K to 40K overpull between 4220 and 4178; worked through and wiped clean. Rest of hole very smooth - max overpull 20K. 12120/2000 00:00 - 00:30 0.50 DRILL PROD1 RIH after 16 stand wiper trip to shoe. No fill 00:30 - 18:30 18.00 DRILL PROD1 Directional Drill 8 3~4" Hole from 5070' to 6752'. WOB-- 5-10 K RPM= 80-85. GPM= 550. PS1=1950 AST - 1 hrs, ART - 5.5 hrs. 18:30 - 19:00 0.50 DRILL PROD1 CBU with wieghted HI Vis sweep. 19:00 - 21:00 2.00 DRILL PROD1 Wiper trip to 5000', max pull - 40K over from 4220' to 4178' wiped clean with one dry pass. Normal drag - only 10 -20 K, Smooth hole. RIH to 6659, wash to 6752 -no fill. Slick Hole. 21:00 - 00:00 3.00 DRILL PROD1 Directional Drill 8 3/4" Hole from 6752' to 6938". WOB: 5-15, RPM: 80-85, GPM: 575, PSI: 2220 AST: 1 ART: 5.5 12/21/2000 00:00 - 00:00 24.00 DRILL PROD1 Drill 8 3/4" directional hole from 6938' to 8254' WOB: 5 -15 K, RPM: 80 - 90, GPM: 550 - 575 PSI: 2220 -2600. AST: 7 HRS, ART: 8 HRS. 12/22/2000 00:00 - 06:30 6.50 DRILL PROD1 Drill 8 3/4" directional hole from 8254' to 8712' TD WOB: 5 -15 K, RPM: 80 - 90, GPM: 550 - 575 PSI: 2220 -2600. AST: 1 HRS, ART: 4 1/2" HRS. 06:30 - 08:30 2.00 DRILL PROD1 Circulate and condition mud. Sweep hole with high vis weighted pill. 08:30 - 12:30 4.00 DRILL PROD1 POH to 9 5/8" casing shoe. 25K over pull 8712' to 7500' 12:30 - 14:00 1.50 DRILL PROD1 Slip and cut drilling line. Service rig. 14:00 - 16:30 2.50 DRILL PROD1 RIH from 3570' to 8500'. Wash to TD @ 8712 - No Fill. No Tight spots. No reaming necessary 16:30 - 19:30 3.00 DRILL PROD1 Pump Hi Vis weighted sweep, circ. & cond. mud for logs. Drop Sperry ESS. Pump slug. 19:30 - 00:00 4.50 DRILL PROD1 POH. Hole slick, minimum overpull of 10 to 20 K. inc. 12/23/2000 00:00 - 01:00 1.00 DRILL PROD1 POH. SLM. Stand back HWDP. 01:00 - 04:00 3.00 DRILL PROD1 Lay down BHA. Down load MWD. PJSM. remove radio active sauces. Lay down BH^. Clear floor. 04:00 - 07:30 3.50 EVAL PROD1 PJSM. With rig and Schlumberger crews. Pick up Schlumberger Platform Express logging tools. Make up Down Hole wet Connect and connect to 5" drill pipe. 07:30 - 09:30 2.00 EVAL PROD1 RIH with 5" drill pipe and logging tools to 9 5~8" casing shoe. 09:30 - 10:30 1.00 EV^L PROD1 Circulate at casing shoe. Rig up Schlumberger upper sheav and E-line. 10:30 - 13:00 2.50 EVAL PROD1 RIH slowly to 5200'. Fill pipe and circulate every 5 stands. 13:00 - 14:30 1.50 EVAL PROD1 Connect Side Door Entry Sub to 5" drill pipe. PJSM. RIH with E-line and latch into wet conect. Good connection. Printed: 1/2612001 4:33:18PM BP EXPLORATION Page 5 of 6 Operations Summa Report Legal Well Name: S-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Phase Description of Operations Date From-To Hours Task Code 12/23/2000 14:30 - 00:00 9.50 EVAL PROD1 RIH with 5" drill pipe and logging tools DPC (TLC) log down from 5199' to 8694'. Log POH. Repeat from 8100 back down to 8600'. Continue logging up to 5800' ( Incomplete).Good Logs. No tool or hole problems. 12/24/2000 00:00 - 00:30 0.50 EVAL PROD1 POH 5" drill pipe with logs to SDES. 00:30 - 02:00 1.50 EVAL PROD1 Remove cable clamp. Pull out of down hole wet connect and POH with E-line. Rig down E-line and sheaves. 02:00 - 04:00 2.00 EVAL PROD1 POH 5" drill pipe with logging tools. 04:00 - 06:00 2.00 EVAL PROD1 PJSM. Lay down logging tools. 06:00 - 07:00 1.00 DRILL PROD1 Make up BHA # 7 for clean out trip. 07:00 - 11:30 4.50 DRILL PROD1 RIH with clean out assembly. Fill pipe at shoe and at 6500'. Wash last 68' to bottom as precaution. No fill. 11:30 - 16:30 5.00 DRILL PROD1 Circulate and condition mud. Spot 382 bbl casing pill in open hole. 16:30 - 20:30 4.00 DRILL PROD1 POH, Stand back 34 stands, lay down remainder. 20:30 - 21:30 1.00 DRILL PROD1 Slip & Cut Drilling Line. 21:30 - 00:00 2.50 DRILL PROD1 Continue POH L/D 5" DP, Stand back HWDP, L/D BHA 12/25/2000 00:00 - 00:30 0.50: DRILL PROD1 Pull wear bushing. 00:30 - 02:00 1.50! CASE PROD1 Change top rams to 7" and test bonnets to 3500 psi. 02:00 - 02:30 0.50 CASE PROD1 Pick up 7" landing joint and make dummy run 02:30 - 04:30 2.00 CASE PROD1 Rig up to run 7" casing. PJSM 04:30 - 10:00 5.50 CASE PROD1 Run 7" 29 # -80 BTC casing, check floats, install two pup joints with RA tags and RIH to 9 5/8" casing shoe. 10:00 - 10:30 0.50 CASE PROD1 Circulate 1.5 times casing volume. 10:30 - 17:00 6.50 CASE PROD1 Run 100 jts BTC, pick up XO to HYD 563 thread. RUH with 7" 29 # L-80 HYD 563 to 8698' 17:00 - 20:00 3.00 CEMT PROD1 Circ. &cond. mud for cement. Reciprocate casing. Hold PJSM with rig crew, cementers and Peak drivers 20:00 - 22:30 2.50 CEMT PROD1 Pump 5 bbls water, test lines to 3500psi. Pump 5 more bbls followed by 20 bbls CW 100 Chemical Wash then 50 bbls MudPush spacer. Drop bottom plug. Mix and pump 135 bbls., 12.0ppg.,CemCRETE Cement. Displace with 320bbls. seawater. Reciprocated casing until 240 bbls displacement pumped. Bump plug w/3500 psi. Hold for 5 minutes. Floats OK 22:30 - 00:00 1.50 CEMT PROD1 R/D Dowell cmt head and equip. L/D landing Jt. 12/26/2000 00:00 - 00:30 0.50 CEMT PROD1 Clear rig floor and clean up. 00:30 - 01:30 1.00 WHSUR PROD1 Install FMC 7" packing. Run in lock down screws. Test pack off to 5000 psi. OK 01:30 - 02:30 1.00 BOPSUI: PROD1 Change rams to 3 1/2" X 6". 02:30 - 09:00 6.50 BOPSUF PROD1 Test BOP 250 psi Iow and 3500 psi high. AOGCC rep. John Spalding waived witnessing test. 09:00 - 09:30 0.50 DRILL PROD1 Service rig. 09:30- 19:00 9.50 EVAL PROD1 Rig up Schlumberger logging unit. PJSM. Run USIT cement evaluation log from 8605' to 3450'. Run repeat log from 8600' to 8300' & 7800' to 7000'. Apply 500 psi & log from 7800' to 7000'. POOH with e-line & R/D Schlumberger. 19:00 - 20:00 1.00 CASE PROD1 R/U & pressure test 7" casing to 3500 psi for 30 minutes. Test was APl. 20:00 - 21:30 1.50 CASE PROD1 Bullhead 100 bbl of 10.6 ppg mud down 7" x 9 5/8" casing annulus. Stage rate up to 4 bpm with 800 psi final injection pressure ( formation broke down with 400 psi @ 1 bpm ). Line up Hot Oil & freeze protect 7" x 9 5/8" annulus with 60 bbl of crude oil. Pump rate 2.2 bpm with 1875 psi. Stop pumping. Had 850 psi back pressure. Secure annulus valve on wellhead. R/D Hot Oil truck. 21:30 - 22:00 0.50 RUNCO~ COMP Held PJSM with rig crews prior to running 3.5" production tubing. Pull wear bushing. Printed: 1/26/2001 4:33:18PM BP EXPLORATION Page 6 of 6 Operations Summa Report Legal Well Name: 8-216 Common Well Name: S-216 Spud Date: 12/9/2000 Event Name: DRILL+COMPLETE Start: 12/8/2000 End: Contractor Name: NABORS Rig Release: 12/28/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Phase Description of Operations Date From-To Hours Task Code 12/26/2000 22:00 - 00:00 2.00 RUNCOI~! COMP 'Run 3.5" 9.2# L-80 NSCT Production tubing ( 2176' @ midnight ). 12/27/2000 00:00 - 06:00 6.00 RUNCOI~! COMP Run 3.5" 9.2# L-80 NSCT completion string as per program with 175 jts tubing, 4 GLM, 3 X-nipples, Baker "S-3" production packer. 06:00 - 08:30 2.50 RUNCOI~ COMP P/U FMC 4.5" x 11" tubing hanger with one jt of 4.5" 12.6# L-80 MBTC tubing below hanger with XO to 3.5" NSCT. M/U in 3.5" tubing string. Land hanger with WLIG @ 7696', top of Baker "S-3" packer @ 7639' RKB. RILDS. L/D Tubing landing joint. Install TWC in Tubing hanger. Test to 500 psi above & 1000 psi below with no problems. .08:30 - 12:00 3.50 BOPSUI; COMP Nipple Down 13 5/8" 10M BOP and DSA flange. 12:00 - 14:30 2.50 WHSUR COMP Nipple Up FMC 4 1/16" 5M Production Tree assembly. Test void to 5000 psi. Shell test tree with water to 5000 psi. All test were APl. 14:30 - 16:00 1.50 WHSUR COMP R/U DSM Lubricator. Pull TWC valve. R/D Lubricator. 16:00 - 19:30 3.50 CHEM COMP R/U circulating lines to wellhead & production tree. Test to 3500 psi. Reverse circulate seawater @ 3 bpm w/380 psi. Pumped 260 bbl of clean seawater + 139 bbl of corexit treated seawater. 19:30 - 20:30 1.00 CHEM COMP Freeze protect 3.5" x 7" annulus. Reverse circulate 75 bbl of diesel down annulus @ 2.5 bpm. Stop pumping. Had 250 psi differential pressure. Let well U-Tube & equalize. 20:30 - 21:30 1.00 RUNCOI~ COMP Drop 1 5/16" packer setting ball-rod down 3.5" tubing and let gravitate to packer. 21:30 - 22:30 1.00 RUNCOI~ COMP Attempt to set packer. Pump down 3.5" tubing @ 3 bpm ( 5 bbl total ). Packer setting ball not seated. 22:30 - 00:00 1.50 RUNCOI~I'RAN COMP Wait on HES Slick line equipment to arrive at location ( Slick line will ' push packer setting ball to packer seat ). 12/28/2000 00:00 - 00:30 0.50 RUNCOI~RAN COMP Wait on slick line unit. 00:30 - 03:30 3.00 RUNCOI~ COMP Rig up HES slick line unit. 03:30 - 06:00 2.50 RUNCOI~ COMP RIH with 2.6" bell guide on 1 3/4" impression block + 9' of t 7/8" wt bar + spang jar. Tag up @ 3900' ( 70 deg inc ). Push packer setting ball-rod down to 7727' wlm. POOH. Hang off slick line tools. 06:00 - 07:30 1.50 RUNCOI~ COMP R/U Hot Oil Pump truck to well. Pressure up on 3.5" tubing to 3500 psi. Set BOT "S-3" packer & hold test on 3.5" tubing for 30 minutes. Line up on 7" x 9 5/8" annulus. Test same against packer to 3500 psi for 30 minutes. Both pressure test were APl. R/D Hot Oil. 07:30 - 08:30 1.00 RUNCOI~ COMP R/D Slick line equipment. Set BPV & Secure wellhead & tree. 08:30 - 10:00 1.50 MOB PRE R/D & prepare for Rig Move. Released Nabors 9ES from well S-216 @ 10:00 hrs on 12-28-00. Printed: 1/26/2001 4:33:18PM OriginaIWell: S-216 Field: Prudhoe Bay Field / Polaris Pool APl: 50-029-22989-00 Permit: 200-197 Date Post-Ri9 Work 04/02/2001 Ran 2.50" X 11" Dummy Gun to 8568' WLM. RDMO. RIH w/GR and 10' EJ 2-1/8" BH 2 SPF, Logged jewelry and perforated 8320' - 8330' 90 degrees right, EOT logged at 7696'. RIH w/CCL and 10' EJ 2- 1/8" BH 2 SPF perforated 8320' - 8330' 90 degrees left. RIH w/PRESS/TEMP, stop at 8315' for 7 hrs, BHP 2516.821 PSI, 101 DEGF. Log 8320' - Surface at 120 FPM. Correlated to Sperry Sun MWD MD Log dated 12/24/00. Deviation at perf. depth 18 degrees. No problem getting past max deviation of 70 degrees - in hole with rollers. Perform 250 bbl data FRACS at 20 BPM. FRAC Schrader w/295 bbls YF140D Fluid and 39,561# 16/20 Resin Polar Prop. Screened out 52 bbls into 10 PPA stage left 25,958# prop in pipe and 13,603# behind pipe. Recovered tree saver cups. Squeezed in 5 bbls MEOH into tree for F/P. Well shut in. 04/03/2001 MITIA Passed to 3000 PSI, Pre-Frac 04/07/2001 MIRU; Drift New Coil with 1.00" Ball; PT stack and hardline; continue on next day WSR FCO. 04/08/2001 RIH with 1.75" Stinger and DJ nozzle pumping 2% KCL at 1.5 BPM; Hit bridge at 562'; appear to going into sand at 4461 '; Clean out down to 8430' (100' below PERFS.); POOH at 80%; Washing mandrel on the way out; freeze protect to 2500' with 60/40 FCO. 04/09/2001 Ran 2.70" centralizer. Sat down at 2947' WLM. No spangs. Pulled 1000# to get free. POOH ran 5' x 2.50" bailer. Sat down at 2970' WLM. No SPANGS. POOH small amount of FRAC sand in bailer. Set catcher at 2725' WLM. Pulled 1-1/2" DGLV and RK from STA #4 at 2666' WLM and installed 1-1/2' OGLV and RK (5/16" Port). Pulled catcher. RDMO. Left well shut in. 04/20/2001 Drift w/2.75" CENT, tag fill at 8475' WLM, set X-LOCK catcher sub at 7679' WLM, Pulled side pocket memory gauge from STA #1 at 7562' WLM, Left well shut in. 10202616824 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-2f6 S-216 Surveyed: 22 December, 2000 DEP/N T VE S UR VEY REPORT 12 January, 2001 Your Ref: AP1500292298900 Surface Coordinates: 5980520.26 N, 618929.71 E (70° 21' 19.4406" N, Kelly Bushing: 64.52fl above Mean Sea Level 149' 02' 03.0221" W) · CO ORILL. INI; Sun~ey Ref: svyfO?08 A Hllllburton Complny Sperry-Sun Drilling .Services Survey Report for S-216 Your Ref: AP1 500292298900 Surveyed: 22 December, 2000 .. North Slope Alaska Measured Depth Incl. (ft) Azim. Sub-Sea Depth fit) Vertical Local Coordinates Global Coordinates Depth Northings Eaetinge Northings Eaetings fit) (ft) fit) fit) fit) Dogleg Rate (°/100ft) Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment S-2f6 PGSS 0.00 0.000 0.000 -64.52 0.00 132.00 0.000 0.000 224.00 1.500 273.000 317.00 3.500 260.000 409.00 5.000 254.000 67.48 159.47 252.38 344.12 132.00 223.99 316.90 408.64 0.00 N 0.00 N 0.06 N 0.37 S 1.96 S 0.00 E 0.00 E 1.20 W 5.21 W 11.83 W 5980520.26 N 618929.71E 5980520.26 N 618929.71E 5980520.30 N 618928.51E 5980519.81N 618924.50 E 5980518.11N 618917.91E 0.00 1.63 2.22 1.70 0.00 Surface Tolerable Gyro 0.00 0.27 1.77 5.10 TIE ON POINT S-216 511.86 5.960 253.470 604.90 7.010 241.910 696.49 7.530 233.710 789.63 7.930 229.630 882.73 9.980 217.000 446.51 538.96 629.81 722.11 814.08 511.03 603.48 694.33 786.63 878.60 976.63 11.060 211.220 906.40 970.92 1070.22 11.250 217.360 998.22 1062.74 1164.31 10.370 222.630 1090.65 1155.17 1259.22 10.850 228.910 1183.94 1248.46 1353.01 12.330 230.800 1275.81 1340.33 1445.16 15.290 227.440 1365.29 1429.81 1540.12 15.850 226.680 1456.76 1521.28 1633.84 15.730 225.770 1546.95 1611.47 1726.06 17.180 219.960 1635.40 1699.92 1817.97 20.740 210.690 1722.32 1786.84 4.71 8.76 14.95 22.72 33.32 47.53 62.46 75.99 88.14 100.27 114.71 132.08 149.72 168.88 193.29 S S S S S .: 21.2~ W 30.90 W 40.67 W 50.48 W 60.23 W 69.80 W 79.99 W 91.30 W 103.82 W 118.23 W 134.81 W 153.47 W 171.88 W 189.59 W 206.62 W 5980515.21N 618908.53 E 5980511.01N 618898.95 E 5980504.67 N 618889.28 E 5980496.74N 618879.59E 5980485,98 N 618870.01E 5980471.63 N 618860.67 E 5980456.64N 618850.72 E 5980442.83 N 618839.63 E 5980430.48 N 618827.31E 5980418.12 N 618813.09 E 5980403.42 N 618796.74E 5980385.76N 618778.36 E 5980367.83 N 618760.23 E 5980348.39 N 618742.83 E 5980323.71N 618726.18 E 0.93 1.80 1.27 0.73 3.O4 1.61 1.28 1.41 1.32 1.63 3.33 0.63 0.29 2.38 5.06 10.30 16.82 25.42 35.56 48.41 64.68 81.82 97.90 113.00 128.59 146.98 168.76 190.73 213.98 242.10 AK-6 BP_IFR-AK 12 January, 2001.11:02 Page 2 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-216 Your Ref: AP1500292298900 Surveyed: 22 December, 2000 North Slope Alaska Measured Depth (rt) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1911.84 24.440 198.690 1809.02 1873.54 1942.45 24.740 196.900 1836.86 1901.38 2005.28 25.150 194.350 1893.83 1958.35 2099.66 27.020 187.810 1978.61 2043.13 2193.72 29.180 182.270 2061.59 2126.11 2287.97 33.130 182.800 2142.23 2206.75 2379.23 37.720 182.610 2216.58 2281.10 2411.44 39.990 182.080 2241.66 2306.18 2443.26 41.820 181.790 2265.71 2330.23 2470.84 42.480 181.490 2286.16 2350.68 2564.61 47.480 178.550 2352.47 2416.99 2658.97 50.580 177.780 2414.33 2478.85 2752.11 53.930 177.790 2471.34 2535.86 2846.19 57.710 178.950 2524.18 2588.70 2937.99 62.000 180.110 2570.28 2634.80 3033.55 66.650 179.900 2611.67 2676.19 3126.12 67.950 179.700 2847.39 2711.91 3220.11 69.790 179.390 2681.27 2745.79 3314.06 69.450 178.890 2713.99 2778.51 3408.69 69.040 178.360 2747.52 2812.04 3501.96 69.100 178.470 2780.84 2845.36 3591.40 67.320 179.850 2814.04 2878.56 3686.88 68.130 182.630 2850.24 2914.76 3778.37 69.950 186.220 2882.97 2947.49 3872.74 70.280 189.630 2915.08 2979.60 3964.93 69.190 193.140 2947.02 3011.54 4058.99 67.700 196.710 2981.59 3046.11 4153.49 67.180 199.440 3017.85 3082.37 4246.94 66.190 199.490 3054.83 3119.35 4341.52 65.360 199.860 3093.64 3158.16 -. Local Coordinates - Northings Eastings (ft) (ft) 226.01S 221.34 238.14 S 225.23 263.65 S 232.36 300.33 S 240.25 348.43 S 244.06 397.13 S 246.23 449.95 S 248.72 470.14 S 249.55 490.97 S 250.25 509.47 S 250.78 575.71S 250.73 846.91S 248.43 720.50 S 245.59 798.28 S 243.39 877.84S 242.76 963.74S 242.76 1049.14 S 242.46 1136.80 S 241.77 1224.86 S 240.45 1313.33S 238.32 1400.41S 235.91 1483.44S 234.69 1571.77 S 236.61 1656.92 S 243.21 1744.80 S 255.45 1829.57 S 272.51 1914.08 S 295.02 1997.04S 322.09 2077.95S 350.69 2159.17 S 379.73 Global Coordinates Northings Eastings (ft) (ft) W 5980290.76 N 618711.99 E W 5980278.58 N 618708.29 E W 5980252.95 N 618701.56 E W 5980212.15 N 618694.32 E W 5980168.00 N 618691.21E W 5980119.27 N 618689.82 E W 5980066.41N 618688.16 E W 5980046.21N 618687.66 E W 5980025.38 N 618687.29 E W 5980006.88 N 618687.05 E W 5979940.64 N 618688.16 E W 5979889.48 N 618691.58 E W 5979?95.95 N 618695.59 E W 5979718.22 N 618699.02E W 5979638.87 N 618700.91E W 5979552.78 N 618702.28 E W 5979467.40 N 618703.93 E W 5979379.76N 618706.02 E W 5979291.73 N 618708.74E W 5979203.32 N 618712.27 E W 5979116.28 N 618716.06E W 5979033.28 N 618718.60 E W 5978944.94N 618718.09 E W 5978859.68 N 618712.83 E W 5978771.62 N 618701.99 E W 5978686.59 N 618686.28 E W 5978601.73 N 618665.11E W 5978518.36N 618639.36 E W 5978437.00 N 618612.05 E W 5978355.34N 618584.31E Dogleg Rate (o/100ft) 6.28 2.62 1.83 3.63 3.60 4.20 5.03 7.12 5.78 2.50 5.77 3.34 3.60 4.15 4.80 4.87 1.42 1.98 0.62 0.68 0.13 2.45 2.82 4.17 3.42 3.76 3.87 2.72 1.06 0.95 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 277.58 290.31 316.8o 358.09 401.57 449.03 500.55 520.21 540.44 558.39 622.14 690.05 760.10 834.37 910.59 993.46 1075.58 1159.76 '1244.16 1328.73 1411.90 1491.48 1577.02 1660.77 1748.68 1834.89 1922.35 2009.53 2095.17 2181.21 12 January, 2001- 11:02 Page 3 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S.216 Your Ref: AP1 500292298900 Surveyed: 22 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4433.77 66.370 200.230 3131.36 3195.88 4527.69 65.550 200.880 3169.62 3234.14 4621.95 65.140 200.860 3208.94 3273.46 4714.64 65.000 200.750 3248.01 3312.53 4809.96 66.840 200.270 3286.90 3351.42 4902.13 67.330 200.690 3322.79 3387.31 4993.32 66.290 200.650 3358.70 3423.22 5085.73 67.750 200.930 3394.78 3459.30 5178.15 67.680 201.220 3429.82 3494.34 5273.85 66.850 200.800 3466.81 3531.33 5369.23 66.460 200.760 3504.60 3569.12 5462.36 65.980 202.240 3542.16 3606.68 5558.47 64.230 201.930 3582.61 3647.13 5651.19 65.400 202.520 3622.07 3686.59 5746.04 66.300 201.720 3660.88 3725.40 5839.00 65.330 203.190 3698.96 3763.48 5933.80 64.290 202.840 3739.31 3803.83 6025.14 65.290 201.530 3778.22 3842.74 6117.82 65.960 200.600 3816.47 3880.99 6211.86 67.190 200.020 3853.85 3918.37 6306.85 66.760 200.600 3891.00 3955.52 6400.88 66.600 200.110 3928.23 3992.75 6495.23 65.790 200.140 3966.31 4030.83 6589.87 64.990 200.740 4005.72 4070.24 6677.91 64.390 200.080 4043.36 4107.88 6769.73 63.620 200.960 4083.60 4148.12 6864.08 62.080 201.270 4126.66 4191.18 6958.13 59.850 200.360 4172.30 4236.82 7050.96 58.780 198.540 4219.68 4284.20 7145.21 56.860 196.720 4269.87 4334.39 Local Coordinates Global Coordinates Northings Eaafings Northinge EasUnge (fi) (fi) (fi) (fi) 2238.25 S 408.58W 5978275.81N 618556.71E 2318.56S 438.70W 5978195.03N 618527.88 E 2398.61S 469.21W 5978114.51N 618498.63 E 2477.18 S 499.07W 5978035.47 N 618470.03 E 2558.69 S 529.56W 5977953.49 N 618440.84E 2638.22 S 559.26W 5977873.50 N 618412.40 E 2716.64S 588.85W 5977794.61N 618384.06E 2796.18 $ 619.05W 5977714.61N 618355.13 E 2875.97 S 649.80W 5977634.33 N 618325.65 E 2958.37 S 681.44W 5977551.45 N 618295.32 E 3040.24S 712.51W 5977469.09 N 618265.55 E 3119.53 S 743.74W 5977389.31N 618235.58 E 3200.31S 776.52W 5977308.02N 618204.09 E 3277.98 S 808.26W 5977229.86 N 618173.59 E 3358.16 S 840.85W 5977149.18 N 618142.28 E 3436.53 S 873.23W 5977070.30 N 618111'.15 E 3515.48 S 906.77W 5976990.82 N 618078.86 E 3592.00 $ 937.97W 5976913.82 N 618048.88 E 3670.78S 968.31W 5976834.57 N 618019.80 E 3751.70 S 998.26W 5976753.18 N 617991.14 E 3833.69S 1028.60W 3914.65 S 1058.64W 3995.70S 1088.34W 4076.32 S 1118.38W 4150.91S 1146.14W 4228.21S 1175.07W 4306.52 S 1205.31W 4383.38 S 1234.53W 4458.65 S 1261.12W 4534.66 S 1285.29W 5976670.72 N 617962.10 E 5976589.30 N 617933.35 E 5976507.79 N 617904.94E 5976426.70 N 617876.18 E 5976351.67 N 617849.61E 5976273.93 N 617821.91E 5976195.14 N 617792.92E 5976117.84N 617764.92 E 5976042.16 N 617739.53 E 5975965.77 N 617716.57 E Dogleg Rate (°ll00ft) 1.15 1.08 0.44 0.19 1.98 0.68 1.14 1.60 0.30 0.96 0.41 1.54 1.84 1.39 1.22 1.78 1.15 1.70 1.17 1.43 0.72 0.51 0.86 1.02 0.96 1.20 1.66 2.52 2.04 2.61 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 2265.16 2350.63 2435.95 2519.68 2606.40 2691.00 2774.52 2859.26 2944.41 3032.30 3119.53 3204.32 3290.96 3374.33 3460.34 3544.55 3629.64 3711.76 3795.81 3881.82 3968.97 4055.04 4141.11 4226.86 4306.18 4388.42 4472.01 4553.91 4633.57 4713.28 12 January, 2001 - 11:02 Page 4 of 6 DrillQuest 2.00.08 Sperry-Sun Dn'lling Services Survey Report for S-216 Your Ref: AP1500292298900 Surveyed: 22 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinatee' Depth Depth Northings Eastings (~t) (ft) (ft) (ft) 7238.69 54.250 196.990 4322.74 4387.26 4608.43 S 1307.64W 7332.31 50.670 197.310 4379.78 4444.30 4679.35 S 1329.52W 7424.66 48.510 196.760 4439.64 4504.16 4746.58 S 1350.12W 7518.35 46.880 195.900 4502.70 4567.22 4813.07 S 1369.61VV 7612.84 43.920 195.520 4569.04 4633.56 4877.83 S 1387.83VV Global Coordinates Northings Eastings (ft) (ft) 5975891.65 N 617695.40 E 5975820.39 N 617674.64E 5975752.84N 617655.11E 5975686.05 N 617636.68 E 5975621.02 N 617619.49 E 7707.33 39.690 194.580 4639.46 4703.98 4938.63 S 1404.20W 7800.56 35.750 193.240 4713.19 4777.71 4993.98 S 1417.94W 7895.32 31.380 191.370 4792.13 4856.65 5045.14 S 1429.15W 7989.76 27.490 193.230 4874.37 4938.89 5090.48 S 1438.99W 8084.72 22.630 192.830 4960.36 5024.88 5129.65 S 1448.07W 5975559.96 N 617604.08 E 5975504.40 N 617591.23 E 5975453.07 N 617580.83 E 5975407.58 N 617571.71E 5975368.27 N 617563.26 E 8177.47 17.810 195.330 5047.37 5111.89 5160.75 S 1455.79W 8272.26 17.900 194.910 5137.60 5202.12 5188.80 S 1463.37W 8365.63 17.930 194.440 5226.44 5290.96 5216.59 S 1470.64W 8458.85 16.370 194.560 5315.51 5380.03 5243.20 S 1477.52W 8552.69 14.700 195.530 5405.92 5470.44 5267.47 S 1484.04W 8637.66 14.820 196.680 5488.09 5552.61 5288.27 S 1490.04W 8713.00 14.820 196.680 5560.92 5625.44 5306.73 S 1495.57W 5975337.05 N 617556.03 E 5975308.88 N 617548.90 E 5975280.98 N 617542.07 E 5975254.26N 617535.61E 5975229.89 N 617529.48 E 5975209.00 N 617523181E 5975190.46 N 617518.57 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Welll Magnetic Declination at Surface is 26.656° (07-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 195.739° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8713.00ft., The Bottom Hole Displacement is 5513.45ft., in the Direction of 195.739° (True). Dogleg Rate ('/lOOft) 2.80 3.83 2.38 1.87 3.15 4.53 4.32 4.74 4.23 5.12 5.28 0.17 0.16 1.67 1.80 0.37 0.00 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 4790.35 4864.55 4934.85 5004.13 5071.40 5134.37 5191.37 5243.65 5289.96 5330.12 5362.15 5391.21 5419.93 5447.41 5472.54 5494.18 5513.45 PROJECTED SURVEY 12 January, 2001. f 1:02 Page 5 of 6 DrlllQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S.216 Your Ref: API-500292298900 Surveyed: 22 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E 409.00 408.64 1.96 S 11.83 W 8713.00 5625.44 5306.73 S 1495.57 W Comment Surface TIE ON POINT PROJECTED SURVEY Survey tool program for S.2f6 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 511.86 511.03 511.86 511.03 8713.00 5625.44 Survey Tool Description Tolerable Gyro (S-216 PGSS) AK-6 BP_IFR-AK (S-216) f2 JanuaG,, 2001 - 11:02 Page 6 of 6 DrillQuest 2.00,06 I IIIl~ ~lll ll~l lllll lllll ~l~ lllll ~l~ ll~l ll~l ~lll ll~ llll 10202616829 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-216 S-2'!6 MWD Surveyed: 22 December, 2000 S UR VEY REPORT 12 January, 2001 Your Ref: API500292298900 Surface Coordinates: 5980520.26 N, 618929.71 E (70' 21' f9.4406" N, Kelly Bushing: 64.52ft above Mean Sea Level 149° 02' 03.0221" W) ORILL. INI~ S~FIVIC~I=S A H~lllbufton Company Survey Reft svyl0705 North Slope Alaska Measured Depth Incl. (ft) AzJm. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for S-216 Your Ref: AP!500292298900 Surveyed: 22 December, 2000 Vertical Local Coordinates' Depth Northings Eastings (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (°il00ft) Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment S-2f6 PGSS 0.00 0.000 0.000 -64.52 0.00 132.00 0.000 0.000 67.48 132.00 224.00 1.500 273.000 159.47 223.99 317.00 3.500 260.000 252.38 316.90 409.00 5.000 254.000 344.12 408.64 0.00 N 0.00 E: 0.00 N 0.00 E 0.06 N 1.20 W 0.37 S 5.21 W 1.96 S 11.83 W 5980520.26 N 618929.71E 5980520.26 N 618929.71E 5980520.30 N 618928.51E 5980519.81N 618924.50 E 5980518.11N 618917.91E 0.00 1.63 2.22 1.70 0,00 Surface Tolerable Gym 0,00 0,26 1.76 5.09 TIE ON POINT S-216 MWD 511.86 5.960 253.600 604.90 7.010 241.980 696.49 7.530 233.580 789.63 7.940 229.040 882.73 9.980 217.070 446.51 538.96 629.81 722.11 814.07 511.03 603,48 694.33 786.63 878.59 976.63 11,060 211.400 906.40 970.92 1070.22 11.250 217.630 998.22 1062.74 1164.31 10.380 222.820 1090.64 1155.16 1259.22 10.850 229.050 1183.93 1248.45 1353.01 12.330 230.950 1275.81 1340.33 1445.16 15.290 228.190 1365.28 1429.80 1540.12 15.850 226.870 1456.76 1521.28 1633.84 15.730 226.220 1546.94 1611.46 1726.06 17.180 220.190 1635.39 1699.91 1817.97 20,740 210.720 1722.32 1786.84 4.70 8.73 14.92 22.76 33.42 47.60 62.49 75.98 88.10 100.20 114.50 131.71 149.25 168.31 192.68 S 21,27 S 30.91 S 40.68 S 50.44 S 60.17 S 69.76 S 80.01 S 91.38 S 103.94 S 118.38 S 135.09 S 153.88 S 172.39 S 190.21 S 2O7.29 W 5980515.22 N 618908.52 E W 5980511.04N 618898.94E W 5980504.69 N 618889.28 E W 5980496.70 N 618879.63E W 5980485.89 N 618870.08 E W 5980471.56N 618860.71E W 5980456.51N 618850.70E W 5980442.84N 618839.55 E W 5980430.52N 618827.18 E W 5980418.19 N 618812.93E W 5980403.63 N 618796.46 E W 5980386.12 N 618777.94E W 5980368.29 N 618759.71E W 5980348.95 N 618742.19 E W 5980324.31N 618725.50 E 0.93 1.80 1.29 0.79 2.96 1.59 1.30 1.39 1.31 1.63 3.29 0.70 0.23 2.43 5.11 10.28 16.78 25.38 35.57 48.46 64.71 81.82 97.88 112.96 128.51 146.80 168,46 190.36 213.53 241,61 MWD Magnetic 12 January, 2001- 11:02 Page 2 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-216 Your Ref: API500292298900 Surveyed: 22 December, 2000 '..y North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 1911.84 24.430 198.550 1809.02 1873.54 1942.45 24.740 196.860 1836.86 1901.38 2005.28 25.150 194.190 1893.83 1958.35 2099.66 27.020 187.640 1978.61 2043.13 2193.72 29.180 182.040 2061.59 2126.11 2287.97 33.130 182.830 2142.23 2206.75 2379.23 37.720 182.810 2216.58 2281.10 2411.44 39.990 182.190 2241.66 2306.18 2443.26 41.820 181.830 2265.71 2330.23 2470.84 42.470 181.510 2286.16 2350.68 2564.61 47.480 178.480 2352.48 2417.00 2658.97 50.580 177.560 2414.34 2478.86 2752.11 53.930 177.570 2471.35 2535.87 2846.19 57.710 178.650 2524.19 2588.71 2937.99 62.000 179.830 2570.28 2634.80 3033.55 66.650 179.660 2611.68 2676.20 3126.12 67.940 179.470 2647.41 2711.93 3220.11 69.790 179.300 2681.29 2745.81 3314.06 69.450 179.890 2714.01 2778.53 3408.69 69.040 178.260 2747.55 2812.07 3501.96 69.100 178.280 2780.87 2645.39 3591.40 67.320 179.500 2814.07 2878.59 3686.88 68.120 182.400 2850.27 2914.79 3778.37 69.960 185.980 2883.01 2947.53 3872.74 70.280 189.350 2915.11 2979.63 3964.93 69.190 192.990 2947.05 3011.57 4058.99 67.700 196.670 2981.61 3046.13 4153.49 67.180 199.470 3017.87 3082.39 4246.94 66.190 199.570 3054.86 3119.38 4341.52 65.360 199.910 3093.67 3158.19 Local Coordinates Northings Easfings (ft) (ft). Global Coordinates Northinge Eaetinge (ft) 225.40 S 221.97W 5980291.36 N 618711.34E 237.53 S 225.84W 5980279.17 N 618707.66 E 263.06 S 232.93W 5980253.53 N 618700.98 E 303.76S 240.70W 5980212.71N 618693.86 E 347.87 S 244.36W 5980168.56 N 618690.91E 396.57 S 246.45W 5980119.82 N 618689.59 E 449.39 S 249.05W 5980066.97 N 618687.83 E 469.58 S 249.93W 5980046.77N 618687.27 E 490.40 S 250.66W 5980025.94N 618686.87 E 508.90 S 251.20W 5980007.44N 618686.62 E 575.14 S 251.11W 5979941.21N 618687.76 E 646.33 S 248.64W 5979870.06 N 618691.36 E 719.91S 245.51W 5979796.55 N 618695.66 E 797.68 S 242.96W 5979718,82 N 618699.44 E 877.04S 241.93W 5979639.49 N 618701.74 E 963.14 S 241.54W 5979553.41N 618703.49 E 1048.53 S 240.89W 5979468.04N 618705.50 E 1136.19 S 239.95W 5979380.41N 618707.83 E 1224.25 S 239.33W 5979292.36 N 618709.85 E 1312.73S 237.90W 5979203.92 N 618712.68 E 1399.80S 235.27W 5979116.90 N 618716.69 E 1482.83 S 233.66W 5979033.91N 618719.62 E 1571.16 S 235.13W 5978945.57 N 618719.56 E 1656~34S 241.38W 5978860.29 N 618714.65 E 1744.28 S 253.22W 5978772.18 N 618704.21E 1829.11S 269.96W 5978687.10 N 618688.82 E 1913.66S 292.33W 5978602.20N 618667.79 E 1996.61S 319.39W 5978518.83 N 618642.05 E 2077.50 S 348.07W 5976437.50 N 618614.67 E 2158.68 S 377.20W 5978355.86N 618586.83 E Dogleg Rate (°ll00ft) 6.33 2.51 1.91 3.64 3.62 4.21 5.03 7.15 5.8O 2.48 5.81 3.37 3.60 4.13 4.80 4.87 1.41 1.98 0.69 1.67 0.07 2.36 2.93 4.17 3.38 3.89 3.97 2.79 1.06 0.94 Alaska Drilling & Wells PBU_WOA $ Pad Vertical Section Comment 277.09 289.81 316.30 357.59 401.o4 448.49 500.04 519.71 539.95 557.91 621.65 689.51 759.49 833.67 909.78 992.56 1074.59 1158.72 1243.32 1328.11 1411.22 1490.71 1576.13 1659.83 1747.69 1833.88 1921.33 2008.51 2094.14 2180.18 12 January, 2001.11:02 Page 3 of 6 DriflQuest 2.00.06 Sperry-Sun Drilling' Services Survey Report for S-216 Your Ref: API500292298900 Surveyed: 22 De;ember, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) 4433.77 66.370 200.260 3131.39 3195.91 4527.69 65.550 200.900 3169.65 3234.17 4621.95 65.140 200.980 3208.97 3273.49 4714.64 65.000 200.830 3248.04 3312.56 4809.96 66.850 200.270 3286.92 3351.44 4902.13 67.330 200.690 3322.80 3387.32 4993.32 66.300 200.620 3358.70 3423.22 5085.73 67.750 201.010 3394.77 3459.29 5178.15 67.680 201.220 3429.82 3494.34 5273.85 66.850 200.810 3466.81 3531.33 5369.23 66.460 200.770 3504.60 3569.12 5462.36 65.980 202.250 3542.15 3606.67 5558.47 64.230 201.900 3582.61 3647.13 5651.19 65.400 202.380 3622.07 3686.59 5746.04 66.300 201.580 3660.87 3725.39 5839.00 65.330 203.130 3698.96 3763.48 5933.80 64.280 202.770 3739.31 3803.83 6025.14 65.290 201.570 3778.23 3842.75 6117.82 65.960 200.680 3816.48 3881.00 6211.86 67.190 200.080 3853.86 3918.38 6306.85 66.760 200.680 3891.02 3955.54 6400.88 66.600 200.130 3928.24 3992.76 6495.23 65.790 200.140 3966.32 4030.84 6589.87 64.990 200.750 4005.73 4070125 6677.91 64.390 200.080 4043.37 4107.89 6769.73 63.630 200.990 4083.61 4148.13 6864.08 62.080 201.310 4126.66 4191.18 6958.13 59.850 200.290 4172.30 4236.82 7050.96 58.780 198.510 4219.67 4284.19 7145.21 56.860 196.660 4269.87 4334.39 Ve~ical Local Coordinates Global Coordinates Depth Northings Easfings Northings Eas~nge (fi) (fi) (~) (~) (~) 2237.75 S 406.11W 5978276.35 N 618559.18 E 2318.05 S 436.26W 5978195.58 N 618530.30 E 2398.06S 466.88W 5978115.10 N 618500.96E 2476.58 S 496.87W 5978036.11N 618472.22 E 2558.06S 527.41W 5977954.15 N 616442.97 E 2637.60 S 557.12W 5977874.15 N 618414.54E 2716.03 S 586.69W 5977795.26 N 618386.22 E 2795.56S 616.92W 5977715.26 N 618357.25 E 2875.33 S 647.73W 5977635.01N 618327.71E 2957.72 $ 679.38W 5977552.12 N 618297.37 E 3039.59 S 710.46W 5977469.77 N 618267.59 E 3118.88 S 741.71W 5977390.00 N 618237.61E 3199.66 S 774.47W 5977308.71N 618206.13 E 3277.38 S 806.09W 5977230.50 N 618175.75 E 3357.64S 838.49W 5977149.74 N 618144.63 E 3436.06 S 870.73W 5977070.81N 618113.63 E 3515.05 S 904.18W 5976991.30 N 618081.44E 3591.58 S 935.36W 5976914.29 N 618051.48 E 3670.32 S 965.78W 5976835.07 N 618022.32 E 3751.21S 995.83W 5976753.72 N 617993.56E 3833.16 S 1026.27W 5976671.29 N 617964.42 E 3914.09S 1056.38W 5976589.90 N 617935.60E 3995.13 S 1086.10W 5976508.39 N 617907.18 E 4075.76S 1116.15W 5976427.30 N 617878.41E 4150.35 S 1143.91W 5976352.28 N 617851.83 E 4227.63 S 1172.86W 5976274.54N 617824.11E 4305.93 S 1203.15W 5976195.77 N 617795.07 E 4382.80 S 1232.36W 5976118.45 N 617767.09 E 4458.09S 1258.88W 5976042.75 N 617741.76E 4534.12 S 1282.99W 5975966.34N 617718.86 E Dogleg Rate ('/'lOOft) 1.15 1.07 0.44 0.21 2.01 0.67 1.13 1.62 0.22 0.95 0.41 1.54 1.85 1.35 1.22 1.84 1.16 1.62 1.13 1.43 0.74 0.56 0.86 1.03 0.97 1.22 1.67 2.55 2.01 2.63 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 2264.12 2349.58 2434.89 2518.6o 2605.31 2689.92 2773.43 2858.17 2943.30 3031.19 3118.42 32O3.20 3289.84 3373.22 3459.25 3543.47 3628.57 3710.68 3794.72 3880.72 3967.85 4053.91 4139.97 4225.72 4305.04 4387.28 4470.86 4552.76 4632.42 4712.14 12 January, 2001- 11:02 Page 4 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S.216 Your Ref: API500292298900 Surveyed: 22 December, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eesfings (ft) (ft) (ft) (ft) (rt) 7238.69 54.250 196.940 4322.74 4387.26 4607.91 S 1305.27 W 7332.31 50.670 197.120 4379.78 4444.30 4678.88 S 1327.00 VV 7424.66 48.510 196.630 4439.64 4504.16 4746._17 $ 1347.42 W 7518.35 46.880 195.780 4502.70 4567.22 4812.70 S 1366.76 W 7612.84 43.920 195.370 4569.04 4633.56 4877.50 S 1384.83 W Global Coordinates Northings Easflngs (ft) (ft) 5975892.21 N 617697.76 E 5975820.90 N 617677.16 E 5975753.30 N 617657.81 E 5975686.47 N 617639.53 E 5975621.39 N 617622.49 E 7707.33 39.690 194.500 4639.46 4703.98 4938.34 S 1401.07 W 7800.56 35.750 193.180 4713.19 4777.71 4993.70 S 1414.74 W 7895.32 31.380 191.420 4792.13 4856.65 5044.86 S 1425.95 W 7989.76 27.490 193.290 4874.37 4938.89 5090.19 S 1435.83 W 8084.72 22.620 192.820 4960.36 5024.88 5129.35 S 1~.~'l..93 W 5975560.30 N 617607.21 E 5975504.73 N 617594.42 E 5975453.40 N 617584.03 E 5975407.92 N 617574.87 E 5975368.62 N 617566.40 E 8177.47 17.800 195.500 5047.38 5111.90 5160.42S 1452.68W 8272.26 17.900 194.980 5137.61 5202.13 5188.46S 1460.31W 8365.63 17.930 194.590 5226.45 5290.97 5216.23 S 1467.64W 8458.85 16.370 194.660 5315.52 5380.04 5242.82S 1474.58W 8552.69 14.700 195.500 5405.93 5470.45 5267.09 S 1481.11W 8637.66 14.820 196.530 5488.10 5552.62 5287.90 S 1487.08W 8713.00 14.820 196.530 5560.93 5625.45 5306.37 S 1492.57W 5975337.43 N 617559.14 E 5975309.27 N 617551.95 E 5975281.39 N 617545.06 E 5975254.69 N 617538.54 E 5975230.32 N 617532.40 E 5975209.42 N 617526.78 E 5975190.86 N 617521.57 E All data is in feet 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 26.656° (07-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 195.710° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8713.00ft., The Bottom Hole Displacement is 5512.29ft., in the Direction of 195.710° (True). Dogleg Rate ('/100ft) 2.80 3.83 2.37 1.86 3.15 4.52 4.31 4.72 4.23 5.13 5.29 0.20' 0.13 1.67 1.80 0.34 0.00 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 4789.21 4863.41 4933.71 5002.99 5070.26 5133.23 5190.22 5242.51 5288.82 5328.98 5360.99 5390.05 5418.76 5446.25 5471.38 5493.02 5512.29 PROJECTED SURVEY f2 January, 200f - f f :02 Page 5 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report ~r S-216 Your Ref: API500~92298900 Surveyed: 22 De;emberw 2000 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (rt) (ft) fit) 0.00 0.00 0.00 N 0.00 E 409.00 408.64 1.96 S 11.83 W 8713.00 5625.45 5306.37 S 1492.57 W Comment Surface TIE ON POINT PROJECTED SURVEY Survey tool program for S-216 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 511.86 511.03 511.86 511.03 8713.00 5625.45 Survey Tool Description Tolerable Gyro (S-216 PGSS) MWD Magnetic (S-216 MWD) 12 January, 2001 - 11:02 Page 6 of 6 DrillQuest 2.00.06 10202616832 North Slope Alaska Alaska Drilling & Wells PBU_ WOA S Pad, Slot S-2~6 S-2~6 PGSS Surveyed: 22 December, 2000 S UR VEY REPORT 12 January, 200f Your Ref: AP1. 500292298900 Surface Coordinates: 5980520.26 N, 618929.71 E (70° 21' 19.4406" N, Kelly Bushing: 64.52ft above Mean Sea Level 149002'0~0221"W) E;I~ RVI CBS SurveyRef: svyl0704 Halliburton Company Sperry-Sun Drilling Services Survey Report for S-216 PGSS Your Ref: APl- 500292298900 Surveyed: 22 December, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -64.52 0.00 0.00 N 0.00 E 5980520.26 N 618929.71E 132.00 0.000 0.000 67.48 132.00 0.00 N 0.00 E 224.00 1.500 273.000 159.47 223.99 0.06 N 1.20W 317.00 3.500 260.000 252.38 316.90 0.37 S 5.21W 409.00 5.000 254.000 344.12 408.64 1.96 S 11.83W 5980520.26 N 618929.71E 5980520.30 N 618928.51E 5980519.81N 618924.50 E 5980518.11N 618917.91E All data is in feet 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 26.656° (07-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 197.907° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 409.00ft., The Bottom Hole Displacement is 12.00ft., in the Direction of 260.600° (True). Dogleg Rate (°il00ft) 0.00 1.63 2.22 1.70 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 0.00 Surface Tolerable Gyro 0.00 0.31 1.95 5.50 12 January, 2001 - ff:O0 Page 2 of 3 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-216 PGSS Your Ref: APl - 500292298900 Surveyed: 22 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Comments Measured Depth (ft) 0.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E Comment Surface Survey tool program for S.216 PGSS From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 409.00 408.64 Survey Tool Description Tolerable Gyro 12 January, 2001 - 1t:00 Page 3 of 3 DriliQuest 2.00.06 4/12/2001 Schlumberger Alaska Date and Consulting Services 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-6711 ATTN: Sherrie NO. T51 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Well Job # Log Description Date BL Sepia CD S-213 ~ OD -c:~ 05 STATIC TEMPIPRESSURE 03129101 1 1 S-216 =l OO-/~--7 PRODUCTION LOG 04102101 1 I 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 20 2001 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A-I-tN: Sherrie Receive~ Schlumberger Alaska Data & Consulling Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-571 I ATTN: Sherrle NO. 890 Company: Field: State of Alaska Alaska Oil & Gas Conservalion Alln: Lisa Weeple 333 West 7th Ave, Suile 100 Anchorage, AK 99501 Color Well Job # Log Description Date Color Sepia Prlnls CD $-216 21018 USIT 001226 ! . .. .. . .. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 1/18/01 BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 995[]8 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-571 ATI'N: Sherrie Received 12-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 MWD Surveys Re: Distribution of Survey Data for Well S-216 MWD Dear Dear Sir/Madam: ,),.00 Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 409.00' MD 'MD 8,713.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Re: S-21."-..(200-197)Surface csg test pressure ~" Subject: Re: S-216 (200-197)Surface csg test pressure Date: Mon, 18 Dec 2000 10:07:50-0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Smith, Phil G (FAIR)" <SmithPGl@BP.c)m> Phil, Thanks for the information and photo. I have discussed the situation with our inspector. If your repair has been satisfactorily completed, the original pressure rating of your equipment should still apply. Your originally planned test pressure of 3500 psi is 70% of the wellhead rated working pressure. The proposed 2500 psi test pressure would be only 50% of the rated working pressure. We believe it appropriate to maintain the test pressure at 3500 psi as originally planned. Good luck with your further operations. Tom Maunder Petroleum Engineer "Smith, Phil G (FAIR)" wrote: Tom, ADW would like to revise the S-216 surface casing test pressure from the 3500 psi stated in the drilling perrrit down to 2500 psi. This request stems from concern about field-repaired damage to the metal-to-metal seal area on the surface hanger. The damage was sustained during nipple down operations followfng the surface cement job over the weekend. The wellhead manufacturer FMC have indicated that the welder Wayne Simmons was qualified to perform the work, approved procedures were used, and the repair should have no trouble passing a full test. It is our view, nonetheless, that a 2500 psi test is more than adequate for any potential pressure on the casing. Maximum anticipate surface pressure with a full column of gas is 1750 psi. Nabors 9ES are preparing to test the BOP stack this moming, continuing thereafter to the casing test. Your attention to the matter this moming is appreciated. Regards, Phil Smith Operations Drilling Engineer 564-4897 ITom Maunder <tom maunder~,admin.state.ak, us> P--~role'~m ~eer ,., A!a. Ska Oil and Gas Conservation Commi~s.i.0n ............................................................ 1 of 2 12/18/00 12:23 PM JPEG image 640x480 pixels ,.~ 4 I · "- b 1 of 1 12/18/00 9:57 AM Re:. S-216. Diverter dispensa~on ( (. Subject: Re= S-216 Dive.er dispensation ~.~ {~ --- \ ~ ~ Date: Mon, 04 Dec 2000 10:06:27 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Smith, Phil G (FAIR)" <SmithPGl@BP.(om> Phil, Yes, you do have approval to drill the surface hole on S-216 without a diverter. Sorryfor not specifically including that comment in the cover letter. Since you will be requesting a waiver in each application you submit, we will specifically include the waiver comment in the future cover letters. Give a call if you have further questions. Tom Maunder "Smith, Phil G (FAIR)" ~rote: Tom, Just wanted to confirm that, by approval of the S-216 permit as written, we are cleared to not rig up a diverter on S-216 surface hole. It doesn't specifically address that on the permit, only in the attachment I sent. Please respond for confirmation. I'll enclose the cover letter and graphs as submitted for S-105 earlier, updated for $-216. Thanks, Phil <<No Diverter Itr AOGCC. doc>> <<Diverter disp. mud plots, xls>> Nane: No Diverter Itr AOGCC. doc No Diverter Itr AOGCC. doc Type: Microsoft Word Document (application/msword) En©ding: base64 Nane: Diverter disp. mud plots, xls Diverter disp. mud plots, xls Type: Microsoft Excel Worksheet (application/vnd. ms-excel) En©ding: base64 Tom Maunder <tom maunder~,admin.state.ak, us> Petrol~eer Alaska Oil and Gas Conservation Commission 1 of 1 12/4/00 10:06 AM To: Blairwondzell, AOGCC Date: December 4, 2000 From: Phil Smith Subject: DiSl~ensation For 20 A~,¢ 25.035 (c) on Polaris S-216 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale of the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent six Aurora/Polaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first six surface holes for the Aurora/Polaris development were .drilled no deeper than the shale underlying the SV-1 sands; S-216 is planned to TD in the shallower SV- 3 shale, as did the most recent three wells. The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is +500' TVD above the Ugnu horizon. The shallowest RFT point recorded in the area is from SB-01, recording a pore pressure of 1,555 psi at 3,195' TVDSS (9.36 ppg EMW). S-216 is planned to reach 9.6 ppg mud weight before TD at 2,770' TVDss. This planned mud weight, and the aforementioned RFT data, is plotted on the attached chart. Supporting surface hole gas detection information is on file with the AOGCC from recently drilled S-105. Your consideration of the waiver is appreciated. Sincerely, Phil G. Smith ADW Engineer 564-4897 0 5OO 1000 500 2000 25OO 3OOO 35OO 4OOO Aurora/Polaris Surface Hole Mud Weight MW (ppg) 8 8.5 9 9.5 10 · -+- S-100 .-a-S-lO1 --.- S-102 ----S-105 --- S-103 I~ S-201 Pore Pressure --a-- S-216 Plan PGS 11/30/2000 S-213 Drilling Permit ALASKA OIL AND GAS CONSERVATION CO~liSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DR~/E ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 30, 2000 Mr. Dan Stone Sr. Drilling Engineer. BP Exploration (Alaska) inc. Alaska Drilling and Wells PO Box 196612 Anchorage, AK 995'19' Request for Waiver °fDiverterRequiremems at .20 AAC 25.035. (c) Prudhoe Bay unit S Pad. Dear Mr. Stone: In the.application for Aurora Well S-105 (200-:152), .a.request was made for .exceptiOn 'to the Diverter requirements at 20 AAC 25.035 (c). In support Of this requests: mud weight information gathered 'while' drilling. 3 Aurora iwells (S-100, S-101 and S-102) and RFT information from explOration well S-100' '.were .submitted.' A~ter' review of the submitted.' information"it was determined that'additional information, in Particular gas readings .while drilling, was.needed to quantify.the presence. °r"absence of shallow gas at S pad. ,. During the 'drilling of S-'105,' cominuous gas measurements were taken while drilling.the 'surface. hole'to a depth of 3060' .md (~2860~.tvd). AccOrding to your geOlogic .prognosis, this hole section terminated in the' .SV3 shale.' The continuous gas .data was merged' with 'MWD logging data and the.combined data submitted to the Commission for reView. ... The Commission agrees that. the available information does not reveal 'any ..prOblems. with shallow gas prior' to setting surface casing.in the recently. drilled Aurora: wells. However, we believe it is 'inappropriate to grant a blanket waiver of the diverter.system requirement, for an indefinite number of wells. This' is because Shallow intervals within the S Pad area may .become gas charged by low volume' .leaks from existing wells, over a. period of time or. quite quickly from a single high .volume incident. . RegardleSs of the past .drilling history in the S Pad area, ihe operator.' must be prepared to accommodate drilling hazards that may develop over time. 'Each well' should be 'carefully monitored to detect any developing drilling hazards, 'and subsequent, operations conducted 'aCcordingly. · ... , , .', ., .' .. Mr. Dan Stone 2 November 30, 2000 The Commission, therefore, will consider waiver of the diverter system requirement on a case- by-case basis for S Pad wells with surface casing setting depths in the SV3 shale at a tvd of -2860' or less. Requests for this waiver may be included in the application for Permit to Drill (Form 10-401) and should include an on-going assessment of shallow hazards based on all information available at the time the permit is submitted. Sincerely, Camille Oechsli Taylor Commissioner J. M. Heusser Commissioner ALASI~A OIL AND GAS CONSERVATION CO~ISSIOI~ TONY KNOWLE$, O~OVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mr. Dan Stone Senior Drilling Engineer BP Exploration (Alaska) P O Box 196612 Anchorage, AK 99519-6612 Re: Pmdhoe Bay Unit S-216 BP Exploration (Alaska) 'Permit'No: 200-197 Sur Loc: 4316'NSL, 4500'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc. 4412'NSL, 694'WEL, Sec. 03, T11N, R12E, UM. Dear Mr. Stone: 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. ' Blowout. prevention equipment (BOPE) must be tested in accordance with 20 AAc 25 035. .' Sufficient notice (approximately 24 hours) must be given to allOw a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, . 'J. M. Heusser CommissiOner BY ORDER OF THE COMMISSION ' DATED this ~ ~ day 0f November, 2000 dlf/Enclosures' cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/0 encl. , , STATE OF ALASKA ALASKA O~' .ND GAS CONSERVATION COMMISi'" JN PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work ~ Drill [] Redrill lb. Type of well Re-Entry [] Deepen Service [] Development Gas Single Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.3' Prudhoe Bay Field / Polaris 3. Address ~6.z~_.~e_rty Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 D-Z~'ZS"~ADL 028261 ~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4316' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 4572' NSL, 647' WEL, SEC. 03, T11N, R12E, UM S-216 Number 2S100302630-277 At total depth 9. Approximate spud date 4412' NSL, 694' WEL, SEC. 03, T11 N, R12E, UM 12/04/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028260, 694' MDI No Close Approach 2560 8610' MD / 5446' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 73 ° Maximum surface 1743 psig, At total depth O'VD) 5270' / 2270 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta.qe data) 30" 20" 91.5# H-40 Weld 80' Surface . Surface 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-M 3271' Surface Surface 3300' 2753' 350 sx Articset Lite III, 363 sx 'G' 8-3/4" 7" 26# L-80 BTC-M 8581' Surface Surface 8610' 7446' 537 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface RECEIVE Intermediate D Production Liner NOV ~, ~ ?fli3rl ~") R fGi["~'~[J~'t A/aska 0il & Gas Cons: Commission Perforation depth: measured Anchora~ true vertical 20, Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drifting Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and.correct to the best of my knowledge Signed Dan Stone ~--------------~--.. '~,w. ~ Title Senior Drilling Engineer ..... Date l$/~/~o '"" ' [~' "?,', ,',,," "~;",,"!: ~,,':~':.~:7 C~,'":H ',~ ~'"~:, :=~ L ",~,'~.'.'q" ,".p',,=~ ~)[i!~ =:"'~ i~,'" ' ~,,','; ' ~,r~.~'.,lr [~ <'.'~ Hi,~ ,.' n,,~"', ,'.FI! r~ ,'.~,~,~,;[! '!~,~, i~.,,~.~"~.!,>~ ~ ~;'.i,~,,; ,,~:~:'=,: . :,',~,'~ ,' ,.'.,'~,~' ]j" :':;' ..-~ ~ ~,, ....... .~ .~... ~ .... ~ ..... ,...,.. ~. ,~.~.,~...I... i,;~,~ dli',;~.~ ~. ¢ il,~,r; ~~~.~ ~, ~..~I~.,.i'L~,~it~?~ ~.~,;;!IJ]~A."...~ ~,~:~,u ~Im!!~.~,.,..., RF ~..;..~, ~!~H.~,~,.I ~.!.~ r~.~': .... . ........ Permit Number ] APl Number. . ... . .... ,. APProval Date _ ] See cover letter "~:~"' [c~'71 50- ~.)Z.~ ,~_~'~X"']' ~0 ~//"'w~-''/~-~I for other requirem.ents 'Conditions of Approval: Samples Required [] Yes ,l~[No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ~.Yes [] No Directional Survey Required ~[Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 1OK [] 15K ~[,~.5K psi Other: by order of Approved By ORIGINAL SIGNED BY Commissioner the commission Date . - I ..... Form 10-401 Rev. 12-01-85 J. M. Heu~ Submit In Triplicate I Well Name: IS-216 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer Surface Location: Target Location: Schrader Bluff "O" sands Bottom Hole Location: X = 618,929.96 Y = 5,980,519.96 4316' FSL 4500' FEL S35 T12N R12E X = 617,590.00 Y = 5,975,475.00 4572' FSL 647' EEL S3, T11N, R12E X = 617,545.70 Y = 5,975,314.81 4412' FSL 694' FEL S3, T11N, R12E Umiat Umiat Umiat I AFENumber: 15M1010 I I Estimated Start Date: 112/04/2000 IMm 18,610' I I TVD: 15,446' I Rig: I Nabors 9ES I Operating days to complete: 116.0 leE/MS: 135.8' I IRKS' 164.3' I Well Design (conventional, slimhole, etc.): I Ultra Slimhole Longstring I Objective: I Schrader Bluff Formation (Target zones O sands) Mud Program: 12-114" Surface Hole (0-3300'): Fresh Water Surface Hole Mud Interval Density Viscosity YP PV Gel-10 Fluid (ppg) (seconds) sec Loss Initial 8.5-9.1 300 75 12 12/25 NC Interval TD 9.1-9.6 65 20-25 22-25 19/55 NC 8-3/4" Intermediate / Production hole (3300' - 8610"' Freshwater LSND Interval Density Viscosity YJ= PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.5 42-52 15-25 10-19 9.0-9.5 6cc <9 shoe to to by HRZ <5 target Directional: KOP: 1300' Maximum Hole Angle: Close Approach Wells: 73° at 3240' MD - Surface shoe None NOV ?, ~, ;nnq Naska Oil & Gas Corls: Commissio~ S-216 Permit to Drill Page I Logging Program: Surface Intermediate / Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den / PWD Open Hole: RFT w/samples Cased Hole: USIT cement evaluation Formation Markers: Formation Tops Uncertainty TVDss Comments Base Permafrost +/-50' 1900 8.60 Estimated pore pressure, ppg SV5 +/-25' 2115 8.64 .... SV 4 +/-25' 2320 8.62 " SV3 / T5 +/-25' . ~, 2670 8.64 " "~ ' SV2 +/-25' ' 2830 8.63 " " ,,, SV1 +/-25' 3160 9.43 .... UG4 +/-25' 3530 9.26 " " Ugnu top (UG4A) +/-25' 3575 10.44" " UG3 +/-25' 3900 8.97 " " UG1 +/-25' 4250 8.73 " " Top Ugnu Ma sands +/-25' 4650 8.52 " " Schrader (Mb1 Sand) +/-25' 4700 8.49 " " Mb2 +/-25' 4760 8.46 " " Mc / WS2 +/-25' 4810 8.44 " " Schrader (Na Sand) +/-25' 4850 8.43 " " Nb +/-25' 4870 8.41 " " Nc +/-25' 4900 8.44 " " Top Oa Sand /WS1 +/-25' 4965 8.40 " " Obb +/-25' 5030 8.37 " " Obc +/-25' 5060 8.36 " " Obd +/-25' 5110 8.34 " " Obe +/-25' 5160 8.33 " " Base Schrader (Obf) +/-25' 5220 8.31 " " TD 5380 TD RECEIVED NOV 2 ?nnrl Oil & Gas Cons: Commission S-216 Permit to Drill Page 2 Casinq/Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 109/109 12-1/4" 9-5/8" 40# L-80 BTC-M 3271' GL 3300'/2753' 8-3/4" 7" 26# L-80 BTC-M 8581' GL 8610'/7446' Tubing 3-1/2" 9.3# L-80 NSCT -8408' GL 7700'/4577' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casing Basis: Size 1 9-5/8" Surface I Lead: Based on 2000' of annulus in the permafrost @ 125% excess and 350' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2350' MD (2245' TVDbkb). Lead 1275 bbl / 1545 ft~ / 350 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. Tail 75 bbl / 421 ft~ / 363 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casing Size 17" Intermediate Longstring I Basis: Lead: N/A Lead TOC: N/A Tail: Based on TOC 500' above top of Ugnu formation and 30% excess + shoe Tail TOC: 5500' MD, 3379' TVDbkb I Total Cement Volume: I Lead IiN/A Tail 111 bbls / 623 ftc/537 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. RECEIVED NOV 2 2 ?nh.ri ,Naka Oil & Gas Cons: Commission S-216 Permit to Drill Page 3 Well Control: Surface hole will be drilled without diverter. Dispensation is expected prior to spud of the well for surface holes drilled on Prudhoe Bay S-Pad. For intermediate hole drilling, 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 surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- , Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Planned completion fluid: 2270 psi @ 5270' TVDss - Schrader OBf Sands 1743 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 3500 psi (required for casing test) 8.6 ppg seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · S-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad has been 60 ppm (S-37, 12/2/98) DRILLING CLOSE APPROACH: Close approach issues are not expected at this time or will be mitigated in the final well plan. S-216 Permit to Drill Page 4 SURFACE HOLE SECTION: · Directional control has been an issue in the recent S-pad surface holes. Response to sliding in the permafrost was hampered through the gravel intervals, presumably the washed-out sections. Doglegs should be kept below 12.5° for casing running. · Relatively high inclination will make hole cleaning an issue in both the surface and intermediate holes. · Lost circulation is has not been a problem in the area and is not expected in this well. Lost circulation material will be on-hand at the rig if required. · Some tight hole has been noted while running casing, in particular with 13-3/8" casing in 16" hole. All Aurora wells on S-pad have experienced some degree of tight hole while drilling and casing the surface hole, though proper drilling and hole cleaning practice has ensured that the difficulty is minimal. · No faults are mapped in the direction of the well plan surface hole. · Heavy clays are reported in the 2000-3000' TVD area of S-pad. · The SV4 sand may contain gas hydrates, though little or none have been encountered thus far in the recent S-pad development. Hydrate will be treated at surface with appropriate mud products. · Produced water injection has over-pressured the SV3/Cretaceous zone. Recent well S- 40 required 9.3 ppg mud to drill this interval. INTERMEDIATE/PRODUCTION HOLE SECTIONS: · The surface casing point is chosen just below the SV3 sands, leaving the SV1 exposed for the 8-3/4" hole. The first three Aurora wells covered the SV1 sand with the surface casing to mitigate differential sticking hazards across the sand. With TD above the HRZ, a lower mud weight will be require, thus minimizing the risk of differential sticking. · No faults are mapped in the immediate vicinity of the S-216 planned trajectory. · All Aurora S-Pad wells drilled this year have contained oil at the top of the Ugnu. For this reason the 7" casing will be cemented to 500' above the UG4^. Disposal: · No annular injection in this well. · Cuffings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-216 Permit to Drill Page 5 (" DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is scheduled to be set Dec 1, 2000. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. Operations: MIRU Nabors 9ES. Nipple up diverter spool (with blinded outlet) and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 ~" drilling assembly and drill surface hole to approximately 3300' MD / 2750' TVD. The actual surface hole TD will be +/-100' TVD below the SV3 sand top (30' below the sand base). 4. Run and cement the 9 5/8", 40# surface casing back to surface. A TAM port collar will be positioned at __.1000' as contingency in the event cement does no fully circulate to surface. 5. ND diverter spool and riser and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 8 ~" drilling assembly and RIH to float collar. Test the 9 5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a FIT to 12.5 ppg EMW.~..,.~,,.~..t-- 8. Drill per directional plan to .topof K't~ar,~ ~'-~cT~ange mud system to LSND. Continue drilling 8 ~" hole to 200' below the base of the Schrader OBf sands. TD: 8610' MD / 5446' TVDbkb. 9. RU Schlumberger, run RFT log with samples at designated locations. 10. Run 7" 26#/ft long string casing to TD and cement to 500' above the Ugnu UG4A formation, set on mandrel hanger. Displace cement with clean Seawater. Bump plug to 3500 psi, check floats. 11. RIH with 6" cleanout assembly to landing collar. Test casing to 3500 psi. 12. RU Schlumberger, run USIT cement evaluation log from PBTD to surface casing shoe. 13. Freeze protect 7" x 9-5/8" annulus with dead crude to 2000' TVD by circulating through the 7" port collar at 2100' MD. 14. Run 3-1/2", 9.3# L-80 completion string. See attached completion schematic for details. 15. Freeze protect tubing and annulus with 2000' diesel. 16. Set production packer and test tubing and annulus to 3500 psi. 17. Install two-way check and test to 3500 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Pull two-way check and Install BPV. Secure the well and rig down / move off 9ES. Estimated Spud Date: 12/04/2000 Phil G. Smith Shared Services Drilling 564-4897 smithpgl@BP.com S-216 Permit to Drill Page 6 S-216 Ri.qsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Monitor closely for signs of gas in the surface hole and perform regular evacuation drills. No gas has been encountered so far in the Aurora / Polaris development and none is expected, however without the diverter on this well the consequence of encountering shallow makes reaction time more critical for personnel safety.~.~,,.~_,.,~k_~\~,~,~,,,,,,~.~.,.~t~,. High formation pressures are present both in and sometimes above the Kuparuk reservoir zone. Expected formation pressure below the permafrost is 9.0 ppg EMW. Previous Aurora S-Pad surface holes were drilled with 9.6- 9.7 pgg mud weight without problem. Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i and S-101 did not encounter any shallow gas problems. S-102 encountered hydrate shows at 2700' and 2850' TVDbkb, however there were no associated complications. Lost circulation while drilling has not been a problem so far in the Aurora development, despite several fault crossings. The closest known fault is 600' from the well plan near the top of the Kuparuk on S-105, converging to 300' from the plan at TD; lost circulation is not considered a likely hazard. Pipe sticking tendency can be mitigated through short trips in the Ugnu / West Sak area and by NOT backreaming connections. Ream down with reduced pump rates. High well angle (>70°) requires extra attention to hole cleaning. The Ugnu interval can be expected to contain hydrocarbons. pad is not a designated H2S pad. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Polaris S-216 Hazards and Contingencies Page ] of 1 WELLHEAD= FMC 11" A~fS~ ............................ i~i~i'"~'"~"; .................... b4'5: BI~." Fi EV"= ............. 3~51§" 'KOP= .................... ~3(~0" 'Max'An~G= '" ~3' @"~2~f~ Datum MD = .DatumTvD= .............. I g 518" 40# L-80 I Minimum ID = 2.813" I 3-112" 9.3# L-80 I 3300' 7700' S-216 ' '~,FETY NOTES 21001 I X Nipple, 2.813" ID I GAS LIFT MANDRELS TYPE MAN 7570' --,7620' X Nipple, 2.813" ID Baker S-3 Packer 7660' ! Nipple, 2.813" ID I 7700' 1 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: I I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Op~Sqz DATE I~'° I I I '"=~#"'~°mBTC I I a.O' I DATE REV BY COMMENTS 11118/00 PGS Original Proposed Completion PRUDHOE BAY UNIT I POLARIS FIELD WELL: S-216 PERMIT No: APl No: Sec., N, E, FEL, FNL BP Exploration (Alaska) ~ DErAU,S ANTI-COLLISION SE'I~rINGS COMPANY DL~rAILS SURVEY PROGRAM WI.,1 J,PATH Name +N/-$ +F./-W Nonling Easling Lalimde Lon~e Sim BP Amoco De~h Fm IX, plh To Suv,'e)'/Plan To~,] Pbn S-216 Interpolation Method'.MD Interval: 100.00 ExpSbt0~,SE43 100L73 59~)520.GO 615929.96 70:21'19..'~5N 149:02'(R.973W Depth Rnngc From: 65.70 To: 8610.46 C, alculafi~nMell~d: /~imumCu~'alme 65.70 86i0.46 Planned:S-216Wp2VI MWI) Ve~k-alS~:ll. mC,~: Sh~l- {O.GO.b0~) EnorSysleng ISCWSA V¢~icalsccd~mAngle: 195.80 Maximum Range: 1054.48 Reference: Plnn: 8-216 Wp2 Scan Me,hod: tngh Side + Azimuth En~- Smfac*= Elipfical + Casbg Ri~ Wan~ngMetlmd: Rnits Based Deplh Reference: S-Pbn,. SECTXON DL~AILS SC~ ~n) t~ ~ ~V~ ~ ~' ~ ~.. VSC~ T~ West(O/East(+) [1000ft/in] 0-- ~ ~s.~o boo bm ~.~0 bGo EGO o.m EGO bGo -2500 -2000 -1500 -1000 -500 0 _ 300.00 bGO bGO 300.00 EGO EGO bGO EGO EGO [ I I ' ' I .... I .... I , , , , I ~ , , , I , , 1185.52 II.GO 225.00 !i80.58 -45..48 -64.07 1.50 32853 61.21 1649.80 17.~9 207.89 16~GO -~.40.33 -129.04 1.75 320.00 170.16 ~7 1659.80 17.99 207.89 1639.51 -14.~.GO -13648 EGO EGO 173.18 [000 -0 21~.4G 3'2.GO 207.00 21GO.29 -333.89 -229.10 175 358.Q5 383.66 ~00~ 190 3237.2~ 73.46 193..20 2734.72_ -1121.0~ -.~44 4.GO -19.70 1211.12 6079_34 73.46 193._"20 ..~41.95 -3766.97 -llff/.09 bGO EGO .3926.08 , !1 7997.49 15.7.~ 196.§l 4855.70 -5GO3.70 -141g.3,3 3.00 178.91 :5220.35 S-21~cTI 12 861646 15.73 19~.6] 5445.70 -$182.99 -146~85 bOO EGO 5~6..~ $-21GcT$ O'D) --500 1000-- 1000 - --1000 1500-- ' 000 --1500 2000-- ' 25OO-- g - --3000 ~' 3500~ --3500 4OO0-- 7000 5_4ooo . 16:TI (Top Mc) 000 --4500 i ~~:T~ crop O~d) ---5500 ~000 ''1 .... I .... I .... I .... I .... I .... I .... I .... I .... I .... I .... I .... I .... I .... I 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 Vertical Section at 195.80° [lO00ft/in] ..................... S ' cry-Sun Drilling Alaska ( Planning Report - Geographic Company: IBP Amoco Field: Prudhoe Bay Site: PBS Pad Well: Exp Slot 01 Wcilpath: Plan S-216 Date: 11/17/2000 Time: 14:08:28 Co-ordinate(NE) Reference: Well: Exp Slot 01, Tree North Vertical(TVD) Reference: S-Plans 65.7 Section (VS) Reference: Well (0.00E,0.00N,195.80Azi) Plan: S-216 Wp2 Page: Held: 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: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PBS Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5980854.54 ft 617919.92 ft Latitude: 70 21 23.002 N Longitude: 149 2 32.343 W North Reference: Tree Grid Convergence: 0.90 deg Well: Exp Slot 01 Surface Position: +NFS -350.45 ft Northing: 5980520.00 ft +E/-W 1004.73 ff Fasting: 618929.96 ft Position Uncertainty: 0.00 ff Reference Point: +NFS -350.43 ff Northing: 5980520.00 ft +FJ-W 1004.73 ft Fasting: 618929.96 ft Measured Depth: 65.70 ff Vertical Depth: 65.70 ft Slot Name: Latitude: 70 21 Longitude: 149 2 Latitude: 70 21 Longitude: 149 2 Inclination: Azimuth: 19.555 N 2.973 W 19.555 N 2.9~ W 0.000 d~ 0.000 d~ Weilpath: Plan S-216 Drilled From: Well Ref. Point Tie-on Depth: 197.10 ff Current Datum: S-Plans Height 65.70 ft Above System Datum: Mean Sea Level Magnetic Data: 11/10/2004 Declination: 25.35 deg Field Strength: 57495 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 195.802 Plan: S-216 W p2 Date Comlmsed: 11/13/2000 Version: 1 Principal: Yes Tied-to: User Defined Plan Section Information ...,., ." / '.".' :i,':';.,i;.;.....',..:,'.".. ,'.,. '. ',~ '.? '..'".'/'.',',;'.'.i:..'..': '?.": :..:,";.."'" '.'.:"'"! ,;% .% ',!' ,~";.'"'.,.': ' '.'.' ;:. ;',~:,',;;',"~,' .' '. , ."' .', ;:' "':~; . ,.' ?.'";.,'""::'.'. ",'.. '.'"": ",. "' .',..i '~ ," ,' .,- 7 , ..... : , ,, , · ,' , ,', , ' · .... . ....... .,..deg. ,.,,,,,., ,..oeg',::'?......: :. :~,,~::. ,':.,':'.,;:', ,~ ,.~'.:.,,: ~.ft .: .:, ,,.:.,,,~..,:,,,, :,,.It .,:~, ..,:::. :..,' :', ~I~: :,:d~,l~,:',d,~'~lOOft, ::.,:: '~dqg':,: :,' ~: :'.".,,,": ....... '.", '. ,: :,, ::., .,,: ..' ' ",.,',:. 65.70 0.000 0.000 65.70 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.000 0.000 300.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 2.000 250.000 499.96 -1.19 -3.28 1.00 1.00 0.00 250.00 823.62 6.000 240.000 822.73 -11.59 -23.24 1.25 1.24 -3.09 345.09 1185.52 11.000 225.000 1180.58 -45.48 -64.07 1.50 1.38 -4.14 328.53 1649.80 17.989 207.893 1630.00 -1 40.33 -129.04 1.75 1.51 -3.68 320.00 1659.80 17.989 207.893 1639.51 -143.06 -130.43 0.00 0.00 0.00 0.00 2169.46 32.000 207.000 2100.29 -333.89 -229.10 2.75 2.75 -0.18 358.05 3237.23 73.457 193.201 2734.72 -1121.02 -486.44 4.00 3.88 -1.29 -19.70 6072.34 73.457 193.201 3541.95 -3766.97 -1107.09 0.00 0.00 0.00 0.00 7997.49 15.734 196.611 4855.70 -5023.70 -1419.33 3.00 -3.00 0.18 178.91 8610.46 15.734 196.611 5445.70 -5182.99 -1466.85 0.00 0.00 0.00 0.00 S-216:T1 (TOP Mc) S-216:T5 (TD) Section I: Start Hold ' :.: ,"~V, ~' ' .. ,'~na...i':.."..':':. '.~,'..:~am!:' ?:..,...,.::...'.: '"::':,T~ ,'.',::.,/::",'.?~/..S'., ..;':": ':':~/~W':i:' :; .:~ :~ '~':: ':'X~Si.:..'"' :~'..,'.:'.,,./..i:';o~S'.'., ~'.::'./~al4,. '..:.:",!..~" .:: ':,'." ,'. T~O'.~.'i '... ': ,:?' ." ?..,:, .' . '.' '....i..:..''.fi' :" 'i":../' ,d~;':',' ' '; ".': "deg "..":', '. '.: '"' "'.'. '"::.';ff :.", ":"'"::'..':;!: '"';i.." ,;": 'i;:~t,. ':.':."'; ,: ../.~ .::..."..!.fl../' "';'?.', :' ...' ;'i:..'.' .'fi?':.".! '; ;i::':.:'::"-id~l',O~::i':'d~'! OOft ';d~i Ooff:."',. ::../: aeg,..;:.:.,: :. :.':.:.=...... 65.70 0.000 0.000 65.70 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.000 0.000 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 o.ooo o.ooo 200.00 o.oo 0.00 o.oo o.oo o.oo o.oo o.oo 300.00 0.000 0.000 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 S 'xry-Sun Drilling Alaska Planning Report - Geographic Company: BP Amoco ~ieid: PnJdhoe Bay Site: PBS Pad Well: F. xp Slot 01 Wellpa~h: Plan S-216 Date: 11/17/2000 Time: 14:08:28 Co-erdiaate(NE) Reference: Well: Exp Slot 01, True North Vertical (TVD) Reference: S-F~ans 65.7 Seetion (VS) Reference: Well (0.00E,0.00N,195.80Azi) Plma: S-216 Wp2 Page: Section 2: Star Build 1.00 MD Ind .$~m TVD +N/-S +FJ-W VS DLS Build Turn TFO ff deg deg ff ff ft ft deg/100ft deg/100ft deg/100ft deg 400.00 1.000 250.000 399.99 -0.30 -0.82 0.51 1.00 1.00 0.00 0.00 500.00 2.000 250.000 499.96 -1.19 -3.28 2.04 1.00 1.00 0.00 0.00 Section 3: Star DLS 1.25 TFO 345.09 MD lad Azim TVD +NFS +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft de~100ft deg 600.00 3.224 244.272 599.85 -3.01 -7.45 4.93 1.25 1.22 -5.73 -14.91 700.00 4.462 241.708 699.63 -6.08 -13.41 9.50 1.25 1.24 -2.57 -9.19 800.00 5.706 240.255 799.23 -10.39 -21.15 15.75 1.25 1.24 -1.45 -6.63 82.3.62 6.000 240.000 822..73 -11.59 -23.24 17.48 1.25 1.25 -1.08 -5.18 Section 4: Star DLS 1.50 TFO 328.53 MD ina ....AZm TVO . .+N/.s' .' +~W-W '. ' VS., .... DX,S:......SUad. Turn . T~O . . . . . ~' · ft . .~ 'deg.' .. d~ ' '., .. ", ,.a., .':~ ':.'. "ft '" . ..ft' .,..',,'..". ,'....ft' .. '..:':d~,100n d~100ftd~!,00f~'./' :deg ~00.00 7.003 235.089 898.62 -16.25 -~0.52 23.94 1.50 1.31 -6.43 -31.47 1000.00 8.371 2~0.473 997.72 -24.37 -41.13 34.65 1.50 1.37 <62 -26.59 1100.00 9.778 22.7.160 1096.46 -34.78 -52.97 47.89 1.50 1.41 -3.31 -22.01 1185.52 11.000 22.5.000 1180.58 ..45.48 -64.07 61.21 1.50 1.43 -2.53 -18.74 Section 5: Star DLS 1.75 TFO 320.00 "' ': MI)'".' '.'....' '.Inci," ':. ': ' ,,Azim i,' ';.",! '': ~.'..', ~rp..,..,' :.':"~ .'.'. ',.~N]~"" "i',~: '.':"i,./~F,/,,W.'. i =.','.: :.'::, ;",'/~S"',.'/..i,."=:',"?DL$ .!..','..:';,','~ld ,':'..: ",.Tarn': i'./:....~'..TFO ..: ,'.':.., '." ':', .' .~'.,'/. '. ':: ': ..' '., ',"::,,f~ ',. ':: ,,'" ,."'.', d,eg;'.=' :, '.",,..;:, ,deg'.. ,,:'!,' ,,~ :,,.:,,' .:.:,'::ft, ,:,.',.:.': "~:.,,,::: ',.",=.,~.:!'. ,~ ::::':ft.',:. ?.,:'..':',,::i,:i",:'. '::,'.fi"/:,,,';:':,?/' .',,.,. ','.fl:.". :!:.: '.':":: ,d..~,.O~:i .~1',~t ;.:d~lOOft=:.,'.': '' d:eg '"",,". :,". ' ,' '.'," ',':' '" i" ' : 1200.00 11.195 224.161 1194.79 -47.47 -66.02 63.65 1.75 1.35 -5.79 -40.00 1300.00 12.600 219.087 1292.64 -62.90 -79.66 82.22 1.75 1.40 -5.07 -39.18 1400.00 14.081 215.040 1389.94 -81.33 -93.53 103.72 1.75 1.48 -4.05 -34.21 1500.00 15.617 211.762 1486.60 -102.73 -107.60 128.15 1.75 1.54 -3.28 -30.27 1600.00 17.193 209.064 1582.53 -127.10 -121.86 155.48 1.75 1.58 -2.70 -27.10 1 649.80 17.989 207.893 1630.00 -1 40,33 -129.04 170.16 1.75 1.60 -2.35 -24.52 Section 6: Start Hold '1659.80" 'i'~.'989 207:893" 1639:5i .... ' '-'i;~3.~6 ....... -'130:;i8. '"" i":/3:'18'"""' "" "'~).00' ......... ,,0:00= , .l.,., 0:00,=,.. ,, ,.i80.00 ..... , ............... . .....,..~ Section 7: Star DLS 2.75 TFO 358.05 ,...' .. ;',,; ft. ::,,.' .. :..., .:,. ~eg., '. :,,...' .... :,,d~.':': :',": ::.::'::'= .:..;.,.'".:'i:':,:",,:,,~,...:' :".":~: :,',:' :'"" :~'.' =' ::. '.ft :;. ?: :, ?,": ,:,.:.':': ::.,ft':,,:,i,.'=,,..'' ~i.,,,~!; :::,'.' :ft...::':;'.'..'.",? =.:,:::,,.:,,= d~,:l':,~'~::d,,~'~,:,:~!~': :":,: ? :d~:' ":'. 1700.00 19.094 207.778 1677.62 -154.36 -136.45 185.68 2.75 2.75 -0.29 -1.95 1800,00 21.843 207,540 1771.30 -185,33 -152,68 219.90 2,75 2.75 -0.24 -1.84 1900.00 24.592 207.353 1863,20 -220.32 -170,64 258.51 2,75 2,75 -0.19 -1.62 2000.00 27.341 207.201 1953,09 -259.23 -190,90 301,42 2.75 2,75 -0,15 -1.45 2100,00 30,090 207,076 2040,78 -301,98 -212,82 348.52 2.75 2.75 -0.13 -1.31 2169.46 32.000 207.000 2100,29 -333.89 -229,10 383.66 2.75 2.75 -0.11 -1.20 Section 8: Star DLS 4.00 TFO -19.70 ,:".';: ': ':~o" ::,'... ,'::.' :'ina'..',,'::.: ':".":.':/,.'.'~ :,,.:.:, ::'?.'~.:,:,',. :~"::,:'.~,..:,,:.'..' :i!,':.:' .+,"~/~':.:.::::'::',':.:': .': .. '... ~" i. ;..'..... :...':,::deg ?...:...:::=,..,:.'....:..:::d.~..':..~: :':.:i:":.':.:.,.: '.!'. ?..~:.:.:..:::..::.." ?..=.".'../:..' ..:.......ft.' 2200.00 33.152 206.247 2126.03 -348.59 -236.45 399.81 4.00 3.77 -2.47 -19.70 2300.00 36.953 204.075 2207.88 -400.58 -260.83 456.46 4.00 3.80 -2.17 -19.06 2400.00 40.788 202.257 2285.72 -458.27 -285.47 518.69 4.00 3.83 -1.82 -17.29 2500.00 44.646 200.701 2359.18 -521.40 -310.27 586.18 4.00 3.86 -1.56 -15.87 2600.00 48.523 199.345 2427.90 -569.64 -335.11 658.61 4.00 3.88 -1.36 -14.73 2700.00 52.414 198.143 2491.54 -662.66 -359.87 735.62 4.00 3.89 -1.20 -13.79 2800.00 56.316 197.060 2549.79 -740.12 -384.42 816.64 4.00 3.90 -1.08 -13.03 2900.00 60.227 196.071 2602.37 -821.64 -408.65 901.87 4.00 3.91 -0.99 -12.40 3000.00 64.145 195.157 2649.02 -906.80 -432.44 990.29 4.00 3.92 -0.91 -11.88 3100.00 68.067 194.302 2689.52 -995.21 -455.68 1081.69 4.00 3.92 -0.86 -11.45 3200.00 71.994 193.493 2723.66 -1068.43 -478.24 1175.60 4.00 3.93 -0.81 -11.10 S '.cry-Sun Drilling Alaska Plannii~ Report - Geographic Comlmay: BP Amoco Field: Pmdhoe Bay Site: PBS Pad Well: ~p Slot 01 Wellgath: Plan S-216 Date: 11/17/2000 Time: 14:08:28 Co-or6inate(N~) Referea~e: Well: Exp Slot 01, True North Vertical (TVD) Reference: S-Plans 65.7 Section Cv'S) RefeFence: Well (0.00E,0.00N,195.80Azi) ~lma: S-216 Wp2 Page: Section 8: Start DLS 4.00 TFO -19.70 MD Ind ,A~m TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 3237.23 73.457 193.201 2734.72 -1121.02 -486.44 1211.12 4.00 3.93 -0.78 -10.83 Section 9: Start Hold MD Ind Azim TVD +NI-S +E/-W VS DLS Build Turn TFO ff de~ deg ft ff ff ft de~/~ 00ftde9/~ 00ft de~/100ft deg 3300.00 73.457 193.201 2752.59 -1179.60 -500.18 1271.23 0.00 0.00 0.00 180.00 3400.00 73.457 193.201 2781.06 -1272.93 -522.08 1366.99 0.00 0.00 0.00 180.00 3500.00 73.457 193.201 2809.54 -1366.26 -543.97 1 452.76 0.00 0.00 0.00 180.00 3600.00 73.457 193.201 2838.01 -1 459.59 -565.86 1558.52 0.00 0.00 0.00 180.00 3700.00 73.457 193.201 2866.48 -1552.91 -587.75 1654.28 0.00 0.00 0,00 180.00 3800.00 73.457 193.201 2894.96 -1646.24 -609.64 1750.04 0.00 0.00 0.00 180.00 3900.00 73.457 193.201 2923.43 -1739.57 -631.53 1845.80 0.00 0.00 0.00 180.00 4000.00 73.457 193.201 2951.90 -1832.90 -653.43 1941.57 0.00 0.00 0.00 180.00 4100.00 73.457 193.201 2980.37 -1926.23 -675.32 2037.33 0.00 0.00 0.00 180.00 4200.00 73.457 193.201 3008.85 -2019.55 -697.21 2133.09 0.00 0.00 0.00 180.00 4300.00 73.457 193.201 3037.32 -2112.88 -719.10 2228.85 0.00 0.00 0.00 180.00 4400.00 73.457 193.201 3065.79 -2206.21 -740.99 2324.61 0.00 0.00 0.00 180.00 4500.00 73.457 193.201 3094.27 -2299.54 -762.88 2420.38 0.00 0.00 0.00 180.00 4600.00 73.457 193.201 3122.74 -2392.86 -784.78 2516.14 · 0.00 0.00 0.00 180.00 4700.00 73.457 193.201 3151.21 -2486.19 -806.67 2611.90 0.00 0.00 0.00 180.00 4300.00 73.457 193.201 3179.68 -2579.52 -828.56 2707.66 0.00 0.00 0.00 180.00 4900.00 73.457 193.201 3208.16 -2672.85 -850.45 2803.42 0.00 0.00 0.00 180.00 5000.00 73.457 193.201 3236.63 -2766.17 -872.34 2899.19 0.00 0.00 0.00 180.00 5100.00 73.457 193.201 3265.10 -2859.50 -894.23 2994.95 0.00 0.00 0.00 180.00 5200.00 73.457 193.201 3293.57 -2952.83 -916.12 3090.71 0.00 0.00 0.00 180.00 5300.00 73.457 193.201 3322.05 -3046.16 -938.02 3186.47 0.00 0.00 0.00 180.00 5400.00 73.457 193.201 3350.52 -3139.49 -959.91 3282.24 0.00 0.00 0.00 180.00 5500.00 73.457 193.201 3378.99 -3232.81 -981.80 3378.00 0.00 0.00 0.00 180.00 5600.00 73.457 193.201 3407.47 -3326.14 -1003.69 3473.76 0.00 0.00 0.00 180.00 5700.00 73.457 193.201 3435.94 -3419.47 -1025.58 3569.52 0.00 0.00 0.00 180.00 5800.00 73.457 193.201 3464.41 -3512.80 -1047.47 3665.28 0.00 0.00 0.00 180.00 5900.00 73.457 193.201 3492.88 -3606.12 -1069.37 3761.05 0.00 0.00 0,00 180.00 6000.00 73.457 193.201 3521.38 -3899.45 -1091.26 3856.81 0.00 0.00 0.00 180.00 6072.34 73.457 193.201 3541.95 -3766.97 -1107.09 3926.08 0.00 0.00 0.00 180.00 Section 10: Start DLS 3.00TFO 178.91 ", ::'" ':;; ['.". :':ft' ,' [" i'.':':': :." ,.',,: :,"C!~ '[', ':: .:':.' ',:" "': .,:". ';~leg'"". ':'/," ?i:': :: .:,';',.:,: .:. ::!~i.~:,. i,? "].,. ::: '::~,' ?...':.' '?,~,:..' ::: :.~:: ,,?.' .,,:' ':: :': f.,'.ft ,, :.:.~.. '[, ',::.!,',, .~,, '?;', ....:,::~. :: ':~ .: ..!:..:.':~: .'~1~,~: :,..;d~,~i:~oft .,:~1~,~:~','!::. :' d~: :', ."': ::" ': .. ,., ;'/;" :.' .'.'~ :', ",: :' ?:~'. 6100.00 72.628 193.218 3550.02 -3792.72 -1113.14 3952.51 3.00 -3.00 0.06 178.91 6200.00 69.628 193.279 3582.38 -3884.82 -1134.82 4047.03 3.00 -3.00 0.06 178.90 6300.00 66.629 193.343 3519.61 -3975.12 -1156.18 4139.74 3.00 -3.00 0.06 178.88 6400.00 63.630 193.409 3661.66 -4063.37 -1177.17 4230.37 3.00 -3.00 0.07 178.86 6500.00 60.630 193.479 3708.41 -4149.34 -1197.72 4318.69 3.00 -3.00 0.07 178.83 6600.00 57.631 193.554 3759.71 -4232.79 -1217.78 4404.44 3.00 -3.00 0.07 178.80 6700.00 54.632 193.633 3815.43 -4313.48 -1237.29 4487.40 3.00 -3.00 0.98 178.76 6800.00 51.632 193.719 3875.42 -4391.21 -1256.20 4567.34 3.00 -3.00 0.09 178.72 6900.00 48.633 193.812 3939.51 -4465.75 -1274.46 4644.04 3.00 -3.00 0.09 178.66 7000.00 45.634 193.915 4007.54 -4536.90 -1292.02 4717.28 3.00 -3.00 0.10 178.60 7100.00 42.635 194.028 4079.30 -4604.47 -1308.63 4786.87 3.00 -3.00 0.11 178.53 7200.00 39.636 194.155 4154.60 -4668.27 -1324.84 4852.62 3.00 -3.00 0.13 178.45 7300.00 35.638 194.299 4233.25 -4728.12 -1340.01 4914.34 3.00 -3.00 0.14 178.38 7400.00 33.639 194.464 4315.02 -4783.87 -1354.30 4971.87 3.00 -3.00 0.17 178.24 7500.00 30.641 194.659 4399.68 -4835.35 -1367.67 5025.05 3.00 -3.00 0.19 178.11 7600.00 27.643 194.890 4487.01 -4882.44 -1380.09 5073.74 3.00 -3.00 0.23 177.94 7700.00 24.646 195.174 4576.77 -4924.99 -1391.51 5117.79 3.00 -3.00 0.28 177.74 7800.00 21.649 195.530 4668.71 -4982.89 -1401.91 5157.10 3.00 -3.00 0.36 177.49 7900.00 18.653 195.994 4762.58 -4998.05 -1411.25 5191.54 3.00 -3.00 0.46 177.16 7997.49 15.734 198.611 4355.70 -5023.70 -1419.33 5220.35 3.00 -2.99 0.63 176.72 S _ ry-Sun Drilling Alaska Planning Report- Geographic Company: BP Amooo Field: Prudhoe Bay Site: PBS Pad Well: Exp Slot 01 Welll~ath: Plan S-216 Date: 11/17/2000 Time: 14:08:28 Co-ordim~,(NE) Reterence: Well: Exp Slot 01, True North Vertical ~VD) Re~erence: S-Plans 65.7 Section CVS) Ref'eFence: Well (O.00E,0.00N,195.80A=~ Plaa: S-216 Wp2 Page: 4 Section 11: Start Hold MD Incl Azim TVD +N/-S +E/-W VS DIS Build Turn TFO ft deg deg ff ft ft ft deg/100ft deg/100ft deg/100ft deg 8000.00 15.734 196.611 4858.12 -5024.36 -1419.53 5221.04 0.00 0.00 0.00 0.00 8100.00 15,734 196.611 4954.37 -5050.34 -1427.28 5248.15 0.00 0.00 0.00 0.00 8200.00 15,734 196.611 5050.62 -5076.33 -1435.03 5275.27 0.00 0.00 0.00 0.00 8300.00 15.734 196.611 5146.88 -5102.32 -1442.78 5302.38 0.00 0.00 0.00 0.00 8400.00 15.734 196.611 5243.13 -5128.30 -1450.53 5329.50 0.00 0.00 0.00 0.00 8500.00 15.734 196.611 5339.38 -5154.29 -1458.29 5356.61 0.00 0.00 0.00 0.00 8600.00 15.734 196.611 5435.64 -5180.27 -1466.04 5383.72 0.00 0.00 0.00 0.00 8610.46 15.734 196.611 5445.70 -5182.99 -1466.85 5386.56 0.00 0.00 0.00 0.00 Survey . Map .. : . Map < .... Latitude --->.. <-- Longitude'--> MD Ind Azim . TVD +NI-S · +E/-W Northlng. Fasting .'.Deg Min Sec Deg Min'Sec .fl '..deg.....deg . . ':'ff' , . . .fl .:,' ., ft",..:., ',,ft ..... ff ............ ,.. 65.70 0.000 0,000 65.70 100.00 0.000 0.000 100.00 200.00 0,000 0,000 200.00 300.00 0.000 0.000 300.00 400.00 1.000 250,000 399.99 0.00 0.00 5980520.00 618929.96 70 21 19.555 N 149 2 2.973 W 0.00 0.00 5980520.00 618929.96 70 21 19.555 N 149 2 2.973 W 0.00 0.00 5980520.00 618929.96 70 21 19.555 N 149 2 2.973 W 0.00 0.00 5980520.00 618929.96 70 21 19,555 N 149 2 2.973 W -0.30 -0.82 5980519.69 618929.14 70 21 19.552 N 149 2 2.997 W 500.00 2,000 250.000 499.96 -1.19 -3.28 5980518.75 618926.70 70 21 19.544 N 149 2 3.069 W 600.00 3.224 244.272 599.85 -3.01 -7.45 5980516.87 618922.55 70 21 19,526 N 149 2 3.191 W 700.00 4,462 241.706 699.63 -6.08 -13,41 5980513.71 618916.65 70 21 19.496 N 149 2 3.365 W 800.00 5,706 240.255 799.23 -10.39 -21.15 5980509.28 618908.98 70 21 19.453 N 149 2 3,592 W 823.62 6,000 240.000 822.73 -11.59 -23.24 5980508.05 618906.91 70 21 19.441 N 149 2 3,653 W 900.00 7,003 235.089 898.62 -16.25 -30.52 5980503.27 618899.71 70 21 19.396 N 149 2 3.865 W 1000.00 8.371 230.473 997.72 -24.37 -41.13 5980494.98 618889.22 70 21 19,316 N 149 2 4.176 W 1100.00 9.778 227.160 1096.46 -34.78 -52.97 5980484.39 618877.55 70 21 19.213 N 149 2 4.522 W 1185.52 11.000 225.000 1180.58 -45.48 -64.07 5980473.51 618866.63 70 21 19.108 N 149 2 4,846 W 1200.00 11,195 224.161 1194.79 -47.47 -66.02 5980471.49 618864.70 70 21 19.089 N 149 2 4.903 W 1300.00 12,600 219.087 1292.64 -62.90 -79.66 5980455.85 618851.31 70 21 18.937 N 149 2 5.302 W 1400,00 14.081 215.040 1389.94 -81.33 -93.53 5980437.21 618837.74 70 21 18.756 N 149 2 5,707 W 1500.00 15.617 211.762 1486.60 -102.73 -107.60 5980415.58 618824.02 70 21 18.545 N 149 2 6.118 W 1600.00 17.193 209.064 1582.53 -127.10 -121.86 5980391.00 618810.14 70 21 18.305 N 149 2 6.535 W 1649.80 17.989 207.893 1630.00 -140.33 -129.04 5980377.65 618803.18 70 21 18,175 N 149 2 6.745 W 1659.80 17.989 207,893 1639.51 -143.06 -130.48 5980374.90 618801.78 70 21 18.148 N 149 2 6.787 W 1700.00 19.094 207,778 1677.62 -154.36 -136.45 5980363.51 618795.99 70 21 18.037 N 149 2 6,962 W 1800.00 21.843 207,540 1771.30 -185.33 -152.68 5980332.28 618780.26 70 21 17.733 N 149 2 7.436 W 1900.00 24.592 207,353 1863.20 -220.32 -170.84 5980297.02 618762.65 70 21 17.389 N 149 2 7,967 W 2000.00 27.341 207.201 1953.09 -259.23 -190.90 5980257.80 618743.21 70 21 17.006 N 149 2 8,553 W 2100.00 30,090 207,076 2040.78 -301.98 -212.82 5980214.70 618721.98 70 21 16.585 N 149 2 9.194 W 2169.46 32,000 207.000 2100.29 -333.89 -229.10 5980182.55 618706.21 70 21 16.272 N 149 2 9.670 W 2200.00 33.152 206.247 2126.03 -348.59 -236.45 5980167.73 618699.08 70 21 16.127 N 149 2 9.885 W 2300.00 36.953 204,075 2207.88 -400.58 -260.83 5980115.37 618675.54 70 21 15,616 N 149 2 10.597 W 2400.00 40.788 202.257 2285.72 -458.27 -285.47 5980057.29 618651.82 70 21 15.048 N 149 2 11.318 W 2500.00 44.646 200,701 2359.18 -521.40 -310.27 5979993.79 618628.03 70 21 14.427 N 149 2 12.042 W 2600.00 48.523 199.345 2427.90 -589.64 -335.11 5979925.17 618604.28 70 21 13.756 N 149 2 12.768 W 2700.00 52.414 198.143 2491.54 -662.66 -359.87 5979851.76 618580.68 70 21 13,038 N 149 2 13,492 W 2800.00 56,316 197.060 2549.79 -740.12 -384.42 5979773.93 618557.37 70 21 12,276 N 149 2 14.210 W 2900.00 60.227 196.071 2602.37 -821.64 -408.65 5979692.05 618534.43 70 21 11.475 N 149 2 14.918 W 3000.00 64.145 195.157 2649.02 -906.80 -432.44 5979606.52 618512.00 70 21 10:637 N 149 2 15.613 W 3100.00 68,067 194.302 2689.52 -995.21 -455.68 5979517.76 618490.18 70 21 9,767 N 149 2 16.292 W 3200.00 71.994 193.493 2723.66 -1086.43 -478.24 5979426.20 618469.07 70 21 8,870 N 149 2 16.951 W 3237.23 73.457 193.201 2734.72 -1121.02 -486.44 5979391.49 618461.41 70 21 8.530 N 149 2 17.191 W 3300.00 73,457 193.201 2752.59 -1179.60 -500.18 5979332.70 618448.61 70 21 7.954 N 149 2 17.592 W 3400.00 73,457 193.201 2781.06 -1272.93 -522.08 5979239.05 618428.20 70 21 7,036 N 149 2 18.232 W 3500.00 73,457 193.201 2809.54 -1366.26 -543,97 5979145.39 618407.79 70 21 6.118 N 149 2 18.871 W S _cry-Sun Drilling Alaska Planning Report- Geographic Comlmuy: BP Amoco Field: Pmdhoe Site: PBS Pad Well: Exp Slot 01 Wellpalh: Plan S-216 Date: 11117/2000 Time: 14:08:28 Co-otnliaate(Nl!;) Reterenm: Well: Exp Slot 01, True North Vertical(TVD) Retereace: S-Plans 65.7 Section O/S) Reference: Well (0.00E,0.00N,195.80Azi) Plan: S-216 Wp2 P~ge: 5 Survey Map Map <~ Latitude ---> <-- Longitude--> MD Inel A~m TVD +NI-8 +E/-W Northin~o Easting Deg Min ~ec Deg Min Sec ft deg deg ft ft ft ff ft 3600.00 73.457 193.201 2838.01 -1459.59 -565.86 5979051.74 618387.39 70 21 5.200 N 149 2 19.511 W 3700.00 73.457 193.201 2866.48 -1552.91 -587.75 5978958.08 618366.98 70 21 4.282 N 149 2 20.151 W 3800.00 73.457 193.201 2894.96 -1646.24 -609.64 5978864.43 618346.58 70 21 3.365 N 149 2 20.790 W 3900.00 73.457 193.201 2923.43 -1739.57 -631.53 5978770.77 618326.17 70 21 2.447 N 149 2 21.430 W 4000.00 73.457 193.201 2951.90 -1832.90 -653.43 5978677.11 618305.77 70 21 1.529 N 149 2 22.069 W 4100.00 73.457 193.201 2980.37 -1926.23 -675.32 5978583.45 618285.38 70 21 0.611 N 149 2 22.709 W 4200.00 73.457 193.201 3008.85 -2019.55 -697.21 5978489.80 618264.96 70 20 59.693 N 149 2 23.348 W 4300.00 73.457 193.201 3037.32 -2112.88 -719.10 5978396.15 618244.55 70 20 58.775 N 149 2 23.988 W 4400.00 73.457 193.201 3065.79 -2206.21 -740.99 5978302.49 618224.15 70 20 57.857 N 149 2 24.627 W 4500.00 73.457 193.201 3094.27 -2299.54 -762.88 5978208.64 618203.74 70 20 56.939 N 149 2 25.267 W 4600.00 73.457 193.201 3122.74 -2392.86 -784.78 5978115.18 618183.34 70 20 56.021 N 149 2 25.906 W 4700.00 73.457 193.201 3151.21 -2486.19 -806.67 5978021.53 618162.93 70 20 55.104 N 149 2 26.546 W 4800.00 73.457 193.201 3179.68 -2579.52 -828.56 5977927.87 618142.52 70 20 54.186 N 149 2 27.185 W 4900.00 73.457 193.201 3208.16 -2672,65 -850.45 5977834.21 618122.12 70 20 53.268 N 149 2 27.825 W 5000.00 73.457 193.201 3238.63 -2766.17 -872.34 5977740.56 618101.71 70 20 52.350 N 149 2 28.464 W 5100.00 73.457 193.201 3265.10 -2859.50 -894.23 5977646.90 618081.31 70 20 51.432 N 149 2 29.103 W 5200.00 73.457 193.201 3293.57 -2952.83 -916.12 5977553.25 618060.90 70 20 50.514 N 149 2 29.743 W 5300.00 73.457 193.201 3322.05 -3046.16 -938.02 5977459.59 618040.50 70 20 49.596 N 149 2 30.382 W 5400.00 73.457 193.201 3350.52 -3139.49 -959.91 5977365.94 618020.09 70 20 48.678 N 149 2 31.021 W 5500.00 73.457 193.201 3378.99 -3232.81 -981.80 5977272.28 617999.69 70 20 47.760 N 149 2 31.661 W 5600.00 73.457 193.201 3407.47 -3326.14 -1003.69 5977178.62 617979.28 70 20 46.843 N 149 2 32.300 W 5700.00 73.457 193.201 3435.94 -3419.47 -1025.58 5977084.97 617958.88 70 20 45.925 N 149 2 32.939 W 5800.00 73.457 193.201 3464.41 -3512.80 -1047.47 5976991.31 617938.47 70 20 45.007 N 149 2 33.578 W 5900.00 73.457 193.201 3492.88 -3606.12 -1089.37 5976897.66 617918.08 70 20 44.089 N 149 2 34.218 W 6000.00 73.457 193.201 3521.35 -3599.45 -1091.26 5976804.00 617897.66 70 20 43.171 N 149 2 34.857 W 6072.34 73.457 193.201 3541.95 -3766.97 -1107.09 5976736.25 617882.90 70 20 42.507 N 149 2 35.319 W 6100.00 72.628 193.218 3550.02 -3792.72 -1113.14 5976710.40 617877.26 70 20 42.254 N 149 2 35.496 W 6200.00 69.628 193.279 3582.36 -3884.82 -1134.82 5976617.98 617857.05 70 20 41.348 N 149 2 36.129 W 6300.00 66.629 193.343 3819.61 -3975.12 -1156.18 5976527.35 617837.12 70 20 40.460 N 149 2 36.753 W 6400.00 63.630 193.409 3561.66 -4063.37 -1177.17 5976438.79 617817.54 70 20 39.592 N 149 2 37.365 W 6500.00 60.630 193.479 3708.41 -4149.34 -1197.72 5976352.52 617798.38 70 20 38.746 N 149 2 37.965 W 6600.00 57.631 193.554 3759.71 -4232.79 -1217.78 5976268.77 617779.63 70 20 37.925 N 149 2 38.551 W 6700.00 54.632 193.633 3815.43 -4313.45 -1237.29 5976187.78 617761.40 70 20 37.132 N 149 2 39.121 W 6800.00 51.632 193.719 3875.42 -4391.21 -1256.20 5976109.77 617743.73 70 20 35.367 N 149 2 39.873 W 6900.00 48.633 193.812 3939.51 -4465.75 -1274.46 5976034.96 617726.66 70 20 35.634 N 149 2 40.206 W 7000.00 45.634 193.915 4007.54 -4536.90 -1292.02 5975963.54 617710.23 70 20 34.934 N 149 2 40.718 W 7100.00 42.635 194.028 4079.30 -4604.47 -1208.83 5975895.72 617694.50 70 20 34.270 N 149 2 41.209 W 7200.00 39.636 194.155 4154.60 -4668.27 -1324.84 5975631.68 617679.50 70 20 33.642 N 149 2 41.877 W 7300.00 38.638 194.299 4233.25 -4728.12 -1340.01 5975771.60 617665.28 70 20 33.054 N 149 2 42.120 W 7400.00 33.639 194.464 4315.02 -4783.87 -1354.30 5975715.64 617651.88 70 20 32.505 N 149 2 42.537 W 7500.00 30.641 194.659 4399.68 -4835.35 -1387.67 5975663.95 617639.33 70 20 31.999 N 149 2 42.927 W 7600.00 27.543 194.890 4487.01 -4882.44 -1380.09 5975616.68 617627.67 70 20 31.536 N 149 2 43.289 W 7700.00 24.546 195.174 4576.77 -4924.99 -1391.51 5975573.96 617616.92 70 20 31.117 N 149 2 43.623 W 7800.00 21.649 195.530 4568.71 -4962.89 -1401.91 5975535.89 617607.13 70 20 30.745 N 149 2 43.926 W 7900.00 18.653 195.994 4762.58 -4996.05 -1411.25 5975502.60 617598.31 70 20 30.419 N 149 2 44.199 W 7997.49 15.734 196.611 4855.70 -5023.70 -1419.33 5975474.82 617590.68 70 20 30.146 N 149 2 44.435 W 8000.00 15.734 196.611 4858.12 -5024.35 -1419.53 5975474.16 617590.49 70 20 30.140 N 149 2 44.441 W 8100.00 15.734 196.611 4954.37 -5050.34 -1427.28 5975448.06 617583.15 70 20 29.884 N 149 2 44.667 W 8200.00 15.734 196.611 5050.62 -5076.33 -1435.03 5975421.96 617575.82 70 20 29.629 N 149 2 44.893 W 8300.00 15.734 196.611 5146.88 -5102.32 -1442.78 5975395.85 617688.48 70 20 29.373 N 149 2 45.120 W 8400.00 15.734 196.611 5243.13 -5128.30 -1450.53 5975369.75 617561.14 70 20 29.118 N 149 2 45.346 W 8500.00 15.734 196.611 5339.38 -5154.29 -1458.29 5975343.65 617553.80 70 20 28.862 N 149 2 45.572 W 8600.00 15.734 196.611 5435.64 -5180.27 -1466.04 5975317.54 617546.46 70 20 28.607 N 149 2 45.799 W S rry-Sun Drilling Alaska ( Planning Report- Geographic com~m~: BP Amoco Field: Prudhoe Bay Site: PBS Pad Well: Exp Slot 01 Wellpath: Plan S-216 Date: 11/17/2(X)0 Time: 14:08:28 Ce-enliaate(N]D Reference: Well: Exp Slot 01, Tree North Verlieal (TVD) Reference: S-Plans 65.7 Seelton (VS) Reference: Well (0.00E,0.00N,195.80Azi) Plan: S-216 Wp2 Page: 6 Survey Map Map <-- Latitude ---> <-- Longitude ~> MD Ind /,,~m TVD +N/-S +E/-W Normlng Easting Deg Min Sec Deg Min Sec ff deg deg ff ff ft ff ff 8610.46 15.734 196.611 5445.70 -5182.99 -1466.85 5975314.81 617545.70 70 20 28.580 N 149 2 45.822 W Targets Map Map <--- Latitude ....> <-- Longitude ---> Name Description TVD +N/-S +F../-W Northing Fasting Deg Min Sec Deg Min Sec ft ft ft ft ft S-216:T5 (TD) 5445.70 -5182.99 -1466.85 5975314.81 617545.70 70 20 28.580 N 149 2 45.822 W -Circle (Radius: 200) -Plan hit target S-216:T1 (Top Mc) -Circle (Radius: 200) -Plan hit target S-216:T4 (Base OBf) -Circle (Radius: 200) -Plan out by 1.07 at $-216:T2 (Top OA) -Circle (Radius: 200) -Plan out by 1.74 at S-216:T3 (Top OBd) -Circle (Radius: 200) -Plan out by 1.81 at 4855.70 -5023.70 -1419.33 5975474.82 617590.68 70 20 30.148 N 149 2 44.435 W 5375.70 -5163.07 -1461.53 5975334.81 617550.69 70 20 28.776 N 149 2 45.667 W 5375.70 -5164.09 -1461.21 5975333.80 617551.03 70 20 28.768 N 149 2 45.658 W 5030.70 -5071.47 -1435.09 5975426.82 617575.68 70 20 29.677 N 149 2 44.895 W 5030.70 -5070.95 -1433.42 5975427.36 617577.33 70 20 29.682 N 149 2 44.846 W 5225.70 -5123.23 -1450.90 5975374.82 617560.69 70 20 29.168 N 149 2 45.357 W 5225.70 -5123.60 -1449.13 5975374.48 617562.47 70 20 29.164 N 149 2 45.305 W Casing Points 10000.00 0.00 7.000 8.500 Case2 WI~,L DETAH~ Name +lqt-S +FJ-W Non,rig FasOg La~mde Longitude Slot Exp Slot 0B$0.43 1004.73 5980~=20.00 618929.e~6 70-'21'19.555N 149:02'= 0P=.972W --182 --175 --150 --125 --50 --25 --0 --25 --50 --75 --125 --150 --175 --182 21 50 ANTI-COLLISION SETrlNGS Interpolation Method'.MD Interval: 100.00 Depth Range Fron~ 65.70 To: 8610.46 Maxinmm Range: 1054.48 Reference: Plan: g-216 Wp2 SURVEY PROGR,Ud DepdtFm DeplhTo Su~-eysPhn Tool 65.708610.46 Planned: S-216 Wp2 VI MW[} From Colour To MD 0 5OO 500 1000 1000 ' 1500 1500 2500 2500 5000 5000 7500 7500 10000 10000 ' 50000 From Colour To MD 0 5O0 500 1000 1000 1500 1500 25O0 2500 5000 5000 7500 7500 '-- 1o000 10000 50000 0 -5.0 . -15.0 -20.0 21 ]~~~~~50 [70 High Side + Rcf. Azimuth [deg] vs Centre to Centre Separation [15ft/in] High Side + RcL Azimuth [dcg] vs CentTc to Centre Separation [75ft/in] J J-~'.iF. NJ) ~ % I:; .~ I.I Mdl['l RI'I, n O:AI iii t% P Af I1.. ~., ~ ~a -- ~.,.?,,~, I,,~7~..~" I~l ,~ I~'ll BI M~i'¢ Ii,~l -- ~ ,11~,~ I,"~l'l' ~ '~.% I~, % ' "% I '. ~a~ ~ % '"; .% I ~, Map t b as ~ hi % k;. Ma~ f P .k ~ III:., III g. Mas R ~ % tldill .% [.J III. ~a~ f H 'k S-~ (R.~ ~r R~k Phil ~-216 ~.216 Wp2 $I'.'CTION DI~,MLS Sec MD Inc Azi T~) N~ I-~VI~].,e8 TI:aceVSec Tafg~ / 65,700.000.00 6.q.700.00 0.00 0.00 0.(]0 ')_300,00 0.000.00 .UX).O0 0.00 O.(X) GOO0.00 0.~0 3 500,00 2.002.~).00 499.96-I.19 -3.28 1.00 2 .q).00 2.04 823,62 6.00240.00 822.72-11.$9-23.24I.Z~i .~14.q.t~) 17.48 5 1185,~2 II.00 =~=5.00 1180.58 -45.48-64.071.50 3285.161.21 1649.$O 17.99 207.89 1630.00 -140.?,2 -129.O1 1.75 320.~0170.16 1659.80 17.99 207.89 1639.51 -142.06 -L10.480.00 0.00 17.1.18 2169.46 32.00 207.00 2100.~ -333.~-229.102.75 .~.~fl.~ .183.f~ 90 3237.22 '/3.46 i 93.20 2734.?2 -1121.02 -486.44-L~O -19.70 1211.12 6072.34 '/3.46 193.='20 3541.95 -3766.9'/ - I 1(~.09 0.00 0.00 .~926.(J8 11 7997.49 15.'/3 196.61 48.~i$."/0 ~q1~3.70 -1419333.00 178.91 5220 35 S-216:TI lTop Mc) 12 8610,46 15.73 196.61 5445.70 ~152.99 .1466.85 0.000.005.~656 S-216:TS('fD) S-216 Kick Tolerance 11/19/2000 2:26 PM S-216 <== Data ~nput Phil Smith <== Data Input Mud Weight (ppg) 10.50 Well Plans: Mud Wt. = Zone of interest pore pressure Weak point - Measured depth (fl) Weak point - True vertical depth (fl) Weak point - Hole angle (deg] Weak point - Hole size (in) Weak point pressure - EMW (ppg) 3,300' 2,670' 73.0° 8.750" 12.50 Zone of interest - Measured depth (fl) Zone of interest - True vertical depth (ft) Zone of interest - Hole angle (deg) Zone of'interest - Hole size (in) Zone of interest - Pore pressure EMW (ppg) 7,775' 4,650' 20.0° 8.750" 9.90 Gas gradient (psi/fl) 0.10 Bottom hole assembly OD (in) Bottom hole assembly length (ft) Drill pipe OD (in) 6.750" 200' 4.000" BHA annular vol. O zone of interest (bbl/fl) DP annular vol. @ zone of interest (bbl/ft) DP annular vol. @ weak point (bbl/fl) 0.0301 0.0588 0.0588 <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input safety margin (psi) 0.00 <== Data Input Weak point pressure (psi): Plo 1,736 psi Weak point pressure - Safety margin: Pmax 1,736 psi Pmax EMW 12.50 ppg Max anticipated formation pressure (psi): Pf 2,394 psi Weak Pt to Zone of Interest distance (TVD ft): OH {rVD} 1,980' Weak Pt to Zone of Interest distance (MD fl): OH {MD} 4,475' Maximum influx height at the bit (TVD ft): H {TVD} 948' Maximum influx height at the bit (MD fl): H {MD} 1,009' Calc. volume of {H} around BHA: Vlbha Calc. volume of {H} around drill pipe: Vldp 6.0 bbl 47.6 bbl Calc. volume that H equals @ initial shut in: Vl 53.6 bbl vol. that H equals @ weak point (MD fl): Vwp 190.7 bbl Calc. volume of Vwp @ initial shut in: V2 138.3 bbl Kick Tolerance: V1 53.6 bbl Initial SICP which equals the Weak Point Pressure: NOTE: Spreadsheet Created by: G. $. Walz 11/22/94 278 psi PAY '""'-',,.ii~= !~~E~i '""">':~' .... x-'-'_ : ..~-. ~>.'&: ,-::~ ;-'.:' ..... ~':'.'.-'-'.' .... '"'- ,-."'. '' +; .... '-.-', ...... ":.,4 .-'- ':':.f'. '- -':'..,' .... . '. .... ' ..' :' :"" .... : ::-" .'-'- '- .... -'-.:::~::?~ ' "Y~- ' '.'-'-'~'"-~- "- -: -- ' ' ~' "<'"-: .' - --~":'.~:-;L-"~' - :- ':: .... "':.- '- - ", '.--- .... -'--. 13 .-::' ?. & ;:~i:../.-1-00~-~.. ~~~~~.~--~~~~ .L..Lt.~; DQILi.:~R :..: .:'.i-.-': :--.~-- · .".:&.':' :::';.T :::.2'~:" '-:--,&?. '-¥ ,. - ~.~:':.':-::::-. ,-!:~:: -'--- .. ' ' ' . - .,.. :' :i ';- .-:. !? . '-':;:::'. -: ::-":.'"~i. .r~'q~-.-,"$:'~ ' ' - ." · ' ' .'- : - '"-:~::"--x .fXe.' ' ::':"::-~ :-'-'----' ' -;.--'.:.-: :~:~' ~:'-]'.-!:~:*~'-- : " '- ~-:::':' ',:'-."."-':' :::.'-:..~' - :':':3 ":.'¥-:~:.'~.;.'~-":: ' ' '-- -"': ':~.:.:~;~'-:,,':- :.:-'--' ' .' :-.:,-~- .-.$.?'- ..... ;- '"--'- .".:x',: -' .... ·-. :.,.-... <-'-- '.'~....~: ..:'._:',:' -':.-x .-~:,:-:"'-:: . '.-..'' -"- : : ::~?~.:i:~~- '.~?i:-:' ' '<'~-~:"'::::.'?. ' :~/:.:'.':?,::-ii~'"'- ". ':-"' DATE- ."¢":'i!~'; - ':;:,k~.'.'-.'-.":":'";'i: ;- :'.: -'-.-'-';~4i~AMOUNT:''- :- "~: '-' - · 'i .' ' . ". ' ::':--.. "' ".::-i' -"" toi:ao!o0: ~!$!~: .' ~:.-.¥. '. -.. ::-::':' .'~::: -':-: ;~.~,~ N~.A.'LID AFTER'i20DAYS ~A.:: ": ,.& :'-~::- -:- -' . ':-:':~:- ' .{~:'-'.':.:- :-.'1 - ':.::.-'.-'~,'::[' .-:~::~,-'-.'-' :'-'.¢:-':.;:"~:~: '~--'-.'~ ..~-:~:4-~'".-:-::.'~ ' - ; -~ . "-- ':!:'-: .::-'..".: .:'-" :.-'-.'.-'-'.~ .' '.'.-'.~; . ~ ~..:.!i-.'~-':] '::.:-,:_.-.:.-:-" ::-'.--.::- :._-. · .' :'::'.-,.: ~'--"- . . . ': .". - ~:: - -"-':':--4- ; -:. ".T: :--:.::' ' --:: :- '! '.."::~_;':: ':'-.x-. :'- · '$' - ' .'::-.. '. ":':. ' - .::-':':-~ . -' '- - ' :~ ~:;; 'x '% -~":' -~ ' ""~'-'.i' .'-- ' ~ ' '"~"'.: :::1'~" '~.?-'-" 'i-_::-: .~.::-'~ .:' -. :::;.':'. '.-:..'.:;.' .-' .-':-~': r~-I . .. · ...ii:.-..'.-.,.:..-.:...--.-..:.'..'..:..:..~. - .:.'.g:.. :: . ::.~.'.:--,-.a:L ~,.~.~--:.:. .... 4.. ~'.- :- "' '1:,~;:? I': ' · - -;:"-:-'~' ?''-:' ':<:" '.:' "; "::" ' - ;~ ~: '.':'L,:. ' . '. ~ .-: ' ..'_~::<: .:: !:.' . ...,- · - . ' . ~.'_...::..'.,.. - - -c.;..... ~..::~_, - · : .~...~-.:1~,.: .-- ',--:.:- - -? ·: .:-~. . .'...- . -~':.:~- . ' ..- ~- -- - ..z'. -' -. - · - - - .~: ~ ::'-. -':-'-:'...---:.'.. "-:$.--;t~'.--k;:!- .-~..~i'-:!.'-':?.:.-.":. -- --:. :::.; .... ..';' -~ -..- -.:-..: ~.~:.':.;':_-: '""-' ' .':'~,'_ .... ~'::: .:-' --~~a~::.';:l .... ' ' ":%"';':.i .-_" -" -' "' '" ' .: ' :" .-': I I WELL PERMIT CHECKLIST FIELD & POOL ~ ADMINISTRATION WELL NAME v~ redrll COMPANY PROGRAM: exp dev serv wellbore sag ann. disposal para req INIT CLASS ~~ GEOL AREA ~~ UNIT# ~~ ON/OFF SHORE ~ 1. Permit fee attached ........................ ~.. N , ' ' ~_,, ~ 2. Lease number appropriate.'~...~--~. ~i'*/~Z~ //.O.. ';t~!,Y-~ N ~ ~,~/~.e-V~ ~/'~Z:>4...~Z-_~Z..~'-'/~; ~~-~'~" ~, ~5,,~5,/~_-i~- ,~.~.~ . 3. Unique well name and number. ~. ~ ............. '~_ .~N ~ .°~_..~ ~. .~: ~ ~ ~ ~~~~'~ ~ ~( ~ ~ 4. Welllo~tedinadefinedpool:~'. .............. ~ ~ ~ ~~/, -~ ~ . ~,, · / /~ 5. . . . N '~ ~/~/~ ~/ ~ ~~'.~ APPR . 7. 8. 9. 10. 11. DATE, 12. ENGINEERING Well located proper distance from ddlling unit boundary. Well located proper distance from other wells .......... GEOLOGY Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can. be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long stdng to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ............ ' ..... 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ..... .~..;.~.~ ....... 26. BOPE press rating appropriate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown .... ~ ...... 29. Is presence of H=S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measur,~es.~. . · 31. Data presented on potential overpressure zones ~.... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) Contact name/phone for weekly progress reports 32. DATE 33. I'l , z;,-t , N V N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR. DATE (B) will not contaminate freshwater; or cause drilling waste... to surface;' (C) will not impair mechanical integrity of the well used for disposali (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20' AAC 25.412. GEOLOGY: Y N Y N Y N Y N Y N Y N ENGINEERING:.. UlClAnnular COMMISSION: .' comments/InStructions: Z .-I Z: c:Vnsoffice\wordian~diana~checklist (rev. 111011100) Well History File APPENDIX Information of detailed nature that is not particularly germane 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 APPEN. DIX. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri May 25 11:13:12 2001 Reel Header Service name ............. LISTPE Date ..................... 01/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............. LISTPE Date ..................... 01/05/25 Origin...~..., .... . ........ STS Tape Name ................. UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-00296 S. HUIBAN G. KIDD S-216 500292298900 BP Exploration (Alaska) Inc. Sperry Sun 24-MAY-01 MWD RUN '4 AK-MM-00296 S. HUIBAN D. FERGUSON 35 12N 12E 4316 4500 .00 28.25 36.00 iST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 109.0 8.750 9.625 3571.0 7.000 8698.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN i IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBES. 4. MwD RUNS 2 AND 3 WERE HOLE OPENERS. NO DATA WILL BE PRESENTED. 5. MWD RUN 4 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO-DENSITY (SLD). 6. DEPTH SHIFTING IS WAIVED PER THE E-MAIL OF 4/5/2001 FROM D. SCHNOOR OF BP EXPLORATION (ALASKA) INC. LOG AND HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 7. MWD RUNS 1 AND 4 REPRESENT THE MWD DATA FOR WELL S-216 WITH API % 50-029-22989-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8713' MD, 5625' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY .(EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVE'D RESISTIVITY (SHALLOW . SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SPSF = SMOOTHED POROSITY SANDSTONE FORMATION CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75 IN MUD WEIGHT: 10.5 PPG MUD SALINITY: 160-400 PPM FORMATION WATER SALINITY: 28,000 PPM FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 404.0 8684.0 RO? 459.0 8712.5 FET 3531.0 8656.5 RPD 3531.0 8656.5 RPM 3531.0 8656.5 RPS 3531.0 8656.5 RPX 3531.0 8656.5 NCNT 3538.5 8664.0 NPHI 3538.5 8664.0 FCNT 3538.5 8664.0 PEF. 3548.0 8673.0 DRHO 3568.0 8673.0 RHOB 3568.0 8673.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIF~ED.DEPTH 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 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 404.0 3587.0 4 3530.5 8712.5 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET RHOB DRHO PEF NPHI NCNT FCNT Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 MWD G/CC 4 1 68 MWD G/CC 4 1 68 MWD B/E 4 1 68 MWD PU 4 1 68 MWD CP30 4 1 68 MWD CP30 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8' 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 404 8712.5 ROP MWD FT/H 0 2024.12 GR MWD API. 17.48 133.59 RPX MWD OHMM 0.27 377.53 RPS MWD OHMM 0.26 2000 RPM MWD OHMM 0.27 2000 RPD MWD OHMM 0.06 2000 FET MWD HOUR 0.2717 386.004 RHOB MWD G/CC 1.228 3.068 DRHO MWD G/CC -0.189 0.413 PEF MWD B/E 0.23 13.05 NPHI MWD PU 14.75 76.62 NCNT MWD CP30 2008 3779 FCNT MWD CP30 402 1032 Mean Nsam 4558.25 16618 128.757 16508 70.3938 16561 10.4506 10252 11.3726 10252 14.4017 10252 14.4513 10252 5.17863 10252 2.20843 10211 0.0538931 10211 3.12392 10251 42.5132 10252 2676.12 10252 548.511 10252 First Reading 404 459 404 3531 3531 3531 3531 3531 3568 3568 3548 3538.5 3538.5 3538.5 Last Reading 8712.5 8712.5 8684 8656.5 8656.5 8656.5 8656.5 8656.5 8673 8673 8673 8664 8664 8664 First Reading For Entire File .......... 404 Last Reading For Entire File ........... 8712.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name.... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 ' File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 404.0 ROP 459.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3530.0 3587.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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): 12-DEC-00 Insite 5.46 Memory 3587.0 6.0 69.8 TOOL NUMBER PB01738CG8 3571.0 Spud Mud 9.20 320.0 9.1 400 13.2 .000 .000 .000 .000 .0 76.5 .0 .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 .liN 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 MWD010 FT/H ' 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 404 3587 1995.5 6367 ROP MWD010 FT/H 0.3 402.3 102.093 6257 GR MWD010 A?I 24.55 127.92 71.4117 6253 First Reading 404 459 404 Last Reading 3587 3587 3530 First Reading For Entire File .......... 404 Last Reading For Entire File ........... 3587 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1-.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File 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 ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3530.5 8684.0 FET 3531.0 8656.5 RPD 3531.0 8656.5 RPM 3531.0 8656.5 RPS 3531.0 8656.5 RPX 3531.0 8656.5 NCNT 3538.5 8664.0 NPHI 3538.5 8664.0 FCNT 3538.5 8664.0 PEF 3548.0 8673.0 DRHO 3568.0 8673.0 RHOB 3568.0 8673.0 ROP 3587.5 8712.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON $ 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: 22-DEC-00 Insite 65.44 Memory 8713.0 14.7 70.3 TOOL NUMBER PB01766HRANLGV6 PB01766HRANLGV6 PB01766HRANLGV6 8698.0 LSND 10.50 51.0 9.2 700 4.8 5. 600 3.934 3.000 3.200 69.0 101.1 69.0 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub'type...0 SANDSTONE 2.65 Name Service Order Units Size 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 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 RHOB MWD040 G/CC 4 1 68 32 9 DRHO MWD040 G/CC 4 1 68 36 10 PEF MWD040 B/E 4 1 68 40 11 NPHI MWD040 PU 4 1 68 44 12 NCNT MWD040 CP30 4 1 68 48 13 FCNT MWD040 CP30 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR RHOB MWD040 G/CC DRHO MWD040 G/CC PEF MWD040 B/E NPHI MWD040 PU NCNT MWD040 CP30 FCNT MWD040 CP30 Min Max M~an Nsam 3530.5 8712.5 6121.5 10365 0 2024.12 145.033 10251 17.48 133.59 69.7706 10308 0.27 377.53 10.4506 10252 0.26 2000 11.3726 10252 0.27 2000 14.4017 10252 0.06 2000 14.4513 10252 0.2717 386.004 5.17863 10252 1.228 3.068 2.20843 10211 -0.189 0.413 0.0538931 10211 0.23 13.05 3.12392 10251 14.75 76.62 42.5132 10252 2008 3779 2676.12 10252 402 1032 548.511 10252 First Reading 3530.5 3587.5 3530.5 3531 3531 3531 3531 3531 3568 3568 3548 3538.5 3538.5 3538.5 Last Reading 8712.5 8712.5 8684 8656.5 8656.5 8656.5 8656.5 8656.5 8673 8673 8673 8664 8664 8664 First Reading For Entire File .......... 3530.5 Last Reading For Entire File ........... 8712.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/05/25 Origin ......... , .......... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/05/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File