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Home My WebLink About200-0657. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU H-16B OA Downsqueeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-065 50-029-20592-02-00 12652 Surface Intermediate Liner Liner Liner 8977 2637 8650 1068 1531 2657 12340 13-3/8" 9-5/8" 7" 4-1/2" 2-7/8" 8981 27 - 2664 26 - 8676 8513 - 9581 9419 - 10950 9995 - 12652 27 - 2664 26 - 7968 7837 - 8513 8423 - 8939 8814 - 8977 Unknown 2670 4760 5410 7500 13890 12340 5380 6870 7240 8430 13450 10820 - 12536 4-1/2" 12.6# 13cr80, L80 24 - 9419 8923 - 8978 Conductor 80 20" x 30" 28 - 108 28 - 108 4-1/2" Baker S3 Packer 9363, 8391 9221, 9363 8309, 8391 Torin Roschinger Operations Manager Josh Stevens josh.stevens@hilcorp.com 907-777-8420 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028284 24 - 8423 OA at surface Downsqueezed 12-bbls 15.8-ppg thixotropic cement with final squeeze pressure of 274-psi. 360 682 17058 2744 2132 7672 925 1507 1218 471 323-337 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 9221, 8309 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:17 pm, Aug 21, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.21 13:54:55 -08'00' Torin Roschinger (4662) DSR-8/21/23 RBDMS JSB 082923 WCB 4-8-2024 ACTIVITY DATE SUMMARY 8/3/2023 Removed OA Gate Valve. Removed Flange and VR Plug from Companion OA. Installed Integrals with Block valves and 1502 caps on both side of OA. 8/13/2023 T/I/O LRS unit 70 Assist Cementers (CEMENT SQUEEZE OA/IASWNSQZ) OA down squeeze. 5bbl 120deg diesel, 15bbl surf wash, 1bbl FW, 9bbl 15.8 thixotropic cement and perform hesitations at 1/4bbl increments in attempt to get squeeze. Able to get positive pressure during hesitations up to 274psi. Pumped a total of 12 bbls of cement. RDMO **Complete** 8/16/2023 ***WELL S/I ON ARRIVAL***(glv c/o, pull ttp) RAN 4-1/2" BAIT-SUB, 2.5" JUS PULL P-PRONG @ 9,244' SLM PULL ST# 3 RK-DGLV @ 6,163' MD PULL ST# 4 RK-DGLV @ 3,659' MD SET ST# 4 RK-LGLV (16/64" ports, 1500 tro) @ 3,659' MD SET ST# 3 RK-OGLV (20/64" ports) @ 6,163' MD PULL PX-PLUG BODY FROM X-NIP @ 9,254 ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU H-16B () OA down squeeze. 5bbl 120deg diesel, 15bbl surf wash, 1bbl FW, 9bbl 15.8 g thixotropic cement and perform hesitations at 1/4bbl increments in attempt to getg squeeze. Able to get positive pressure during hesitations up to 274psi. Pumped ag total of 12 bbls of cement. RDMO 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU H-16B OA Downsqueeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-065 50-029-20592-02-00 341J ADL 0028284 12652 Surface Intermediate Liner Liner Liner 8977 2637 8650 1068 1531 2657 9254 13-3/8" 9-5/8" 7" 4-1/2" 2-7/8" 8328 27 - 2664 26 - 8676 8513 - 9581 9419 - 10950 9995 - 12652 2320 27 - 2664 26 - 7968 7837 - 8513 8423 - 8939 8814 - 8977 Unknown 2670 4760 5410 7500 13890 9254, 12340 5380 6870 7240 8430 13450 10820 - 12536 4-1/2" 12.6# 13cr80, L80 24 - 94198923 - 8978 Conductor 80 20" x 30" 28 - 108 28 - 108 4-1/2" Baker S3 Packer 4-1/2" Baker S3 Packer 9221, 8309 9363, 8391 Date: Torin Roschinger Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 PRUDHOE BAY 6/23/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:46 pm, Jun 09, 2023 323-337 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.09 14:37:21 -08'00' Torin Roschinger (4662) DSR-6/13/23MGR22JUN23SFD 6/14/2023 2320 10-404 GCW 06/22/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.23 09:08:49 -08'00'06/23/23 RBDMS JSB 062723 Well: H-16B Current PTD: 200-065 Well Name:H-16B API Number:50-029-20592-02-00 Current Status:Not Operable PAL Rig:FB, SL Estimated Start Date:6/23/2023 Estimated Duration:3days Sundry #Date Approval Rec’vd: Regulatory Contact:Abbie Barker PTD Number:200-065 First Call Engineer:Josh Stephens 970-779-1200 (Cell) Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: Kill Weight Fluid Min ID: 3155 psi @ 8,800’ TVD 3200 psi @ 8,800’ TVD 2320psi 7.1ppg 2.28” at 9,995’ MD (Based on SBHPS on 3/22/06) (Based on) (Based on .1psi/ft gas gradient) Brief Well Summary: H-16B is a gas lifted Ivishak producer that is currently not operable for having a surface casing leak to gas. The well was previously repaired with an OA cement job in 1998 and but in November of 2022 was made not operable for having gas bubbling in the conductor flutes and elevated LEL levels. Various diagnostic work done since 2002 indicate that the top of cement in the OA is at 150’ and the surface casing leak is ~70’ with a .25 BPM LLR at 200psi. The well is currently secured with a TTP and passed an MIT-IA to 2,700psi and MIT-T to 2,550psi. Objective:Repair surface casing leak by cementing OA to surface. Notes On Wellbore Condition: x 9/24/2022 SL set DGLVs, TTP and performed a passing MIT-IA and MIT-T to 2,700psi x 12/6/2015 MIT-OA failed with 11.2 GPM LLR x 6/28/2013 LDD found leak depth ~70’ below CSG valve, and hard bottom at ~150’ Procedure: Well Support: 1. Remove OA casing valve and install integral flange for cement job. a. See attachments below for recommended RU. b. Ensure that clean up loop is installed as close to the WH as practical. Fullbore: 1. RU fullbore and cementers a. Have additional empty vac truck with stinger on location to clean up any returns from the conductor. 2. Pump the following fluid schedule down the OA. a. 5bbls heated diesel b. 15bbls 150 degree surfactant wash c. 1bbls FW spacer d. 12bbls 15.8ppg cement with 5ppb bridge maker. 3. Pump cement until a ~700psi squeeze is achieved. a. If cement does not squeeze before 9bbls, shutdown and perform 5-minute hesitations. b. Thixotropic cement gels soon after you stop shearing it. HES will advise safe shut down times to allow for surface equipment washup. c. Max treating pressure is 1,500psi Well: H-16B Current PTD: 200-065 4. Once squeeze is achieved or 10bbls of cement has been pumped, close in the OA and wash up surface lines. a. Do not displace cement or attempt to wash up the wellhead. 5. RDMO Cementers Slickline 1. MIRU SL 2. Pull DGLVs and Set LGLVs 3. Pull TTP from 9,254’ DHD 1. POP well and monitor conductor for SC leak Cement Calculations – Fullbore OA cement squeeze 13-3/8" x 9-5/8" Capacity 0.0581 bbls/ft 13-3/8" x 9-5/8" Volume from 70' MD to surface 4.07 bbls 13-3/8" x 9-5/8" Volume from 70' MD to 150' MD 4.65 bbls Excess cement to pump 3.3 bbls Total Cement to Pump 12 bbls Cement Design Cement Type / Weight 15.8 ppg batch mixed Slurry Design Temp 30-40 Degrees F Fluid Loss 40-200cc (20-100 cc / 30 min) Compressive Strength 2000 psi in 48hrs Thickening Time 2-4 hours Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Rig Up Well: H-16B Current PTD: 200-065 As-built Schematic: Well: H-16B Current PTD: 200-065 Proposed Schematic: Well: H-16B Current PTD: 200-065 Rig Up Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: June 9, 2023Subject: Changes to Approved Sundry Procedure for Well H-16BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “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 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/04/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTALT#20221104-1 Well API #PTD #Log Date Log Company Log Type Notes AOGCC Eset# PBU H-16B 50029205920200 200065 7/3/2022 Baker RPM/SPN PBU H-25A 50029214780100 216036 7/4/2022 Baker RPM/SPN PBU H-35A 50029226000100 214045 7/4/2022 Baker RPM/SPN REVISED -REDISTRIBUTED PBU P1-06A 50029226950200 222009 7/17/2022 Baker RPM REVISED -REDISTRIBUTED PBU L5-21 50029217320000 187057 7/28/2022 Baker RPM/SPN Please include current contact information if different from above. T37233 T37237 T37234 T37235 T37236 PBU H-16B 50029205920200 200065 7/3 /2022 Bake r RPM/SPN Kayla Junke Digitally signed by Kayla Junke Date: 2022.11.07 16:05:04 -09'00' • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, September 28, 2015 2:14 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Producer H-16B (PTD#2000650) Put on Production to Evaluate Surface Casing Attachments: H-16B WBS.pdf Chris, As per are earlier conversation, Producer H-16B (PTD#2000650) is a natural flow producer,that has shown surface casing communication in the past with nitrogen. An MIT-OA failed on July 10, 2015 with liquid, but there was no indication of bubbling in the conductor or fluids coming to surface. A CMIT T x IA passed to 2500 psi on September 5, 2015. BP would like to put the well on production to evaluate the surface casing communication. The cellar will have secondary containment and if we see fluids coming from the conductor the evaluation period will be terminated. A copy of the wellbore schematic is included for reference. Kevin Parks tti%!iitney Petttl<, BP Alaska -Well Integrity Coordinator GVV Global wells Organization SCANNED AUG 0 4 2016 Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 OF T y ��wP�,I77, THE STATE Alaska Oil and Gas ofALAs TA Conservation Commission tfttx___ 333 West Seventh Avenue = � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -4ai Main: 907 279 1433 0�'ALAS*� Fax: 907 276 7542 www aogcc.alaska.gov Jessica Sayers SCANNED MAY 1 4 2015 Well Intervention Engineer BP Exploration(Alaska), Inc. — 066- P.O. Box 196612 c), Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-16B Sundry Number: 315-255 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this `t' day of May, 2015 Encl. EIVED STATE OF ALASKA APR $ 201 ALASKA OIL AND GAS CONSERVATION COMMISSION )TSS 1 APPLICATION FOR SUNDRY APPROVALS AOGG 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑' • Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑] Time Extension❑ Operations Shutdown 1: Re-enter Susp.Well❑ Stimulate❑ Alter CasingL7 Other Well Lock Technology 0 . 2.Operator Name 4 Current Well Class: 5 Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development 2 • 200-065-0 • 3 Address: Stratigraphic ❑ Service El6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20592-02-00 • 7.If perforating 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU H-16B • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028284 ' PRUDHOE BAY, PRUDHOE OIL • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12652 ' 8977 ' 9254 8328 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 27.88-107.88 27.88-107 88 Surface 2637 13-3/8"72#L-80 27.38-2664.31 27.38-2664.23 4930 2670 Intermediate 9332 9-5/8"47#L-80 25.88-9358.07 25.88-8387.88 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft) See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: I Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14.Estimated Date for 15 Well Status after proposed work: Commencing Operations: Oil 0 ' Gas ❑ WDSPL ❑ Suspended ❑ 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 Jessica Sayers Email Jessica.Sayers@BP Corn Printed Name Jessica Sayers Title Well lntervetions Engineer Signature / ` •••ne 5 -4281 Date IZ�IS Prepared by Garry Catron 564-4424 lb I-1COMMISSION USE ONLY Conditions of approval. Notify L. mission so that a representative may witness Sundry Number: (G ^25 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: / d— .9 0 L( APPROVED BY Approved by:ae. P COMMISSIONER THE COMMISSIONDate. 5- 4- -�5 VT L 4/3 P1/5-0 Jo"4 hd> c'a er�sv S[� ‘6,y` iS Form 10-403 Revised 10/2012 Op e p ti alid for 12 months from the date of approval. Submit Form and Attachments in Duplicate RBDMS1c MAY - 6 2015 D0y�?/� Plug Attachment ADL0028284 Well Date MD Plug Type TVD H-16B 8/9/2011 9254 4-1/2" XX Plug 8328 H-16B 3/17/2002 12340 2-7/8" CIBP 8908 a) -a op Op coo w w co co _I J J el a) Q O 0, 0 0 0 0 (0 CO MO O O _ N- co CC) CO CD In O V I- U o o 0 o p CO CO CO CO CO co V O ''zt CCI CO 00 'Cr CO co a) O co „, co I- V 00 CO r- co CO I- N CO O) O) CO CO cr CO CO CO N CO CO I Q O ~ CO co co N V CO Q N N CO ' N N CO CO CO E 00 . E ” coN pp ai co co - `- N maMcflrnCOc (f) O Q O) N O) O) O 2 C J • O LO O N CZ H CO CO O) N- N Q C I N 0) CN N CO O) O) 6) O O p Cb O COCD CO 0O0OUCO J J J co J O CD M * CO CO N 4# O N X . I,- CO N N 00 N M - N M N N � i �-r I N I� O O O CO CO CO N— C) CO CO CO CD CO CO O) J O) N r N O) W EY Q w w U U LI p c c o u z Z Z W W W OO m OFDDD U Z Perforation Attachment ADL0028284 Well Date Perf Code MD Top MD Base TVD Top TVD Base H-16B 8/8/11 BPS 10820 _ 10870 8923 8928 H-16B 8/8/11 BPS 12180 12310 8995 8982 H-16B 8/8/11 BPS 12360 12410 8980 8978 H-16B 8/8/11 BPS 12414 12536 8977 8978 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Packers and SSV's Attachment ADL0028284 Well Facility Type MD Top Description TVD Top H-16B PACKER 9223 4-1/2" Baker S-3 Perm Packer 8310 H-16B PACKER 9365 4-1/2" Baker S-3 Perm Packer 8392 H-16B PACKER 9410 5" Baker ZXP Top Packer 8418 H-16B PACKER 9995 3.7 Baker KB Liner Top Packer 8814 bp Ilk 0 • ae�+ To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 04-23-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: H-16 WeIlLock Conductor Treatment Objective This program is for treating surface casing response to pressure by external repair with WeIlLock. The well fails an MIT-OA. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to place the WeIlLock between the conductor and surface casing to mitigate the leak. Approximately one week before treatment, put under evaluation and POP to warm well and aid in treatment/curing of resin. Please reference the waste management plan, at the end of this document, for disposal practice and approval. Ensure the slop trailer is clean, prior to arrival. Do not mix non-exempt hydrocarbons with WeIlLock (this is to avoid taking to WeIlLock to the facility). Well Detail Current Status: Not Operable — PAL Previous Test: 04-21-2009 MIT-OA (Nitrogen) Fail Integrity Issues: Surface casing leak Last H2S Reading: 01-13-2014 5 ppm • Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg Diesel: 6.8 ppg Temperature: Maintain 750-80° F throughout the entire job, leave heater trunks in well during cure period (one week) Relevant History: > 04/13/09: MIT-OA w/ N2 Failed, 02 dropped, LELs increased 1 of Procedure 1 D Thoroughly clean the conductor by surface casing annulus to remove any deleterious material. This include steam washing the annulus and cleaning with detergent. 2 D Run open bleed on OA during the entire job. 3 D ***Pump WeIlLock into conductor by casing annulus. 4 D Allow WeIlLock to cure for one week. 5 D MIT-OA to 1200 psi with diesel *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period and record temperature and observable viscosity of sample. 2 of 3 1 CAN SAFETY NOTES: WELL ANGLE>71T®1007S'- VIELL-FAD= '._..:MCEVOY H-16 B A q-1/2 CHROME MIar MG&NPPLES'•• K)ORWUI ACRMTOR BAKER C KIS 487= 729' BF E EV- 24.38' I KOP= 3100' Iii Anyb= 9" 12157' 2003 4-1/2" =3.813' Datum k0" 10188' COLLAR 2683 l CoMmTVO= 8900 SS '• ' 518 O5/ (1?-?40'S,'4^,72*,L40),S'-+7*ar. H 2474' I--A GAS(FT MAN J5ILS ST MD TVD DEV TYPE VLV LATCH BORT DATE 4 '3659 3835 21 MUG DOME Plc P 16 03109/09 ATOP OF BAKER TIEBACK SAV.D•7.500' { 8613' I 3 6163 5783 32 MMC SO P c '20 03,09/09 [9-5/8'x 7'BAKER 2)4'P!(R.D6 • ,315 I-- - $81•*' 2 7784 7203 25 MMC) DMY p){ ' 0 02114/09 1 9112 8248 57 MO TN BK ' 0 02114/09 10-50P X T BAKER NMC NCR,ID.6.250' -1 862T 19-5/13"CSG,47a.L-90.D=8.681' I--1 8676'... f A 1H91Y F14.i2'HES XMP,0=3.813" y4 1221' T X 4-112'ERR 5-3 PKR,ID=3.875' I 4-1/TTBG,12.811,13CR-ISV0.MT+DP, 0317' ® • 121' H'l-v'�XPP,I)3.813" al 0152 bpi D=3.958' 1214' 4-1/2•XX nix;N(1118111) 2' 4-1Tec STUB(02'11/09) 1).320' 11332' Hr x 4-1 IT UNCLE OVERSHOT -L._1362' HI-It?HES X NIP,D*3.813' Minimum 10 =2.28"e 9896'1 7...4 — &NW T X 4-112'Biot S-3 ROL D=3.875' i BKR KB LN R TOP PKR ' cur 4-1/2'FES X TOP,D-3.813' I 4-1/2'TBG,12.60,L-$014SCT, 9478' I MT 4 12'HES XN NP D=3.725' .0152 bpi,O=3936' TOP OF BAKER TEBACK SAV.D•5.250' H gar 3 *MUM TO 3.60'00Y CIA T X 4-1/2'BAKER 2W PKR D=4.408' x41.7" --{41/2'1NLEG,ID*3.958' j T X 4112'BAKER HMC FGR,ID•4,408 -I saw3 .E., L_____..-_� -tE1JNO TT.NOT LOGGED___ iTLNRno,Leo,D=6.276' 1.......11611' —'J BOW H RAKFR KR I Mi Ti1P OKR n-)9R" I 10001• 1--{3-)14'BKR DEPLOYMENT SLV,ID-3.09' ' 1O10D7• 2-7M'LNR TOP,D=2.37T I4-1/2'LAN,12 60,L-60,0152 bpi,0.3,958' H 10960' {� PE FORA110N%MAARY \y REF LOG SATS aM AUL ON 05128/00 \, 1 I :COP(09108!00) ANGLE AT TOPPERF 8M 10820' /J MIN NMI w R W mtiu(CIS rur Ilwkir Ld pug r 44*4 SIZE SPF MERVAL Opn1SoR SHOT SO2 J/ ` 2' 6 10820-1087D 0 09/06103 2' 4 12180-12310 0 06)09100 2' 4 12360-12410 C 1)8009100 PBTD -1 12699' I 2' 4 12414.12536 C 05/31/00 2-718'LNR 6.1019,L-80 STA, --1 12652' I Alt:, ......... ,0058 bpi,CI=2.441' i `o DATE REV BY COHABITS DATE REV BYCOka,@1TS R4111-113EUE BAY IT 67/3119/ IM IALCOMPLE'TION 00/31/10 PRMd)�.IS/SLUSIPXPULLED(3/IDNW11.1.49) W .4 H-160 08,03/10 __. RIG SIDETRACK(1414Al 0U521/11 SET/PJC SET PX R UD(05.110111) I_ f No 20008'90 06/31/00 010810E-TRACK(111111401/14/11 JRIC RLL FERIM)(0725111) AR No 50008-20502-02-00 02/14/09 . 016 RM10___._-_ 18128/13 LOPIC SET XX FU,K)(616/11) — SEC 21,1'11 Pt R138L,1322'FM.8:1284'FEL 02/24109 'PLR CRAG'6) 06123/10 I-1Jk0 CPLG DRAFT CONFECTIONS BP Esploradon(Alaska) I 3of3 I Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~ ~- .~_~_~ Well History File Identifier Organization (done) [] Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds TOTAL PAGES: ~../4 ~ NOTES: ORGANIZED -- -~BY; BEVERLY BRE~HERYL MARIA LOWELL [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BRE~HERYL MARIA LOWELL Scanned (done) PAGES: SCANNED BY: (at the time of scanning) BEVERLY BREN VlNCE~ARIA LOWELL ReScanned (done) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: PAG ES: Quality Checked (done) RevlNOTScanned.wpd STATE OF ALASKA ~ /O9 A~ OIL AND GAS CONSERVATION CO SSION MAR 1 Q 2U09 REPORT OF SUNDRY WELL OPE TIO~q A1~ka Oit & Gas Fans, Onmmissinn 1. Operations Performed: nC Orage ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. _ ®Development ^ Exploratory 200-065 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20592-02-00 - 7. KB Elevation (tt): 72 86' 9. Well Name and Number: PBU H-166 - 8. Property Designation: 10. Field /Pool(s): ADL028284 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 12652 ~ feet true vertical 8977 feet Plugs (measured) 9386' & 12340' Effective depth: measured 12589 feet Junk (measured) 9367' true vertical 8979 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" X 30" 110' 110' Surface 2674' 13-3/8" 2674' 2674' 4930 2670 Intermediate °' Production 8676' 9-5/8" 8676' 7968' 6870 4760 Liner 1068' 7" 8513' - 9581' 7837' - 8513' 7240 5410 Liner 1531' 4-1/2" 9419' - 10950' 8423' - 8939' 8430 7500 Liner 2657' 2-7/8" 9995' - 12652' 8814' - 8977' 13450 13890 ~t~~"~a ~,1h~ tJ ~.t~U:~ ' Perforation Depth MD (ft): 10820' - 12310' ` _. " t.u ~'° Perforation Depth TVD (ft): 8923' - 8982' 4-1/2", 12.6# 13Cr80 / L-80 9419' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2", BKR S-3 Packers 9221' & 9363' 12. Stimulation or cement squeeze summary: l I t t t d d ~~" `~S~ ~~ ~~~~~ (measure n erva s rea e ): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram - ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Hank Baca, 564-5444 N/A Printed Name Sondra Stewman Title Drilling Technologist ~~~ y ~~~~ q Prepared By Nam®/Number: ~3~'b D nature Phone ate I Sondra. Stewman 564-4750 Form 10-404 Revised 04/2006 ?~''~~ ~~ _ ~ ~ ~"?~ ~ ~ ~ ;1,,.}~ Submit Original Only ~~ ~ S (o 1~,~~t~1 TREE= 4-1/16" MCEVOY WELLHEAD= MCEVOY ACTUATOR = BAKER KB. ELEV = 72.9' BF. ELEV = 24.38' KOP = 3100' Max Angle = 99 @ 12157' Datum MD = 10168' Datum ND = 8800' SS DRLG DRAFT 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2674' TOP OF BAKER TIEBACK SLV, ID = 7.500" I~ 8513' 9-5/8" X 7" BAKER ZXP PKR, ID = 6.313" 8519' 9-5/8" X 7" BAKER HMC HGR, ID = 6.250" 8527' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8676' 7"x4.5" Unique Mach Overshot 9332'" Junk Catcher w / 1" d x 3/4" chunks 936T 2- Bags of Sluggits 9386-9376 Minimum ID = 2.37" @ 9995' BKR KB LNR TOP PKR iP OF BAKER TIEBACK SLV, ID = 5.250" ~ 9419' 7" X 4-1 /2" BAKER ZXP PKR, ID = 4.408" 9425' "' X 4-1/2" BAKER HMC HGR, ID = 4.408" 9433' 7" LNR, 26#, L-80, ID = 6.276" - S]I~ETY NOTES: WELL ANGLE > 70° @ 10075' H -16 B & > 9U° @ „650'. 02/22/09: 'PER DRLG REP, POSTED TALLY IS CORRECT, DIMS MAY BE OFF 2-3' 2003'" 4-1 /2" HES X NIP. ID = 3.813" 2583' 9-5/8" DV COLLAR GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3659 3635 21 MMG DCR RKP 0 02/14/09 3 6163 5783 32 MMG DMY RK 0 02/14/09 2 7784 7304 25 MMG DMY RK 0 02/14/09 1 9112 8248 57 MMG DMY BK 0 02/14;09 9190" ~ 4-1/2" HES X NIP, ID = 3.813" 9221'" 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 92j4'* 9352' 4-112" HES X NIP, ID = 3.813" 4-1/2" HES X NIP, ID = 3.813" 9363' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 9386' 4-1 /2" PX TTP Set 09-25-2006 9386' 9407' 4-1 /2" HES X NIP, ID = 3.813" 4-1 /2" HES XN NIP, ID = 3.725" * MILLED TO 3.80" ID BY CTD 9418' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9419' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 9995' ~ BAKER KB LNR TOP PKR, ID = 2.37" 10001' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" 10007' 2-7I8" LNR TOP, ID = 2.377" I4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10950' PERFORATION SUMMARY REF LOG: SWS OH MCNL ON 05/28/00 ANGLE AT TOP PERF: 97 @ 10820' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10820 - 10870 C 09/08/03 2" 4 12180 - 12310 C 08/09/00 2" 4 12360 - 12410 C 08/09/00 2" 4 12414 - 12536 C 05/31/00 12340' I-~ cIBP PBTD (~ 12589' I 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.377" ~-{ 12652' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/81 ORIGINAL COMPLETION 02/14/09 D16 RWO OS/03/98 RIG SIDETRACK (H-16A) 02/24/09 /TLH CORRECTIONS 05/31/00 CTD SOTRK/WELL EXT-H-16B 03/07/02 CH/TP CORRECTIONS 09/08/03 JGM/KK ADPERF & SET CIBP 09/25/06 JCM/PAG SET PX TTP @ 9386' PRUDHOE BAY UNIT WELL: H-166 PERMIT No: 2000650 API No: 50-029-20592-02 SEC 21, T11 N, R13E, 1322' SNL & 1265' WEL BP Exploration (Alaska) • PBU H-16B, Pre & Post Rig Work Summary u Date Descri lion 22/Feb/2009 T/I/O=Vac/0/0; Pulled 4-1/16" CIW "H" BPV #150 thru tree post Rig; 1-2' ext. used, tagged C~ 102". 14/Feb/2009 T/I/O = 0/0/0 Pull 4 1/16" CIW H TWC Post tree test Do on 16 10/Feb/2009 T/I/O = 0/0/0 Pulled 6" ciw twc used 4-5" and centralizer tag at 60" for post bop pt no ,. roblems 09/Feb/2009 Pulled 6" CIW BPV thru tree for Do on 16 T/I/O=BPV in hole/0/0 Temp=S/I OMIT TxIA to 2000 psi. '***Job continued from 2-4-09**** Pumped 5bbls of 20*F diesel down IA to reach 2000 psi for CMIT TxIA. IA lost 40 psi in the 05/Feb/2009 1st 15 mins. And 0 psi in the 2nd 15 mins for a total pressure loss of 40 psi in 30 min test. Bled psi back down to 0. Notified pad operator of well status, hung tags and normal up well. Casin valves o en to au es. Final WHP's=0/0/0. 04/Feb/2009 T/I/0=250/500/190 CMIT TxIA to 2000 si. Continue on 02/05/09 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (50 psi), bled to 0 psi. Functioned LDS, 3 were tight but moving, the rest moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled 26/Jan/2009 void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test; lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 1 blank is installed, LDS has been drilled out 8/1/08 . 24/Jan/2009 T/I/O=Vac/0/0. Set 6-3/8" Ciw J BPV # 421 thru tree, pre rig. 1-2' ext used, tagged @ 108". No roblems. T/I/0=200/200/0 Circ- out [RWO Prep] Pumped 10 bbls neat meth, 976 bbls 1% KCL down Tubing- up IA taking returns through jumper line down F/L to circ out. Pumped 5 bbls neat, 19/Jan/2009 140 bbls diesel down Tubing, U-tubed Tx IA to freeze protect. Pumped 8 bbls neat, 36 bbls crude, 65 bbls diesel down F/L to freeze protect. *** SV, WV, SSV= closed, Master valve open, Annulus casing valves open to gauges on departure.***FWHP's 0/0/0 ELINE CUT 4-1/2" TUBING WITH 3.65" SCP POWERCUTTER AT 9320 FT IN THE 29/Dec/2008 MIDDLE OF FIRST FULL JT ABOVE PACKER. HAD TO PULL 1100# OVER NORMAL WT TO FREE TOOL STRING AFTER CUT. JC/SLUGGITS TAGGED AT 9366 FT. WELL SI ON DEPARTURE. FINAL T/I/O 310/340/0. ***JOB COMPLETE*** 28/Dec/2008 INITIAL T/I/O = 350/360/0. RU ELINE TO CUT 4-1/2" TUBING WITH 3.65" SCP POW ERCUTTER. ***JOB CONTINUED 29-DEC-2008*** DUMP BAIL -12' (2 BAGS) TOTAL ON PX PLUG @ 9375' SLM SET 4-1/2"JUNK CATCHER, TOP @ 9358' SLM 113" OAL -HAS 4 1/2 G FISHING 25/Dec/2008 NECK) ***WELL S/I, INFORM PAD-OP OF WELL/VALVE CONDITIONS*** NOTE: PRONG & JUNK CATCHER DIAGRAMS IN WELL FILE T/I/0= 50/120/0 Temp= S/I Assist Slickline, CMIT TxIA PASSED to 3500 psi. (Pre RWO) Pressured up TxIA to 3500 psi with 23 bbls diesel and 16.6 bbls crude. T/IA lost 60/80 psi 24/Dec/2008 in 1st 15 mins and 20/20 psi in 2nd 15 mins for a total pressure loss of 80/100 psi in 30 mins. Bled back 27 bbls. Final WHP's=120/200/0. Slickline in control of well at LRS de arture. SET SHORT "P" PRONG (OAL=45.5", 1.75" F.N.,1.875" BODY) IN PX PLUG BODY C~ 9,375' SLM 24/Dec/2008 RMED PASSING CMIT-TxIA TO 3 500# SEE LRS AWGRS MADE ONE 3 1/2" X 10' DUMP BAILER RUN W/SLUGGITS ON PX TTP@ 9375' CURRENTLY ON 2ND BAILER RUN W/SLUGGITS 23/Dec/2008 PULL PRONG FROM PX PLUG BODY @_9368' SLM CURRENTLY RUNNING IN W/ "SHORT" PRONG (43.5" OAL) ***CONTINUE WSR ON 12-24-08*** • BP EXPLORATION Operations Summary Report Legal Well Name: H-16 Common Well Name: H-16 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date ~~ From - To Hours ' Task Code NPT 2/8/2009 05:00 - 09:00 4.00 RIGD P 09:00 - 15:30 6.50 MOB P 15:30 - 18:30 I 3.001 RIGU I P 18:30 - 20:30 I 2.001 RIGU I P 20:30 - 22:00 I 1.501 RIGU I P 22:00 - 00:00 2.00 WHSUR N 2/9/2009 00:00 - 00:30 0.50 WHSUR N 00:30 - 01:00 I 0.501 WHSUR I P 01:00-02:30 ~ 1.50~WHSURP 02:30 - 03:30 ~ 1.00 ~ WHSUR ~ P 03:30 - 05:30 I 2.001 WHSUR I P 05:30 - 07:00 1.50 WHSUR P 07:00 - 09:30 2.50 WHSUR P 09:30 - 12:00 2.50 WHSUR P 12:00 - 13:30 1.50 WHSUR P 13:30 - 17:00 I 3.501 BOPSUR P 17:00 - 00:00 7.001 BOPSUpP 2/10/2009 100:00 - 00:30 I 0.501 BOPSUR P 00:30-01:30 ~ 1.OO~WHSURP 01:30 - 03:00 I 1.501 PULL I P Start: 1 /29/2009 Rig Release: 2/14/2009 Rig Number: Page 1 of 5 ~ Spud Date: 7/9/1981 End: Phase ', Description of Operations PRE ~ Move off C-41 and prepare to R/D for moving to H-16B PRE Move off C-pad and onward to H-pad. Santa Fe pad for crew change at 1130-hours. Frontier Corner at 1215-hrs. J-pad C~ 1315-hrs. On H-pad at 1530-hours. PRE Raise Derrick. Remove Boosters. Layout Herculite around H-166. Install BOP stack on cellar pedestal. PRE Hold PJSM on spotting rig and assign people to positions. Spot rig over H-166 and shim in place. PRE Hang bridle lines. Attach blocks to Top Drive and hook up compensators. Spot slop tank. IA, OA and Tree pressure are 0-psi. RU circulating lines and manifold, OA bleed hose to slop tank, double IA valve. Take on Seawater. Accept Rig at 2200-hrs on 2/8/2009. WAIT DECOMP Wait on DSM to arrive with lubricator due to crew availability. WAIT DECOMP Wait on DSM to arrive with lubricator. Delay due to lack of crew availability. DECOMP Clear remaining snow from well cellar. Steam tubing spool prior to pulling BPV. Change out 4" Demco to #2 Mud pump. DECOMP PU DSM lubricator and ressure test to 500- si. Good tes . Attem t to ull BPV. SSV is not fully open. DSM pump SSV open. Pull BPV with 0-psi under plug. LD lubricator and BPV. DECOMP RU to displace wellbore to clean 8.5-ppg seawater. Hold PJSM with Rig crew, Doyon tourpusher, BP WSL and CH2MHill truck drivers. Discuss spill potential, working around high pressure lines and assign spill champions. Pressure test lines to 2500-psi using warm seawater. DECOMP Establish circulation and pump 20-bbl Hi Vis sweep at 4-BPM with 260-psi. Chase sweep at 6.5-BPM with 450-psi. No fluid was noted from the OA. DECOMP Monitor well. Blow down and RD all circulating lines. Drain tree in preparation for setting TWC. DECOMP Set and test TWC to 1000- si from below and 3500- si from above. Solid tests, but the T x IA TWC appears to still be trying to equalize, allowing the TWC to leak back. Drain tree with suction line to verify leak and TWC quits leaking. DECOMP PJSM. N/D tree and adaptor spool. Calibrated Combustible Gas detector and H2S Gas detector. DECOMP Terminate SSSV control lines. Hanger threads in very good shape, and Cameron Tech used 8-1/2 right-hand turns to M/U XO to hanger. Cameron Tech functioned all LDSs with no problems. DECOMP N/U BOPE. Check all 4 air boots in the riser. Fill test equipment with freshwater. Stroke valves and function Hydril to prepare for testing. Steam BOP stack outside and Hydril inside. DECOMP Initial BOPE test, 250-psi low, 3,500-psi high using 4" and 4-1/2" test joints. Test Hydrill with only the 4" test joint. Record all tests on Chart. DECOMP RD test equipment. Blow down all lines. RU Dutch riser system. DECOMP PU DSM lubricator. Pressure test Dutch Riser and lubricator to 500-psi. Good testa Pull TWC. LD lubricator, TWC and Dutch Riser. DECOMP While checking IA pressure in preparation for pulling hanger, Printed: 3/6/2009 1:42:07 PM BP EXPLORATION Page 2 of 5 Operations Summary. Report Legal Well Name: H-16 Common Well Name: H-16 Spud Date: 7/9/1981 Event Name: WORKOVER Start: 1/29/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/14/2009 Rig Name: DOYON 16 Rig Number: Date From - To I Hours ' Task ~, Code NPT Phase ', Description of Operations 2/10/2009 01:30 - 03:00 1.50 PULL P DECOMP discover ~15-psi on gauge. Bleed approximately 10-gallons of diesel to rig slop tank and pressure on IA drops to -5-psi. Decide to open IA to bleed and monitor pressure. Bleed off 5-gallons and flow stops. MU landing joint and screw into hanger with 8-1/2-turns. Screw into top drive. Cameron tech BOLDSs. 03:00 - 07:30 4.50 PULL P DECOMP Hold PJSM with rig crew on pulling hanger and circulating through choke. Pull hanger off seat at 125K-Ibs. PU wt = 145K-Ibs. Park hanger just below annular and shut annular in. Open up choke and establish circulation. Circulate at 5.5-BPM with 450-psi. Approximately 25-bbls of diesel returns initially. Circulate 1-1/2 Wellbore volumes due to possible holes in the tubin .While circulating, RU to LD 4-1/2" 12.6# BTC-M tubing. 07:30 - 12:00 4.50 PULL P DECOMP PJSM. Pump Dry job. Pull Hanger to rig floor. Fluid level static. Connect control lines to spooler. POH and UD first full joint at 0830-hours, then space-out pups. Full joint #10 at 0900-hrs. All of the first 10-joints have internal scale. Greg's Crew held 15-minute Pinch Point safety meeting on rig floor. Started sl'i~htly crushing some joints at #40, moved backup tongs to the collar. Using the long-shanked Oilwell manual slips to prevent crushing tubing with the slips. Joint #50 UD at 1145-hours. UD SSSV, all of the control line, and recovered all 53 SS bands as noted in the original running tally. 12:00 - 18:00 6.00 PULL P DECOMP Held 15-minute Pinch Point safety meeting on rig floor with Toby's crew at start of their tour. Continue POH and UD tubing from full joint #51. Occasionally bending pin end with upper power tongs. Jt #75 ~ 1320-hours. All the first 75 joints showing severe internal corrosion but no external corrosion or com lete enetrations. Jt #145 ~ 1515-hours. Internal corrosion decreased to very little evidence by joint #150. Some pits near pin ends for the remainder of the string. Jt #200 C~ 1700-hrs. Cutoff joint to surface at 1800-hours. Cutoff joint 18.45' long with 4-7/8" jet cut diameter. 18:00 - 19:00 1.00 PULL P DECOMP Clear and clean rig floor. Change out elevators and prepare to M/U Dress-off BHA. Install 9" ID wear ring. 19:00 - 20:30 1.50 FISH P DECOMP PJSM - 4-1 2" Dress-off assembl - 6" x 4-9/16" Dress-off Shoe, 3-ea Extensions, 4-1/2" Tubing Dress-off Mill, Boot Basket, 7" Casing Scraper, Bumper sub, Oil Jars, and Pump-out sub, 6 ea 4-3/4" DC's 20:30 - 00:00 3.50 FISH P DECOMP Continue RIH from 235' with BHA #1. P/U 4" DP 1x1 from pipe shed and RIH to 4343'. 2/11/2009 00:00 - 04:00 4.00 FISH P DECOMP Continue RIH with 4" DP from 4343' to 8555' 04:00 - 06:30 2.50 FISH P DECOMP PJSM -Cut and slip drilling line. 06:30 - 08:00 1.50 FISH P DECOMP Continue RIH with the dress-off BHA. Yo-Yo 7" Scraper from 9157' to 9315'. 0715-hrs, stop just above the stub at 9,320' and get parameters: Up wt 180K-Ibs, Down wt 145K-Ibs, 7-1/2-BPM at 1050-psi, 40-RPM. Stop rotating, stop pump, continue in slowl and to at stub at 9 32 '. P/U, start rotating, start pump and bring up to 7-1/2-BPM, 1050-psi, 4-5K-Ib-ft. Slowly RIH and mill over the jet cut with 5K-Ib-ft, 1300-psi, 1-2K-Ibs WOB. Stop rotating after 5-mins and torque falls off, P/U, see pressure drop when we get off stub. Start rotating and RIH to dress-off the stub with the mill. Pressure increases to Printed: 3/6/2009 1:42:07 PM • • BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: H-16 Common Well Name: H-16 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To .Hours Task Code NPT 2/11/2009 06:30 - 08:00 1.50 FISH P 08:00 - 10:00 2.00 FISH P 10:00 - 14:00 4.00 FISH P 14:00 - 14:30 0.50 FISH P 14:30 - 15:00 0.50 FISH P 15:00 - 19:00 4.00 WHSUR P 19:00 - 19:30 0.50 WHSUR P 19:30 - 20:30 1.00 FISH P 20:30 - 23:30 3.00 FISH P 23:30 - 00:00 0.50 FISH P Spud Date: 7/9/1981 Start: 1 /29/2009 End: Rig Release: 2/14/2009 Rig Number: Phase ~, Descriptiorl of Operations DECOMP 1300-1400-psi and mill about 10-minutes with 1-2K-Ibs on bit, 5K-Ib-ft torque. DECOMP P/U to circulate HiVis sweep 8-BPM, 1200-psi for one wellbore volume plus DP volume, -715-Bbls. Returns are clean. DECOMP POH and S/B DP and DC in Derrick. Stand #60 at 1230-hours. At DCs at 1345-hours. Start steam on wellhead at 1200-hours. DECOMP PJSM. B/O and UD Dress-off BHA. Clear BHA off rig floor. Excellent wear patterns on the shoe and the inside mill. DECOMP Clear and clean rig floor. Service rig. DECOMP Pull Wear Bushing. BOLDS. OA opened and had no pressure. M/U Packoff ullin tool to landing joint, RIH and engage packoff. P/U on packoff per directions from Cameron Tech, then slackoff. Repeat several times working up to 30K-Ibs overpull above Top Drive weight of 40K-Ibs. Work Link Tilt back and forth on 180-degree increments. Max overpull is 80K-Ibs = 30K-Ibs per each of the 4 dogs on the packoff running/pulling tool. 1615-hrs, break off the four dogs with -130K-Ibs total pull. Call ADW engineer and agree to try another pulling tool. This time pull to 100K-Ibs and leave on packoff while applying steam to the spool. Pump into Packoff void with hyd. fluid and dump oil on top of packoff. (Unsuccessfully DECOMP Set 9" ID wear bushing. DECOMP P/U BHA #2. Itco spear, extension, spear stop sub, x-o, 2) 2-7/8" Pac DP, x-o, bumper sub, jars, pumpout sub, x-o, 9) 4-3/4" DC's DECOMP RIH with 4" DP from derrick from 277' to 8913' DECOMP M/U 9-5/8" RTTS (storm valve) and set 1) stand below rotary 2/12/2009 100:00 - 01:00 I 1.001 WHSUR I P DECOMP (Test RTTS (Storm valve) from above to 1000 psi for 10 01:00 - 03:00 2.00 WHSUR P DECOMP Ni le down BOP's and tubin s ool to change 9-5/8" Packoff. 2 Barriers are PX plug in X-nipple ~ 9386' and tested RTTS ~ 90'. 03:00 - 08:00 5.00 WHSUR P DECOMP Attempt to change packoff, found one LDS broken, which the Cameron Tech ground the nose off of. Replaced the LDS with a plug inside the Gland Nut. Removed a blank LDS plug on the flange, chased the threads and ran a new LDS in its place. Install new Packoff and RILDS. 08:00 - 12:00 4.00 WHSUR P DECOMP PJSM to discuss the installation of the BOP stack with adaptor flange. two Cameron personnel described proper placement of studs to avoid damage to the packoff when moving the BOP stack over the wellhead stump. A Task safety manager was appointed, tools were described, and pinch points were discussed and identified. P/U and M/U BOP stack, adaptor S ool, and Tubin S ool to Casin hea .Test packoff to 5000-psi for 30-minutes. Install Wear Ring and Drilling riser, inflate air boots. 12:00 - 12:30 0.50 DHB P DECOMP P/U RTTS Run/PuIJ tool on a joint of drill pipe, RIH, engage RTTS, release it and UD the RTTS. 12:30 - 13:30 1.00 CLEAN P DECOMP RIH with the Baker Itco Spear to retrieve the Junk Catcher. Down wt 147K-Ibs, 4.3-BPM at 1300-psi. SLowly RIH and tag at 9344'. P/U and rotate at 10-RPM and slowly RIH and pass Printed: 3/6/2009 1:42:07 PM BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: H-16 Common Well Name: H-16 Spud Date: 7/9/1981 Event Name: WORKOVER Start: 1/29/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/14/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations -_- __ - 2/12/2009 12:30 - 13:30 1.00 CLEAN P DECOMP - 9344', stop rotating and continue RIH, see pressure increase to 1400-psi then tag at 9367'. P/U and takes a 30K-Ibs overpull to pull Junk Catcher. Pressure did not fall off while pulling up-hole 20'. Set back down to 9367' to verify. P/U 20' to prepare to circulate a bottoms up. 13:30 - 15:30 2.00 CLEAN P DECOMP Dro ball/rod to open pump-out sub. Circulate Bottoms Up. Finish loading, rabbiting, and strapping 4-1/2", 12.6#, 13Cr80, Vam Top tubing in Pipe Shed. Verify all Completion jewelry in the Pipe Shed. Make one more depth verification to 9367' and put one left-hand turn into drillpipe to ensure spear grapples fully engaged. 15:30 - 22:30 7.00 CLEAN P DECOMP POH and UD DP and DCs. Joint #30 UD at 1630-hours. #90 C~ 1800-hrs. #205 C~1 2030-hrs. #280 C~ 2230-hrs. 22:30 - 00:00 1.50 CLEAN P DECOMP UD BHA #2. Did not recover'unk catcher. (Grapple showed signs of being inside of fish). Discussed with ADW engineer and decided to run completion. 2/13/2009 00:00 - 01:00 1.00 CLEAN P DECOMP Clear and clean rig floor. 01:00 - 02:30 1.50 BUNCO P RUNCMP Rig up completion running equipment. Pull wear bushing. 02:30 - 17:00 14.50 BUNCO P RUNCMP PJSM -Run 4-1/2" 12.6# 13 Cr80 completion per tally. BakerLok all connections below the packer. Torque all connections to 4440-Ib-ft optimum and applying Jet Lube Seal Guard pipe dope. Jt #12 in hole ~ 0500-hrs. #34 ~ 0630-hrs. #84 ~ 0845-hrs. #122 @ 1030-hrs. #153 ~ 1215-hrs. #216 for tag at 1630-hrs. Slowly RIH and tag stub at 9321' ,but takes 10K-Ibs without progress. Check two more times with same results. P/U and slowly turn 1/2 rotation to the right. Slowly RIH and see stub, taking 8K-Ibs on stub then Overshot sli son over th b. See first set of pins shear with 8K-Ibs at 4' in, then continue RIH slowly and see second set shear with 14K-Ibs at 12' in, then continue in another 2' and stack out 15K-Ibs at no-go. P/U and verify and get same no-go depth. Calculate Space-out and use 4-pup joints: 5.80', 9.74', 9.75', and 3.82'. This provides a swallow of 7'-8' for the stub inside the Unique Machine Overshot. UD joints #216, #215, and #214. Keep #214 on Pipe Skate. 17:00 - 18:30 1.50 BUNCO P RUNCMP M/U Spaceout Pup Joints and RIH below full joint #214. M/U Hanger to #214 and RIH. Up Wt. = 145 K Dn Wt. =130 K. Took 3 k Weight 7' from landing hanger P/U and slacked off over stub. Land hanger and RILDS. Unique Overshot landed depth of 9330'. 18:30 - 20:00 1.50 BUNCO P RUNCMP R/U circulating lines to reverse circ. Corrosion inhibited seawater. Pressure test lines to 4000 psi. 20:00 - 00:00 4.00 BUNCO P RUNCMP Hold PJSM with BP WSL, Tour pusher, Rig crew, CH2MHill drivers, Baker Rep. Reverse circulate 65 BBLS of seawater, 360 BBLS of corrosion inhibited seawater, and 185 BBLS of seawater ~ 3 BPM with 300 psi. All seawater heated to 120 degree. 2/14/2009 00:00 - 02:00 2.00 BUNCO P RUNCMP Dro Packer settin ball/rod. Pressure up on tubing to set Packer. Bring tubing pressure up to 3,500 psi. Test Tubing at 3 500 six 30 minutes. Good test. Bleed tubin ressur down to 1500 si. Pressure u Annulus to 3 500 si and test Casing and Packer for 30 minutes. Good test. Dump tubing pressure and shear DCR-Valve. ~ 1900 psi. Recorded all Printed: 3/6/2009 1:42:07 PM BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: H-16 Common Well Name: H-16 Spud Date: 7/9/1981 Event Name: WORKOVER Start: 1/29/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/14/2009 Rig Name: DOYON 16 Rig Number: Date From - To ', Hours Task Code ~ NPT ~ Phase Description of Operations 2/14/2009 00:00 - 02:00 2.00 RUNCO P RUNCMP tests on chart. Pump both directions through shear vavle with no problems. 02:00 - 05:30 3.50 RUNCO P RUNCMP Pull landing joint and rig down test hoses. Cameron Rep set 4" si for 10 mins - ood test. Pressure Test TWC from above to 3500 Si for 10 mi .Pressure slow) bleedin off make multiple attempts. Double check all surface equipment, IA, and OA. Reset landing joint and screw into Tbg Hanger. Rig up pressure test equipment to landing Joint. Pressure test TWC from above to 3500 psi for 10 mins. -good test. R/D testing equipment. 05:30 - 07:00 1.50 BOPSU P RUNCMP PJSM - N/D BOPE and adapter spool. 07:00 - 10:00 3.00 WHSUR P RUNCMP PJSM. N/U Adaptor Spool and Tree. Fill tree with diesel and stroke all valves. 10:00 - 11:30 1.50 WHSUR P RUNCMP Pressure test Tree to 5000-psi, required bumping up 6-times. 11:30 - 16:00 4.50 WHSUR P RUNCMP PJSM R/U DSM lubricator and test to 500-osi. Pull TWC_ No pressure or vacuum under TWC. R/U to Reverse Circulate Diesel freeze protect fluid. PJSM with Lil Red and rig crew to discuss fluid transfer, pressure testing lines, and spill avoidance. H/U Lil Red lines to Tree and test to 2500-psi. Bring on Lil Red pump to 2-BPM @ 500-psi. Pump 140-Bbls of diesel freeze protect. 16:00 - 17:00 1.00 WHSUR P RUNCMP Line up and allow Diesel to U-Tube for 1 hour. 17:00 - 18:00 1.00 WHSUR P RUNCMP Secure cellar, wellhead, and tree for move to DS-16-22. Ric_ Printed: 3/6/2009 1:42:07 PM MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm_ Marker.doc WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To; State of Alaska AOGCC :333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE · Distribution - Final Printls) 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' Joe¥ Bu~con / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 13S9 Stafford, ~ 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 1 1 Res. Eval. CH I I 1 H-16B 9-8-03 Mech, CH /~.~~ ~ Caliper Survey Signed · Print Name: Date · ProAcTive Diagnostic Services, Inc., PO Box 1369 Stafford Tx 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog.com Website: www.memorylog.com S% STATE OF ALASKA rc~' ALA ~ OIL AND GAS CONSERVATION C ,v,,vllSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanonr'-] Suspendr-] Operation Shutdownr-~ Perforate[] VarianceS] Annuar Disposal[--1 After Casinq[--I Repair Well[~] Pluq Perforations[-'] Stimulate[--I Time Extensionl--~ Other['-I Change Approved Programr-'~ Puli Tubingr"] Perforate New Poolr"'~ Re-enter Suspended Well[~ ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development · Exploratoryr-1 200-065 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic [] Service D 50-029-20592-02-00 7. KB Elevation (ft): 9. Well Name and Number: 73.OO H-16B 8. Property Designation: 10. Field/Pool(s): ADL 028284 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12652 feet true vertical 8974 feet Plugs (measured) Set CIBP @ 12340' (03/17/2002) Effective Depth measured 12340 feet Junk (measured) true vertical 8977 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 158' 158' 40K 520 Surface 8626' 13-3/8" 2674' 2674' 80K 4760 Intermediate 8628' 9-5/8" 8676' 7968' 80K 6280 Liner 1068' 7" 8513'-9581' 7837'-8513' 80K 7020 Sidetrack Liner 531' 4-1/2" 9419'-10950' 8423'-8939' 80K 7500 Sidetrack Liner 2657' 2-7/8" 9995'-12652' 8814'-8974' 80K 11160 Perforation depth: Measured depth: Open Perfs 10820'-10870', 12180'-12310' Open Perfs Below CIBP 12360'-12410', 12414'-12536'. True vertical depth: Open Perfs 8923'-8928', 8992'-8978'. Open Perfs Below CIBP 8976'-8974', 8974'-8974'. Tubing: ( size, grade, and measured depth) .4-1/2" 12.6#' L-80 TBG to 9363' w/4-1/2" Tailpipe to 9419'. Packers & SSSV (type & measured depth) 9-5/8" x 7" BKR ZXP PKR @ 8519'. 7" x 4-1/2" BKR S-3 PKR @ 9363'. 7"x 4-1/2" Baker ZXP Packer @ 9425'. 4-1/2" x 2-7/8" Baker KB Liner Top Packer @ 9995'. 4-1/2" HES HXO SSSV Nipple @ 2057'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~'~ -. ~ ..... ..~ ,/,. ' Treatment descriptions including volumes used and final pressure: ~'~:1~'*,~ ~ ~ ',' ' ,' ~ :' '~ '~ '1 r,' , 1'''~i' f"~ 13 Representative Dailv Averaqe Production or Iniection Data ... Oil-abl Gas-Ucf Water-abl Casin~ Pressure .... Tubi'n~'"' Pressure Prior to well operation: 131 229 1194 263 Subsequent to operation: 206 5259 4956 268 14. Attachments: 15. Well Class after proposed work: Exploratoryl-"l Development ~ Service[~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: Oil· Gas~] WAGE~] GIN Jr--] WlNJE~] WDSPL[~ Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name DeW, ayne R. Schnorr_, ^ Title Techical Assistant Signature ,~'"~~,~~ Phone 907/564-5174 Date Sept22,2003 H-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09~03/2003 PERFORAT]~NG: DR]~FT/TAG 09/07~2003 PERFORAT]'NG: DR]~FT/TAG; .~EWELRY LOG--DEPTH CONTROL; PERFORAT]'NG 09/08/2003 PERFORATING: DR]'FT/TAG; .JEWELRY LOG--DEPTH CONTROL; PERFORAT]~NG 09/20/2003 TESTEVENT--- BOPD: 206, BWPD: 4,956, MCFPD: 8,809, AL RATE: 3,550 O9/O3/O3 09/07/03 09/08/03 O9/20/O3 EVENT SUMMARY *** WELL FLOWING ON ARRIVAL *** DRIFTED W/2.30" CENT TO 10114' SLM. STOPPED DUE TO DEVIATION. (LINER TOP @ 10007' MD) *** WELL RETURNED TO PRODUCTION*** MIRU UNIT #9. RIH WITH MEMORY LOGGING TOOLS IN 2.2" CARRIER. RIH TO 11500. LOG INTERVAL 11500 TO 10650. FLAG PIPE @ 10650. POH. VERIFY DATA. GOOD DATA. MU AND RIH WITH GUN #1 (25') (SPILL DRILL IN WELL HOUSE, 14 SECOND RESPONSE) AND PERF INTERVAL 10870' TO 10845'. POH. MU GUN #2 (25'). RIH WITH GUN #2 AND PERF INTERVAL 10845' TO 10820'. POH & RDMO <<< NOTIFY PAD OPERATOR / PCC OF WELL STATUS, LEAVE WELL IN TEST >>> JOB COMPLETED. TESTEVENT--- BOPD: 206, BWPD: 4,956, MCFPD: 8,809, AL RATE: 3,550 FLUIDS PUMPED BBLS 7O DIESEL 75 50/50 METHANOL WATER 145 TOTAL ADD PERFS 09/08/2003 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" PJ2006 POWERJET GUN, LOADED @ 6 SPF, 60 DEPGREE PHASING, RANDOM ORIENTATION. 10820'-10870' Page 1 Permit to Drill No. 2000650 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. PRUDHOE BAY UNIT H-I 6B Operator BP EXPLORATION (ALASKA) 1NC AP1 No. 50-029-20592-02-00 MD 12652 TVD 8974 Completion Date 5/31/2000 ----- Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples N__~o -- Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Lo~ Data Digital Digital Type Media Format Na~ J SRVY RPT Memory Thermal N ,E'/' PROD.SPiN/TEM/ Interval Log Log Run Scale Media No Start Stop 64 12652 2 FINAL 9782 12640 5 FINAL 9600 10200 (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments OH 6/29/2000 SPERRY 10867.. ch 4/6/2001 BL, Sepia CH 7/19/2000 PRES C 4/6/2001 10014 9782-12640 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis Received? ~ Daily History Received? Formation Tops Receuived? Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska April 29, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7m Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs H-16B, AK-MW-00052 1 LDWG formatted Disc with verification listing. API#: 50-029-20592-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO T-HE 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: Sign~~, ' L~~cx,). REOEIYED ~aska 0il & Gas Cons, C0mmissi0p Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ ClaP Pulltubing_ Alter casing_ Repairwell Other X ClBP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 73 feet 3. Address Explorato~._ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1322' FNL, 1265' FEL, Sec. 21, T11 N, R13E, UM (asp's 643324, 5959466) H-16B At top of productive interval 9. Permit number / approval number 3183' FNL, 2319' FEL, Sec. 16, T11 N, R13E, UM (asp's 642207, 5962864) 200-065 At effective depth 10. APl number 2974' FNL, 1626' FEL, Sec. 16, T11 N, R13E, UM (asp's 642885, 5963086) 50-029-20592-02 At total depth 11. Field / Pool 2730' FNL, 1445' FEL, Sec. 16, T11 N, R13E, UM (asp's 643061, 5963333) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12652 feet Plugs (measured) Set CIBP @ 12340' (03/17/2002) true vertical 8974 feet Effective depth: measured 12340 feet Junk (measured) true vertical 8977 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 72 cf Concrete 158' 158' Surface 8626' 13-3/8" 3720 cf Class'G' 2674' 2674' Intermediate 8628' 9-5/8" 1305 cf Class 'G', 130 cf PF 'C' 8676' 7968' Liner 1068' 7" 247 cf Class 'G' 8513' - 9581' 7837' - 8513' Sidetrack Liner 531' 4-1/2" 228 cf Class 'G' 9419'- 10950' 8423'- 8939' Sidetrack Liner 2657' 2-7/8" 124 cf Class 'G' 9995'- 12652' REC~tVED Perforation depth: measured Open Perfs 12180' - 12310' Open PerfsbelowCIBP 12360'-12410', 12414'-12536' APR I 1 200Z true vertical Open Perfs 8992'-8978' Open Perfs below CIBP 8976'- 8974', 8974'- 8974' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9363' with 4-1/2" Tailpipe to 9419'. Packers & SSSV (type & measured depth) 9-5/8" x 7" Baker ZXP Packer @ 8519'. 7" x 4-1/2" Baker S-3 Packer @ 9363'. 7" x 4-1/2" Baker ZXP Packer @ 9425'. 4-1/2" x 2-7/8" Baker KB Liner Top Packer @ 9995'. 4-1/2" HES HXO SSSV Nipple @ 2057'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or I niection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 03/10/2002 Shut-In Subsequent to operation 03/23/2002 1242 12420 953 323 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DeWayne R. Schnorr ~ Prepared by DeWayne R. Schnorr 564-517.,.4 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE H-16B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/14/2002 PACKERS / BRIDGE PLUGS: DRIF-I-/TAG 03/17/2002 PACKERS/ BRIDGE PLUGS: CAST IRON BRIDGE PLUG EVENT SUMMARY 03/14/02 DRIFTED TUBING INTO LINER TO 10110' SLM WITH A 2.2" CENTRALIZER, STOPPED DUE TO DEVIATION. <<<OK TO PRODUCE>>> 03/17/02 MIRU CTU #3, MU BAKER TOOLSTRING, DRIFTED TO 12,400' CTMD. OVERPULL AND BECOME TEMPORARILY DETAINED WHILE POH AT 12,355' THEN 12,335'. FREE TOOLSTRING BY PUMPING DOWN BACKSIDE. RE- DRIFTED SUCCESSFULLY AFTER WHP REDUCED. 12,050' - 12,360'. RIH WITH AND SET BAKER 2-7/8" CIBP @ >>>12,340'<<< (CTM). NOTE OVER- PULLED WITH RUNNING TOOL AT 2-7/8" LINER TOP PACKER -9980'. ***TURNED WELL OVER TO PCC TO POP*** FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (1 TESTS/ 340 DIESEL 20 2% KCL WATER 361 TOTAL Page 1 Scblumkerger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AITN: Sherrie NO. T23 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 3/28/01 Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 1-14 / -) ?-'O 7-7 PRODUCTION PROFILE 03/17/01 1 1 D-14A / ~/~/O~O~ 21054 RST-SlGMA/BORAX 01/28/01 1 1 1 D.S. 16-27A ~--~l~O0~.J 20390 RST-SIGMA/BORAX 09/07/01 1 1 1 H-16B c~ C) Q--{')~ 20236 MCNL 05/28100 1 1 , 1 , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED APR 0 6 2001 Atas~ Oil & Gas Cons. Commission Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: TO: Julie Heusser, .~'~,.,~,\~\ DATE: Commissioner ' Tom Maunder, ~-~~o P. I. SuPervisor -~" ~ { ~-Ok March 28, 2001 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector SVS Misc. tests BPX l .- .43Z&aS. Prudhoe Bay Field M0nd.a.y~ March.12, 2001: I witnessed the four of the Semi-Annual SVS tests on BPX wells H-15,16B,23A,29A in the GC-2 area of the Prudhoe Bay Field. I had to leave before completion of the pad due to a Exploratory wells Diverter function test. Merv Liddelow (BP Rep.) performed the SVS tests today. All components functioned properly and held their pressure tests with the exception of the Surface Safety Valve on H-15 which had a slow internal leak. This was greased, cycled and retested "OK". The well houses were all dean with pilot valves in proper position. SUMMARY: I witnessed the SVS test on four BPX wells in the Prudhoe Bay Field. 4 wellS, ,11 components, One failure. Wellhouse Inspections; 4 wellhouses, No failures Attachments: SVS PBU H-pad 3-28-01 LG.XLS NON-CONFIDENTIAL SVS PBU H-pad 3-28-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Submitted By: Lou Grimaldi Date: Fi¢ arO ad: pruahoe,, Bay neki, 14 Separator psi: LPS 150 HPS 28-Mar 685 :, I: .~ !.~.! I I~ t ! ~ ~1 ..... I I I I I I I II . II I I I I I I I1~.i) I II I I Ill I I. I I I II L I I I Well Pemit Separ Set L~ Test Test Test Date O11, WAG, G~J, Number Number~ psi PSi Tri~ Code Code Code Passed GAS or H-01A 1951100 , , , , , ,,, , ~,, ~, ,, : . . : ... H-02 1710160 H-0~ 1710~20 ............... H-05 1710240 ......................... , ,~ , ~, ,, , , ,, , · . , Hi06 177~20 " ............ . 2 ".. .... , . ... , . ~'~ . , , ~ ,, ,~ ~ , ,,. ~ , H-07A 2001280 , ,, , , ,, , , , , , , ~ , , ,, ~, ,, ,~ ,, , H-08 1770230 ..,, , , ~ , , .~ ...., , ~, n,, , , ~,1. ,, , , ,, , , , t.. , ,,, , ,~... H- 11 1800680 . ,, , , , , _ , , ,,,,. , ,~ . , , .~ ,, ,,, ,, ,,, , , , , , , ,, H-12 18~670 H.l'3 · .i81'0i70 ................................... ~, ,., , ,., , ~ , , , ,, H_~4A ' ~980686' ' ,i ........ H-15'_ ..... ~.:~,~-~ '1'81o610"' 150 " 'p ''4 ..... ~j~ 20~.~50., 685 550/125 525/120 . ~ .... p .... H-17A 1971520 - , ~ ,,, , ,, ~ ,, , ~ , , , . ~, , , ,,, , .... .,, , , , , , H-18 ' ~822'1b0' " , , , ,,,~, ,,,t , , , , , , , , , , , ,. , , ,,, , , ,~ ,, , , H-19B 1980940 , , , ,, ,.. , , i , ,, ,, , ............. . ...... ~ ....... , ,,,, H-20 1830070 H-21 '1860710 ..................... H.22A ..... 1970486 ............................ ~-23A ' 1950850' 685 550/1'2~' 560/125 P'' P ...... ,, ,, , ,,, ,, ~ , , , , ,, , ,,. , , , ,, , , ,,, H-24 1853050: u'2' .... 855680 ...................................... ..... i , , ,,, , ,, , ~ , . ,,~ , . , ,. ,, , . , ,,,, ~ ,, ,, ,, H,26 1852770 , , , , , , , , ., , i, ~ , ~ , ,,,, ,, , ,~ ,, i ~ , ~ , , ~ , ,, ,,, H-27 1852360 ,,., . .... , , , , ~, , , , . , , , , , . , ,, H-28 1880~0 H-29A 198~'380 ' 685 550/i25 570)140' 'P ......P ............... , , , ~ , , ~,, , , , .,, , ,,,,, , , , ,, . ,, ,, ,, ~ , , H-30 1880350 ,, ,, , . ,, . .. ~. , ,, i ..... ~. , , , , ,, ,, ,, , , , ,, H-31 1940140 H,32 ..... 1940250 .......... ' .............................. ~ - H-33 1'946380 .................................. u_~_o. ..... 1971~0 ................ : ..... ' ...................... : - ~ ,, ,. ~ . ~ i ,, ~ . ~ ,, , , , , , , , , H-35 1951490 : i , il i i , ii , i i il i , i i il i i i i ii il i ii RJF 1/16/01 Page 1 of 2 010328-SVS PBU H-pad-LG Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, ,,Number Number .... PSI PSI ,Trip ,Code Code Code Passed ,G,AS~or,.CYCLE H-36A 2000250, H-37 ' 1971020' Wells: ..... 4 Components: ,, , 1 !, Failures: , ~, 1 Failure Rate: 9.09% [~ 90 Day Remarks: parti~ pad r.esult.s. ,Dual pilots tested on above wells. s tL I I I I I II I I I I II . . . I II ~l~ II I III I [ RJF 1/16/01 Page 2 of 2 010328-SVS PBU H-pad-LG ..-~oo · c~3" Scblmberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 332 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints !H~-16B PSP PRODUCTION PROFILE 000708 I 'i IG-o5 ~ 'qC,~! ..... 20271 RST-SIGMA 000615 1" 1 1 G-07 ~ ~.~e JJ"~.- 20272 RST-$1GMA 000616 1 1 ... 1 , ,,, ,, ~,, , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 7/12/00 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED JUL 1 9 000 Naska 0il & Gas Cons. Commissi0rt Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie~ "-'" STATE Of ALASKA ALASKA ..... AND GAS CONSERVATION COMM, ~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Deepen H-16A to H-16B 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-065 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20592-02 4. Location of well at surface ~ ~, .......... i , ~ 9. Unit or Lease Name 1322' SNL, 1265' WEL, SEC. 21, T11N, R13E, UM t ~L?"~l~'~:~if..~.- ~vt~ i~ At top of productive interval ~ ~;~ ~: ; Prudhoe Bay Unit 2096' NSL, 2310' WEL, SEC. 16, T11N, R13E, UM I ........... At total depth · ,-?~,:~ ~. ',~ ' 10. Well Number 2548'NSL, 1445'WEL, SEC. 16, T11N, R13E, UM i ...... '~ ......... 'i i' H-16B 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 72.86' ADL 028284 12. Date Spudded 5/24/2000 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'5/20/2000 5/01/2000 115' water depth' if °fish°re N/A MSL J 16. No. of Completions One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 12652 8974 FTI 12589 8976 FTJ [] Yes [] NoI (Nipple) 2057' MDJ 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, RES, GR, ROP, Memory CNL, 23. CASING, LINER AND CEMENTING RECORD CASING SE~ rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PUU 20" x 30" Insulated Conductor Surface 110' 36" 8 cu )/ds Concrete 13-3/8" 72# L-80 Surface 2674' 17-1/2" 3720 cu ft Class 'G' 9-5/8" 47# L-80 Surface 8676' 12-1/4" 1305 cu ft Class 'G'~ 130 cu ft PF 'C' 7" 26# L-80 8513' 9581' 8-1/2" 247 cuft Class 'G' 4-1/2" 12.6# L-80 9419' 10950' 6" 228 cu ft Class 'G' 2-7/8" 6.16# L-80 9995' 12652' 3-3/4" 124 cu ft Class 'G' 24. Perforations op. en to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and imerval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9419' 9363' MD TVD MD 1-VD 12414' - 12536' 8974' - 8974' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. ~.,~ ~* DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 20 Bbls MeOH 2 9 2000 27. &~n~ PRODUCTION TEST ~ :.~,_; .~_.~ . ~j, Date First Production Me~°d of Operation (Flowing, gas lift, etc.) June 5, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL=BBL GAS-MCF WATER-BBL CHOKE SIZE [ GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL 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. Sag River 9533' 8487' Shublik 9586' 8574' Sadlerochit 9724' 8668' Zone 2 10056' 8843' 24N 11175' 8987' Zone 2A / 22N 11604' 9036' 24N 12014' 9004' OWC 12175' 8992' ~a~ka 0i~ ~' .... "~' '''~ 31. List of A~achments: Summa~ of Daily Drilling RepoAs, Su~eys 32. I hereby ceAi~ that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~-- ~ Title TechnicalAssistantll, Date H- 16B 200-065 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL; This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. I'rEM ;37: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28,' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: H- 16 B Accept: 05/23/00 Field: Prudhoe Bay Spud: 05/24/00 APl: 50-029-20592-02 Re lease: 05/31/00 Permit: 200-065 CTD Unit: Nordic #1 COIL TUBING DRILLING 05/24/00 Accept rig 15:00 hrs 5/23/00. Replace lock down pin on blind/shear rams. Pressure test BOPE. Bullhead kill well with SW; chase with FIo-Pro mud. MU milling BHA. RIH. Tag and mill XN at 9455' CTM. RIH. Tag landing collar at 10906' CTM. Start milling shoe track. 05/25/00 .Mill shoe track and 15' of formation to 10965' corrected depth. POOH. LD milling BHA. PU drilling BHA (MWD resistivity, PWD, 1.1 deg motor; DS49rr). TIH. Drill 10965' - 11365'. 05/26/00 Drill 11365' - 11800'. Displace well to experimental 7.9 ppg FIo-Pro mud with glass beads. Resulting high pump pressure prohibited further drilling. Also, uphole shales started getting sticky with the new -system in place. Ream shales. Displace well to 9.2 ppg FIo-Pro w/12# Klagard. Drill 11800'- 12050'. 05/27/00 /Drill 12050' - 12120'. MAD pass. Drill 12120' - 12215'. Bit worn. MAD pass to casing. POOH. LD drilling BHA. Download resistivity data. MU drilling BHA #3 (MWD resistivity, 1.1 deg motor, DS49 bit). RIH. Drill 12215' - 12350'. 05/28/00 Drill to 12353', unable to get motor differential. Large amount chert in samples. POOH, bit smoothed off. Change bit, download Sperry Resistivity tool. TIH. Drill to 12365'. Unable to make hole - just stacks or stalls, difficult to get steady slide. POOH to check bit. Ream very sticky shales at 11700'. Pull into shoe track and got stuck. Packed-off, no returns. Work pipe down to free BHA. Started getting returns again, but not 100%. POOH. CTC packed with clay. Bit OK. Cut 300' of coil for fatigue management. MU drilling BHA #5. RIH. 05/29/00 Drill to corrected TD 12652'. Bit worn from chert. MAD pass. POOH. LD drilling BHA. Download resistivity data. MU SWS memory CNL tool inside 2-3/8" PHo6 carrier with nozzle. RIH. Log down and up from 9800' to TD. POOH. 05/30/00 LD memory CNL logging tools. MU and RIH with 87 jts 2-7/8" STL liner. Install CTLRT. RIH to TD. Drop ball and release from liner. Displace FIo-Pro with 9.3 ppg KCI water. Losses at 40% initially, slowed to 5% after displacement. Mix and pump 22 bbls 15.8 ppg Class G cement. Load CT dart, chase, latch into liner wiper plug and displace to landing collar. Bump. Test floats. Unsting, full returns. POOH. LD CTLRT. MU nozzle and 85 jts of 1-1/4". RIH. H-16B, Coil Tubing Drilling Page 2 05/31/00 Wash into liner. Jetted cement from 12560'-12600', wash to PBTD at Latch Collar. Spot 150K LSRV FIo- Pro in liner. POOH to 9200'. Pressure test liner to 1500 psi, lost 250 psi in 15 minutes, re-pressure to 1500 psi, lost 150 psi in 15 minutes (Cement compressive strength-2760 psi). POOH, stand back I ~,~" CS Hydril. WO LTP. PU Baker KB liner top packer & RIH. Sting in to top of liner deployment sleeve. Unsting, space out CT to load setting ball and release same. Pump down to seat - OK. Landed at 51.7 bbl away. Sting back into liner top and space out +/- 1' from fully inserted. Set slips with 2700 psi. Set down to 4000# CT weight and energize packer element. Test down prod tbg to 1500 psi - 5 min. OK. Bleed off. Pressure up CT to 3800 psi and release from LTP - OK. Pull up hole and test packer and liner to 1500 psi for 30 rain - OK. Good test - 80 psi pressure drop. POH. L/O Baker tools. Safety Meeting. RIH with 122 ft of SWS 2" Powerjet Perforating guns at 4 SPF. RIH with 42 STDS of CSH workstring. RIH with perforating BHA on CT. Tag PBTD and correct to 12,589 ft BKB. Pump 10 BBL new FIoPro. Drop 5/8" steel ball and displace with KCL water. Position bottom perforating charge at 12,536 ft. Firing head sheared at 3400 psi. POOH with perforating BHA. Prepare to lay out CSH workstring in singles for rig move. 06/01/00 Safety meeting. LD 42 stands 1 1,~,, CSH workstring. PJSM prior to laying down perf guns. Make up well control XO joint. POH & LD guns. All shots fired. Perforated Interval: 12,414 - 12,536 FT BKB. 122 ft of 2" PowerJet charges at 4 SPF. RIH with CT nozzle to 2000'. Displace MEOH to nozzle and POH laying in MEOH at 2:1 up to 150'. Lay in at 1:1 to surface. Close swab valve. Rig down for move to F Pad. Pressure tested tree cap to 4,000 PSI. Well secured. Released rig from well H-16b at 14:30 hrs on 05/31/00. North Slope Alaska Alaska State Plane 4 PBU_ WOA H Pad H-16A - H-16B Surveyed: 28 May, 2000 SURVEY REPORT 7 June, 2000 Your Reft API-500292059202 Surface Coordinates: 5959466.00 N, 643325.00 E (70° 17' 48.3133" N, Kelly Bushing: 72.86ft above Mean Sea Level 148° 50' 21.6702" W) O R I L L I (= S Survey Ref: svy9805 A ~i,.~t'~J'*'~ CO~A~*Y North Slope Alaska Measured Depth (ft) Incl. 10867.64 10965.00 10994.13 11022.33 11052.73 11089.53 11123.93 11 156.33 11187.33 11218.73 11251.53 11281.53 11311.93 11341.33 11372.33 11405.93 11434.33 11465.93 11501.13 11543.53 11576.73 11605.33 11637.93 11664.33 11699.13 85.04O 82.560 74.8O0 72.950 75.420 75.280 77.620 78.850 80.260 81.320 81.320 80.620 80.260 80.000 80.530 81.060 84.930 88.460 89.600 88.020 85.370 86.170 89.520 91.370 92.430 Sperry-Sun Drilling Services ~; ~ ~ i~-~ ~ ;~Your Ref: API-500292059202 .... ~ ~,,?~i~.~.~ Survey Report for H-16A H-16B Surveyed: 28 May, 2000 9 2000 ~, '~ Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (tt) fit) fit) fit) fit) fit) 63.730 63.540 62.933 62.423 61.863 61.183 57.503 53.273 49.753 45.523 42.523 39.353 33.713 32.833 26.843 26.843 28.433 33.713 34.953 41.293 43.583 48.343 49.043 52.393 56.733 8854.12 8926.98 2937.96 N 1570.83W 5962373.47 8864.64 8937.50 2980.94 N 1484.11W 5962418.10 8870.35 8943.21 2993.79 N 1458.63W 5962431.43 8878.18 8951.04 3006.23 N 1434.56W 5962444.32 8886.47 8959.33 3019.90 N 1408.70W 5962458.48 8895.78 8968.64 3036.87 N 1377.41W 5962476.05 8903.84 8976.70 3053.92 N 1348.65W 5962493.65 8910.45 8983.31 3071.94 N 1322.55W 5962512.16 8916.07 8988.93 3090.91N 1298.70W 5962531.58 8921.10 8993.96 3111.79 N 1275.80W 5962552.89 8926.05 8998.91 3135.10 N 1253.27W 5962576.63 8930.76 9003.62 3157.48 N 1233.86W 5962599.38 8935.81 9008.67 3181.56 N 1216.02W 5962623.79 8940.85 9013.71 3205.77 N 1200.13W 5962648.30 8946.10 9018.96 3232.26 N 1184.94W 5962675.08 8951.47 9024.33 3261.86 N 1169.96W 5962704.95 8954.93 9027.79 3286.82 N 1156.88W 5962730.16 8956.76 9029.62 3313.83 N 1140.61W 5962757.47 8957.35 9030.21 3342.89 N 1120.76W 5962786.91 8958.23 9031.09 3376.22 N 1094.60W 5962820.73 8960.15 9033.01 3400.68 N 1072.24W 5962845.61 8962.26 9035.12 3420.50 N 1051.74W 5962865.82 8963.48 9036.34 3442.00 N 1027.28W 5962887.78 8963.28 9036.14 3458.71N 1006.85W 5962904.88 8962.12 9034.98 3478.87 N 978.51W 5962925.58 Dogleg Rate (°/100fi) N 641698.43 E N 641784.31 E 2.555 N 641809.54 E 26.717 N 641833.37 E 6.786 N 641858.96 E 8.316 N 641889.93 E 1.828 N 641918.36 E 12.426 N 641944.11E 13.333 N 641967.60 E 12.057 N 641990.09 E 13.719 N 642012.17 E 9.042 N 642031.15 E 10.693 N 642048.53 E 18.333 N 642063.95 E 3.079 N 642078.64 E 19.121 N 642093.05 E 1.577 N 642105.65 E 14.716 N 642121.40 E 20.074 N 642140.70 E 4.785 N 642166.21 E 15.407 N 642188.10 E 10.541 N 642208.22 E 16.832 N 642232.27 E 10.498 N 642252.38 E 14.495 N 642280.32 E 12.831 Alaska State Plane 4 PBU_WOA H Pad Vertical Section (ft) Comment 276.93 373.08 401.46 428.42 457.55 493.05 526.46 558.16 588.49 619.06 650.64 679.09 707.15 733.64 760.79 789.44 813.97 842.31 874.76 914.83 946.89 974.86 1007.09 1033.32 1068.05 Tie-on Survey Window Point Continued... 7 June, 2000 - 13:04 - 2 - DrillQuest 1.05,05 North Slope Alaska Measured Depth (ft) Incl. 11731.73 11759.93 11795.83 11827.63 11862.23 11893.83 1~1929.23 11968.43 12o01.43 12o32.63 12o66.03 12o93.43 12126.63 12156.83 12192.03 12233.23 12265.23 12315.43 12345.13 12384.93 12424.33 12455.33 12484.73 12509.33 12540.93 96.390 98.410 97.8OO 96.740 95.330 94.360 94.540 95.150 94.630 92.160 91.980 93.040 95.070 98.680 96.040 95.510 96.830 93.040 91.190 93.130 93.920 90.750 87.930 87.050 87.740 Azim. 60.153 64.203 68.783 74.773 77.943 81.643 87.113 92.043 93.633 89.573 86.053 84.993 80.943 78.123 74.073 71.783 64.023 58.743 57.333 54.683 46.223 42.523 39.183 36.003 28.443 Sub-Sea Depth (ft) 8959.62 8955.98 8950.92 8946.89 8943.25 8940.58 8937.84 8934.52 8931.71 8929.86 8928.65 8927.45 8925.11 8921.49 8916.98 8912.83 8907.24 8904.64 8903.54 8902.04 8899.61 8898.35 8898.69 8899.77 8901.21 Sperry-Sun Drilling Services Survey Report for H-16A - H-16B Your Ref: API-500292059202 Surveyed: 28 May, 2000 Vertical Depth (ft) 9032.48 9028.84 9023.78 9019.75 9016.11 9013.44 9010.70 9007.38 9004.57 9002.72 9001.51 9000.31 8997.97 8994.35 8989.84 8985.69 8980.10 8977.50 8976.40 8974.90 8972.47 8971.21 8971.55 8972.63 8974.07 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3495.88 N 950.83W 5962943.11N 642307.68 E 3508.93 N 926.10W 5962956.63 N 642332.15 E 3523.10 N 893.52W 5962971.42 N 642364.46 E 3532.96 N 863.57W 5962981.85 N 642394.21 E 3541.07 N 830.14W 5962990.60 N 642427.48 E 3546.65 N 799.16W 5962996.76 N 642458.35 E 3550.10 N 764.05W 5963000.89 N 642493.39 E 3550.39 N 725.00W 5963001.92 N 642532.42 E 3548.76 N 692.16W 5963000.92 N 642565.29 E 3547.90 N 661.04W 5963000.64 N 642596.42 E 3549.17 N 627.69W 5963002.55 N 642629.74 E 3551.31N 600.40W 5963005.21 N 642656.99 E 3555.36 N 567.54W 5963009.89 N 642689.76 E 3560.80 N 538.06W 5963015.89 N 642719.13 E 3569.19 N 504.19W 5963024.92 N 642752.84 E 3581.22 N 465.01W 5963037.70 N 642791.78 E 3600.65 N 417.14W 5963058.04 N 642839.27 E 3615.06 N 390.75W 5963072.95 N 642865.39 E 3630.77 N 365.57W 5963089.14 N 642890.26 E 3653.00 N 332.60W 5963111.99 N 642922.80 E 3678.01 N 302.30W 5963137.58 N 642952.62 E 3700.15 N 280.64W 5963160.12 N 642973.84 E 3722.38 N 261.42W 5963182.72 N 642992.64 E 3741.85 N 246.43W 5963202.47 N 643007.26 E 3768.54 N 229.61W 5963229.47 N 643023.57 E Dogleg Rate (°/100ft) 16.029 15.941 12.744 18.980 9.981 12.064 15.414 12.628 5.053 15.211 10.546 5.468 13.618 15.126 13.654 5.678 15.052 21.466 7.830 8.248 21.525 15.708 14.867 13.401 23.999 Alaska State Plane 4 PBU_WOA H Pad Vertical Section Comment (ft) ) 1100.54 1128.39 1163.44 1193.94 1226.42 1255.46 1286.82 1319.76 1346.45 1372.11 1400.80 1424.87 1454.66 1482.37 1515.37 1554.80 1605.54 1635.53 1665.20 2000 1704.96~Ja~KP- 1743.99 1774.19 1802.41 1825.57 1854.19 Continued... 7 June, 2000 - 13:04 - 3 - DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for H- 16A - H- 16B Your Ref: AP1-$00292059202 Surveyed: 28 May, 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) 12568.53 88.280 21.383 8902.17 8975.03 3793.54 N 218.00W 5963254.69 N 643034.70 E 12597.93 90.480 21.033 8902.48 8975.34 3820.94 N 207.36W 5963282.29 N 643044.81 E 12620.33 92.600 19.793 8901.88 8974.74 3841.93 N 199.55W 5963303.42N 643052.22 E 12652.00 92.600 19.793 8900.44 8973.30 3871.69 N 188.84W 5963333.39 N 643062.36 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 27.016° (24-May-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 57.100° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12652.00ft., The Bottom Hole Displacement is 3876.30ft., in the Direction of 357.208° (True). Dogleg Rate (°/100fi) 25.639 7.577 10.963 0.000 Alaska State Plane 4 PBU_WOA H Pad Vertical Section (ft) Comment 1877.52 1901.33 1919.29 1944.45 Projected Survey Continued... 7 June, 2000 - 13:04 - 4 - DrillQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Survey Report for H-16A - H-16B Your Ref: APi-$00292059202 Surveyed: 28 May, 2000 Alaska State Plane 4 PBU_WOA H Pad Comments Measured Depth (ft) 10867.64 10965.00 12652.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8926.98 2937.96 N 1570.83 W 8937.50 2980.94 N 1484.11 W 8973.30 3871.69 N 188.84 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 12652.00 8973.30 Survey Tool Description MWD Magnetic 7 June, 2000 - 13:04 - 5 - DrillQuest 1.05.05 ALASKA OIL AND GAS CONSERVATION COPl~IlSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit H-16B BP Exploration (Alaska) Inc. Permit No: 200-065 Sur Loc: 1322'SNL, 1265'WEL, Sec. 21, T1 IN, R13E, UM Btmhole Loc. 2589'NSL, 1307'WEL, Sec. 16, T1 IN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Robert N. Christenson, P.E. Chair BY ORDER OF THE_~OMMISSION DATED this l ~ q~--"~ day of May, 2000 dlf/Enclosurcs cc: Dcpartmcnt of Fish & Gamc. Habitat Scction w/o encl. Department of Environmental Conservation w/o cncl. /-'-,, STATE OF ALASKA ---" '-"';~/ ALASKA ,L AND GAS CONSERVATION COMIC. ~ION I PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] 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. KBE = 72.86' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028284 4. L(~cation' of we'll at surface ,/ ~/ ,,," ' 7'. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1322' SNL, 1265' WEL, SEC. 21, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1261' NSL, 3553' WEL, SEC. 16, T11N, R13E, UM H-16B Number 2S100302630-277 At total depth 9. Approximate spud date 2589' NSL, 1307' WEL, SEC. 16, T11N, R13E, UM 05/22/00 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 028281, 2690' MDI No Close Approach 2560 12803' MD /8880' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10950' Maximum Hole Angle 98 o Maximum surface 2194 psig, At total depth (TVD) 8800' / 3250 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casinq Weiqht Grade Couplin.q Lenqth MD TVD MD TVD (include staqe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2603' 10200' 8803' 12803' 8880' 112 cuft Class 'G' 19,_TL0 be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10950 feet Plugs (measured),.,,;_,."' ~'~v 0 4 2000 true vertical 8937 feet Effective depth: measured 10866 feet Junk (measured) ~.~,' ' '~'~ ..... ~ ..... ' ...... true vertical 8927 feet ..... Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2638' 13-3/8" 3720 cuft Permafrost II 2674' 2674' Intermediate 8642' 9-5/8" 1305 cuft Class 'G', 130 cuft PF 'C' 8676' 7968' Production Liner 1068' 7" 480 cuft Class 'G' 8513' - 9581' 7837' - 8513' Sidetrack Liner 1531' 4-1/2" 228 cu ft Class 'G' 9419' - 10950' 8423' - 8937' Perforation depth: measured 10560' - 10680' true vertical 8895'- 8906' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 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 Ted Stagg ,~~/ Title C TDrilling Engineer Date 5-/~/~° Permit Number ._ ...-. IAPl Number ,/ ........ j ' 'Ap. pr~ovalp~e~,,I See cover e.er ~ ~-~ ~ ~) I 50- 029-20592-02 I ,~'"'/~ /'''~ I other for requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes Hydrogen Sulfide Measures .~/'Yes [] No Directional Survey Required ..]~'es '~'No Required Working Pressure for BOPE [] 2K; [] 3K; [~4K; [] 5K; [] 10K; [] 15K Other: ORIGINAL SIGNEDBY by order of ~--~ /~.. ~)~) Approved By Robert N. Christenson Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX H-16b Sidetrack Summary of Operations: H-16a will be extended to a target in mid Zone 2 that will provide optimum standoff from both water and gas. H-16b will drill out the shoe of H-16a and be completed with a cemented liner that will cover and shut off the existing H-16a perforations. This extension will be conducted in two phases, the first being already done. Phase 1' Test and drift tubing. · A Tubing Integrity Test was successfully performed on 4/25/00. · A tubing drift was run on 4/125/00. Phase 2: Kill, mill shoe, drill and complete sidetrack: Planned for May 22, 2000. Drilling coil will be used to kill the well with 8.6 ppg FIo-Pro, mill the shoe track and drill and complete the directional hole as per attached plan. Mud Program' · Phase 1' production fluids · Phase 2: FIo-Pro (8.6- 8.7 ppg) Disposal: ~;?'~¥ 0 4 2000 · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject · All Class I wastes will go to Pad 3 for disposal. Aqr,~(,.~,,~.~~ Casing Program: · 2 7/8", 6.16~, L-80, ST-L liner will be run from TD to approx. 10,200' MD and cemented with approx. 20 bbls. cement to bring cement to the top of the 2 7/8" liner. The liner will be pressure tested to 2200 psi and pe~orated with coiled tubing conveyed guns. Well · · · Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. Open hole resistivity and cased hole CNL logs will be run. Hazards No faults or lost circulation are expected. Res. pressure is normal. Reservoir Pressure Res. pressure is approx. 3250 @ 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2194 psi. TREE: 4 1/16" McEVOY WELLHEAD: McEVOY ACTUATOR: BAKER H-16b Proposed Completion KBE: 72.48' BFE= 24.38' 13-3/8" 72 #fit L-80 BTRS. 1'2676' I 4 1/2" OD.12.6# L-80 MOD/BUTT/TBG TUBING.ID:3.958" CAP:.0152 BBLS/FT. 18513'17"x 9-5/8" BAKER ZXP LNR/HGR ~ PKR W/TIEBACK (PKR ID = 6.313") 7" 26# L-80 IBT-MOD LNR ID: 6.276" CAP: .0383 BBL/FT KOP-8719 HIGH ANG 89 DEG. @ 10454' MD TOP OF 7" LINER 9-5/8", 47#/ft, L-80, BTRS. 9368' Old P&A'D WELLBORE .---- ~AY 04 200¢ .BTD 110567'1 7" 29¢/FT, L-80 BU~/CSG. 4 1/2" SSSV LANDING NIPPLE I (HES "HXO" 3.813" ID ) I 2057' ICAMCO GAS LIFT MANDRELS ! i # 2 -5: 4.5"X 1.5" MMG-M (3.958" ID) with RK LATCHES i# 1: 4.5"X 1" KBG-2LS (3.909" ID) with DK-1 W/BTM LATCH NO MD(BKB) TVD DEV 5 3099' 3098' 6 4 3983' 3936' 25.8 3 6542' 6109' 31.2 2 8400' 7757' 31.8 1 9285' 8346' 55.8 7" SHOE 9581' I MILLED WINDOW IN 9 5/8" CSG I 8676'-8714' 4 1/2" "X" NIPPLE Baker 4-1/2"x 7" Model "S" Packer (3.875" ID) 9352' I 93e3' I 4 1/2 .... X" NIPPLE (HES) ( 3.813" ID) 4 1/2 .... XN" NIPPLE (HES) ( 3.725" ID) 9386'I 9407'I 4.5"X 7" BAKER ZXP LNR/PKR W/TIEBACK SLV (PKR ID =( 3.938 .... I a41a'l 4 1/2" 12.6# L-80 MOD/BUTT LINER ® 11o866'I 4 1/2" SHOE @ 110950' I 2 7/8" liner cemented to approx. 10,200' MD PERFORATION SUMMARY SIZE SPF INTERVAL 2 3/4" 4 10560'-10680 OPEN Name H-16A I -2,500 H-16A 4,500 ::.' 4,000 3,500 3,000 2,500 -2,000 I I I -1,500 -1,000 -500 X distance from Sfc Loc 5OO CLOSURE Distance 3,912 ft Az 358 de~! NEW HOLE E/W (X) NIS (Y) Kick Off -1,554 2,944 TD -127 3,910 State Plane 643,198 5,963,376 Surface Loc 643,325 5,959,466 DLS de~ll100 Tool Face Length Curve t 6 -90 20 Curve 2 14 -97 325 C~Jrve 3 14 70 390 Curve 4 14 90 199 Curve 5 t4 -90 439 Curve 6 14 180 41 Curve 7 14 90 439 1,853 Drawn: 5/3/2000 10:15 Plan Name: Case 104 H-16A Vertical Section 0 500 8500 8550 8600 8650 8700 ~8750 8800 8850 8900 8950 9000 9O5O Path Distance(Feet) · 1,000 1,500 2,000 2,500 3,000 3,500 4,000 lH-16b Case 104 5/3/00 -27~ Angle @ K.O.= 83 deg MD:10950 Tot Ddd:1853 ft 12803 TD Marker Depths (~Orig Wellbore TSAD ol 01ft'rvD S, S I. o 8,880[ 8,880]ff 'I-VD I 8,SS41 t D 10,9501ft MD Deprtr ~KO 3,344 ff IMD KO Pt 10,950 MD New Hole 1853 Total MD 12,803 TVD TD 8,880 Curve DLS degll00 6 ToolFace -9O Length 2O Curve 2 14 -97 325; Curve 3 14 7( 390 Curve 4 14 90 199 Curve 5 t4 -90 439 Curve 6 14 180 41 Curve 7 14 90 439 1,853 Drawn: 5/3/2000 10:15 Plan Name: Case 104 I 10,000 psi Pack-Off H-16b CT Drilling & Completion BOP ILl Z · 1 2" 22.5" 1 8" 7 1/16" Annular 7 1/16" 5000 psi 7 1/16" Pipe/Slip ~ 2 318" 7 1/16" x 5,000 psi Slips 7 1/16" Pipe I 2 7/8" 3/8" SWAB OR MASTER VALVE I,,IAY 04 2000 I..! 1 67631 DATE / CHECK NO: I 4/18/00 ~0167631 VENDOR ALASKAST40 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 041700 CK041700 100.00 100. O0 HANDLING INST' s/h tee~ie x 4628 , . , THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~I[e]IIF;IlB '--- 100. OO 1 OO. OO EXPLORATION (ALASKA)~;INO, ,;'::,?~,,.. ,,, :: ::.:.,:.:, · ,,..,~,.,o,~....,:~'.,.,~... NO:. H 1:.:676::31. i; ~l:~[~ ~.~:: N~ttONAEOITY BANK ':?~:: ': ':' CoNsOliDAtED 6OMM~RcIALACCOUNT · ~ ::: 'CLEVELAND 0Hi0 : ' ' : .. : ;~;:;..56~389' 412 OO 167631 PAY To. The STATE OF ALASI~AiAOQCC ~::::::'. ORDER 3001 PORCUPINE :DRIVE'!. :i::~::'' ::~::': :: , · ****************************************** US DOLLAR ..:;;~..: ..i~!'. ,..:~:::::,;;.:' ii:.:i "::'i: DATE :: ;::: : AMOUNT ANCHORAGE AK 99501 NOT VALID AFTER 120 DAYS ":"- '".,. .,,, ('"' ~2i.. :' .. M/ELL PERMIT CHECKLIST COMPANY FIELD & POOL ADMINISTRATION INIT CLASS ~Cv" Z'- 4~/'~-:-- DATE WELLNAME /'/-z/'~ PROGRAM: exp~ ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15oday 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 string 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 ..... GEOL AREA dev UNIT# ~ wellbore seg ~ ann. disposal para req ~ ON/OFF SHORE Y N Y N .~ DATE 5/, GEOLOGY 25. BOPEs, do they meet regulation ................ ~) N 26. BOPE press rating appropriate; test to 27. Choke manifold complies w/APl RP-53 (May'84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y N 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ........ ,4,/,~ Y 32 .............. Seismic analysis of shallow gas zones ,,1j Y IIA, _PR DATE 33. Seabed condition survey (if off-shore) ............. /~ Y S-' ¢' ~D 34 Contact name/phone for weekly progress reports [exploratory onl~,,~]~Y ~r~~~___~ -" ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N APPR DATE GEOLO. G,¥:, ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: 1:3 0 Z 0 -! c:\msoffice\wordian\diana\checklist (rev. 02/17/00) 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 APPENDIXl 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 $ Tue Apr 16 20:28:48 2002 Reel Header Service name ............. LISTPE Date ..................... 02/04/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/04/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing LibraryJ Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TA~E HEADER Prudhoe Bay Unit M~D/~AD LOGS O~ATOR: ~ING COMPANY: T~PECREATION D~TE: JOB DATA H-16B 500292059.202 BP Exploration (Alaska), Inc. Sperry Sun 16-APR-02 MWD RUN 1 MWD RUN 2 MAD RUN 2 JOB NUMBER: AK-MW-00052 AK-MW-00052 AK-MW-00052 LOGGING ENGINEER: B. J~HN B. JAHN B. JAHN OPERATOR WITNESS: J. MCMULLEN/ J. MCMULLEN/ J. MCMULLEN/ 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 4 MAD RUN 4 AK-MW-00052 AK-MW-00052 B. JAHN B. JAHN J. MCMULLEN/ J. MCMULLEN/ 13 liN 13E 1322 1265 72.48 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 4.500 10950.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. 3. MWD RUNS i -4 ARE DIRECTIONAL WiTH DUAL GAMF~ RAY (DGR) UTiLiZiNG GEIGER MUELLER TUBE DETECTORS ANE ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). NO FOOTAGE DRILLED ON MWD RUN 300 AND IS NOT PRESENTED. 4. GAMMA RAY (SGRC) LOGGED BEHIND CASING FROM 10917' MD, 8861' SSTVD TO 10950 'MD, 8865' SSTVD. 5. A MADPASS (MAD) PASS WAS PERFORMED WHILE TRIPPING OUT OF THE HOLE AFTER MWD RUNS 2 & 4. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 6. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PD~ OF 5/28/00 (MCNL GR) WITH A KBE OF 78.86' AMSL. THIS WELL DRILLED OUT OF THE 4.5,' SHOE FROM H-16A AT 10950' MD, 8865' SSTV ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL H-16B WITH API 50-029-20592-02. THIS WELL REACHED A TOTAL DEPTH OF 12652' MD, 8903' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = '~D '~E ~FT' DE~iFED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD) $ File Header Service name ............. STSLIB.00t Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 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 10916.0 12602.5 RPM 10939.0 12613.5 RPS 10939.0 12613.5 FET 10939.0 12613.5 RPX 10939.0 12613.5 RPD 10939.0 12613.5 ROP 10960.5 12648.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH !091~.C 10940.5 10943 : 10946.5 10950.5 10955.0 10960.5 10965.0 10974.5 10977.5 10980.0, 10984.5 10988.5 11005.0 11010.0 11017.5 11029.0 11036.5 11043.5 11047.0 11053.0 11056.0 11059.0 11063.5 11065.5 11071.5 11079.0 11088.0 11089,5 11095.5 11108.0 11129.0 11160.5 11178.0 11194.0 11204.0 11206.0 11226.0 11231.0 11241.0 11250.0 11256.5 11258.5 11261.5 11267.0 11275.5 11280.0 11283.5 11291.0 11298.0 11303.5 11313.0 11324.0 11334.5 11343.5 11350.5 11362.5 11375.5 11377.5 11379.5 11389.0 11394.0 11398.0 11400.5 11409.0 11411.5 11417.5 11430.0 11438.0 11439.0 11445.0 (MEASURED DEPTH} EQUIVALENT UNSHIFTED DEPTH GR i091,-.~~ 10941.5 10944.5 i0950.C 10954.0 10959.5 10965.0 10968.5 10978.0 10980.5 10984.5 10988.5 10993.0 11010.5 11015.0 11023.0 11034.5 11042.0 11045.5 11049.0 11054.5 11058.0 11061.5 11067.5 11069.5 11076.0 11082.0 11091.5 11093.5 11099.0 11111.5 11119.5 11125.5 11133.5 11164.5 11182.5 11199.0 11208.0 11210.5 11236.0 11239.5 11248.5 11258.5 11264.0 11265.5 11269.0 11272.5 11282.0 11287.5 11292.0 11298.0 11305.5 11312.0 11320.0 11329.0 11340.0 11349.0 11357.5 11369.0 11382.0 11383.5 11387.0 11394.0 11398.5 11403.5 11405.5 11414.5 11418.0 11423.5 11432.0 11441.5 11444.5 11453.5 11451.0 11455.0 11460.5 11468.C 11471.0 11476.5 11481.0 11488.0 11495.5 11505.5 11512.0 11516.0 11521 0 11528 0 11530 0 11534 0 11537 0 11544 0 11555.0 11568.5 11572.5 11576.0 11587.0 11591.0 11597.0 11605.0 11611.0 11613.5 11617.5 11626.0 11631.5 11634.0 11646.0 11650.5 11455 5 !146C 5 11468 5 11476 5 11479 0 11482 5 11489 5 11496 0 11503 5 11514.5 11521 5 11525 5 11530 0 11536 5 11538 5 11542 0 11546.5 11555.0 11564.5 11579.5 11584.5 11588.0 11595.0 11599.0 11605.0 11614.0 1161.7.5 11621.5 11'626.0 11633.0 11637.5 11642.5 11653.0 11659.5 11664.5 11668.5 11687.0 11691.5 11695.5 11699.0 11701.0 11707.5 11710.5 11713.5 11718.0 11728.5 11730.5 11734.0 11743.0 11758.0 11767.0 11775.0 11779.5 11783.0 11785.5 11790.0 11794.0 11802.0 11806.5 11809.5 11818.5 11824.0 11842.5 11852.5 11867.5 11875.5 11879.0 11883.0 11886.0 11890.0 11895.5 11908.5 11915.5 11921.5 11672.0 11676.5 11,692.5 11698.0 1,1701.0 11704.5 11711.5 11716.5 11720 0 11724 5 11727 5 11737 0 11738 0 11742 0 11749.0 11765.0 11772.5 11780.0 11784.5 11788.5 11790.0 11794.0 11800.0 11806.5 11808.5 11816.0 11827.5 11830.5 11844.0 11855.0 11872.5 11880.5 11884,0 11888,0 11891.5 11894.5 11899.0 11913.5 11920.0 11925.0 11924 0 11930 C 11935 5 11945 C 11948 5 11959 5 11962 0 11979 5 11984 0 11993.0 11999.0 12003.5 12006.0 12019.0 12026.5 12033.5 12043.5 12059.5 12066.0 12070.5 12078.0 12080.5 12087.0 12094.0 12101.5 12116.5 12126.0 12138.5 12149.0 12151.0 12154.5 12161.0 12165.0 12184.0 !2,!~1.5 12194.0 12201.0 12213.0 12219.0 122 30.0 12233.5 12242.0 12270.0 12274.5 12277.5 12283.5 12298.5 12301.0 12305.0 12310.5 12315 0 12324 0 12332 0 12337 5 12343 5 12346 0 12350.0 12354.5 12356.5 12369.0 12372.0 12389.5 12394.0 12399.0 12408.0 12414.5 12423.0 12431.5 12454.0 12463.0 12473.5 12502.5 12505.5 12511.0 12525.0 12532.0 11928 .C 11936.5 11941.0 11950.5 11953.0 11964.0 11968.5 11985.0 11990.5 11998.0 12005.0 12008.0 12012.0 12023.5 12030.5 12035.5 12046.0 12065.0 12071.0 12075.0 12083.0 12086.0 12093.0 12101.0 12106.5 12120.0 12130.0 12141.0 12151.5 12154.5 12160.0 12167.5 12170.0 12189.5 12%97.5 12200.5 12206.5 12218.5 12223.5 12234.5 12238.5 12248.0 12275.5 12280.0 12282.5 12287.0 12302.5 12305.0 12309.5 12315.0 12320.5 12329.5 12336.5 12344.0 12348.0 12351.5 12356.5 12360.0 12362.0 12376.0 12381.5 12398 5 12404 0 12409 0 12417 0 12423 0 12429 5 12438 0 12459 5 12468 0 12477 5 12506 0 12509 0 12512 0 12524.0 12529.0 12541 12565 12567 12574 12583 12590 12592 12594 12596 12600 12648 $ .0 .C .0 .5 C ¢ 0 5 O 5 0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 12539.0 12563.5 12566.0 !25r4.0 12582.5 12591.5 12594.0 12597.5 12600.0 12604.5 12652.0 BIT RUN NO MERGE TOP MERGE BASE 1 10917.0 12219.0 2 12219.5 12356.0 4 12356.5 12652.0 MERGED MAIN PASSi $ 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 ~ep Code 'Offset Channel DEPT FT 4 1 6'8 0 1 ROP MWD FT/H 4 i 68 4 2 GR MWD API 4 1 68 8 3 RP~ MWD OHMM 4 i 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 i 68 20 6 ,RPD MWD OHMM 4 i 68 24 7 FET MWD HR 4 I 68 28 8 Name Service Unit Min Max DEPT FT 10916 12648 ROP MWD FT/H 0.26 2119.57 GR MWD API 13.29 180.26 RPX MWD OHMM 0.26 1699.94 RPS MWD OHMM 0.12 1699.91 RPM MWD OHMM 0.12 1785.56 RPD MWD OHMM 0.1 675.51 FET MWD HR 0.33 25.91 First Reading For Entire File .......... 10916 Last Reading For Entire File ........... 12648 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Last Mean Nsam Reading Reading 11782 3465 10916 12648 83.7839 3376 10960.5 12648 32.8781 3374 10916 12602.5 7.30181 3350 1D939 12613.5 7.78593 3350 10939 12613.5 8.21151 3350 10939 12613.5 8.39632 3350 10939 12613.5 1.9608 3350 10939 12613.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10903.0 12602.5 FET 10939.0 12613.0 RPX 10939.0 12613.0 RPS 10939.0 12613.0 RPM 10939.0 12613.0 RPD 10939.0 12613.0 RAT 10946.0 12648.0 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 2 0 10904.0 12187.5 MWD 4 0 12188.0 12652.0 # REMARKS: MERGED MAD PASS. $ Data Fozmat Specification Record Data Record Type .................. 0 Data Specification Block T~e ..... 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 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HR 4 1 68 28 8 N~me Service Unit Min Max Mean Nsam DEPT FT 10903 12648 11775.5 3491 RAT MAD FT/H 352 1984 625.426 3405 GR MAD API 12.68 174.54 36.0458 3400 RPX MAD OHMM 0.1 2000 5.03058 3349 RPS MAD OHMM 0.1 2000 11.0748 3349 RPM MAD OHMM 0.15 2000 12.511 3349 RPD MAD OHMM 0.13 2000 13.2996 3349 FET MAD HR 3.4 54.07 25.6484 3349 First Reading For Entire File .......... 10903 Last Reading For Entire File ........... 12648 First Reading 10903 10946 10903 10939 10939 10939 10939 10939 Last Reading 12648 12648 12602.5 12613 12613 12613 12613 12613 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version N'~nber ........... t.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Next File N~e ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 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: 1 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR RPD RPS RPX ROP LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 10917.0 12173.0 10940.0 12184.0 10940.0 10940,0 10940.0 1.2184.0 10940.0 12184.0 10965.0 12219.0 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: 2 6-MAY-00 Insite 4.05.2 4.251 Memory 12219.0 73.0 98.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01475GR3 EWR4 ELECTROMAG. RESIS. 4 PB01475GR3 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: FLOPRO · MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): .0 MUD PH: 10.5 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .090 MUD AT MAX CIRCULATING TERMPERATURE: .038 MUD FILTRATE AT MT: .120 75.0 185.4 75.0 MUD CAKE AT MT: NEUTRON TOOL H~TRiX: H~TRIX DENSITY: HOLE CORRECTION iIN): 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 .160 Units Size Nsam Rep Code Offset Channel DEPT FT 4 ~1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 I 68 RPX MWD010 OHMM 4 I 68 RPS MWD010 OHMM 4 i 68 RPM M~D010 OHMM 4 I 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HR 4 1 68 0 4 8 12 16 20 24 28 1 2 3 4 5 6' 7 8 75.0 Name Service Unit Min Max DEPT FT 10917 12219 ROP MWD010 FT/H 1.27 2119.57 GR M~D010 API 13.29 180.26 R~X MWD010 OH}fl~ 0.26 2000 RPS MWD010 OHMM 0.12 2000 RPM MWD010 OHMM 0.12 1785.56 RPD MWD010 OHMM 0.1 1523.27 FET MWD010 HR 0.4 9.23 First Reading For Entire File .......... 10917 Last Reading For Entire File ........... 12219 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Mean Nsam 11568 2605 79.7888 2509 34.2701 2513 8.19542 2489 8.02845 2489 7.86888 248.9 7.81562 2489 1.18225 2489 First Reading 10917 10965 10917 10940 10940 10940 10940 10940 .Last Reading 1221.9 12219 12173 12184 12184 12184 12184 12184 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12173.5 12308.0 RPX 12184.5 12319.0 FET 12184.5 12319.0 RPD 12184.5 12319.0 RPS 12184.5 12319.0 RPM 12184.5 12319.0 ROP 12219.5 12356.0 $ LOG HEADER DATA DATE LOGGED: 27-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 4.251 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12356.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 93.0 MAXIMUM ANGLE: 96.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER E~R4 ELECTR(H~G. RESIS. 4 $ # BOREHOLEAND CASING DATA OPL"~ HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: FLOPRO MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): .0 MUD PH: 8.5 MUD CHLORIDES (PPM): 84000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .050 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .021 176.6 MUD FILTRATE AT MT: .070 70.0 MUD CAKE AT MT: .060 70.0 # 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...C Name Service Order Units Size Nsam Rep Co~e Offset Channel DEPT FT 4 i 68 ROP MWD020 FT/H 4 I 68 GR MWD020 API 4 I 68 RPX MWD020 OHMM 4 I 68 RPS MWD020 OHMM 4 I 68 RPM MWD020 OHMM 4 I 68 RPD MWD020 OHMM 4 ! 68 FET MWD020 HR 4 i 68 0 i 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 12173.5 12356 ROP MWD020 FT/H 0.83 297.46 GR MWD020 API 21.24 31.99 RPX MWD020 OHMM 0.59 10.46 RPS MWD020 OHMM 0.71 13.99 RPM MWD020 OHMM 1.13 15.05 RPD MWD020 OHMM 4.24 16.73 FET MWD020 HR 0.74 14.14 Mean 12264.8 85.533 26.4245 5.59578 7.71933 8.93091 10.8445 4.58885 First Reading For Entire File .......... 12173.5 Last Reading For Entire File ........... 12356 File Trailer Service name ............. STSLIB.004 Service Sub Level Name Version Number ........... 1.0.0 Dat,eofGeneration:..~ ..... 02,/,04/16 Max~ PhYsi~i RecOrd. 65555 File Type ................ LO Next File Name. .......... STSLIB.,005 Nsam 366 274 270 270 270 270 270 270 First Reading 12173.5 12219.5 12173.5 12184.5 121~'4.5-~ 12184.5 12184.5 12184.5 Last Reading 12356 12356 12308 12319 12319 12319 12319 12319 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 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 12308.5 12606.5 FET 12319.5 12617.5 RPD 12319.5 12617.5 RPM 12319.5 12617.5 RPS 12319.5 12617.5 RPX 12319.5 12617.5 ROP 12356.5 12652.0 $ LOG HEADER DATA DATE LOGGED: 28-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 4.251 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: Memory 12652.0 87.1 93.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01475GR3 EWR4 ELECTROMAG. RESIS. 4 PB01475GR3 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: FLOPRO MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): .0 MUD PH: 8.5 MUD CHLORIDES (PPM): 84000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .059 MUD AT MAX CIRCULATING TERMPERATURE: .024 MUD FILTRATE AT MT: .075 MUD CAKE AT MT: .073 NEUTRON TOOL MATRIX: ~0~ co~CTION (~N): 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 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 HR 4 1 68 28 8 70.0 185.4 70.0 70.0 Name Service Unit Min Max Mean Nsam DEPT FT 12308.5 12652 12480.3 688 ROP MWD040 FT./H 0.26 423.44 101.135 592 GR MWD040 API 21.27 66.51 29.4595 597 RPX MWD040 OHMM 1.33 26.39 8.59961 597 RPS MWD040 OHMM 2.55 34.42 11.1048 597 RPM MWD040 OHMM 3.39 33.61 12.0894 597 RPD MWD040 OHMM 5.46 26.03 13.5434 597 First Reading 12308 5 12356 5 12308 5 12319 5 12319 5 12319 5 12319 5 Last Reading 12652 12652 12606.5 12617.5 12617.5 12617.5 12617.5 FET MWDO40 HR 0.33 25.91 4.00476 597 First Reading For Entire File .......... 12308.5 Last Reading For Entire File ........... 12652 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 12319.5 12617.5 Physical EOF File Header Service name .... ' ......... STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB. 005 FILE SU~H4ARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS RAT $ # LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 10904.0 12173.5 10940.0 12185.0 10940.0 12185.0 10940.0 12185.0 10940.0 12185.0 10940.0 12185.0 10949.0 12220.0 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 TOOL NUMBER DGR DUAL .GAMMA RAY PB01475GR3 EWR4 ELECTROMAG. RESIS. 4 PB01475GR3 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FLOPRO MUD DENSITY (LB/G): 9.20 27-MAY-00 Insite 4.05.2 4.251 Memory 12356.0 93.0 96.8 3.750 Co~ent Record FILE HEADER FILE NUMBER: 6 RAN MAD Curves and log header data for each pass of each run in separate files. .5000 0 MUD VISCOSITY (S): .0 MUD PH: 8.5 MUD CHLORIDES (PPM): 84000 FLUID LOSS (C3): 6.0 RESiSTiVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .050 ~JD AT FJ~X CIRCULATING TERMPERATURE: .021 MUD FILTRATE AT MT: .070 MUD CAKE AT MT: .060 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 Name Service Order Units Size NsamRep Code Offset Channel DEPT FT 4 I 68 RAT MAD020 FT/H 4 I 68 GR MAD020 API 4 i 68 RPX MAD020 OHMM 4 I 68 RPS MAD020 O~MM 4 1 68 RPM MAD020 O~MM 4 I 68 RPD MAD020 OHMM 4 I 68 FET MAD020 HR 4 i 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 176.6 70.0 70.O Name Service Unit Min Max DEPT FT 10904 12220 RAT MAD020 FT/H 19.42 1080 GR MAD020 API 12.68 174.54 RPX MAD020 OHMM 0.1 2000 RPS MAD020 OHMM 0.1 2000 RPM MAD020 OHMM 0.15 2000 RPD MAD020 OHMM 0.13 2000 FET MAD020 HR 2.29 45.02 First Reading For Entire File .......... 10904 Last Reading For Entire File ........... 12220 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 First Last Mean Nsam Reading Reading 11562 2633 10904 12220 610.104 2543 10949 12220 38.1004 2540 10904 12173.5 5.77348 2491 10940 12185 13.1765 2491 10940 12185 15.8855 2491 10940 12185 15.'1085 2491 10940 12185 26.6336 2491 10940 12185 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of GeneraTion ....... 02/04/i6 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 0 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12142.0 12606.5 RPX 12152.0 12617.0 RPS 12152.0 12617.0 RPM 12152.0 12617.0 RPD 12152.0 12617.0 FET 12152.0 12617.0 RAT 12188.0 12652.0 $ LOG HEADER DATA DATE LOGGED: 28-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: In$ite 4.05.2 DOWNHOLE SOFTWARE VERSION: 4.251 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12652.0 TOP LO~ INTERVa~ (~X): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.1 MAXIMUM ANGLE: 93.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01475GR3 EWR4 ELECTROMAG. RESIS. 4 PB01475GR3 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: FLOPRO MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): .0 MUD PH: 8.5 MUD CHLORIDES (PPM): 84000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .059 7'0.0 MUD AT MAX CIRCULATING TERMPERATURE: .024 185.4 MUD FILTRATE AT MT: .075 70.0 MUD CAKE AT MT: .073 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type .................. C Data Specification Block T~e ..... C Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undef±ned 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 RAT MAD040 FT/H 4 1 68 GR MAD040 API 4 1 68 RPX MAD040 OHMM 4 1 68 RPS MAD040 OHMM 4 1 68 RPM MAD040 OHMM 4 1 68 RPD MAD040 OHMM 4 1 68 FET MAD040 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 12142 12652 RAT MAD040 FT/H 352 1984 GR MAD040 API 14.61 59.17 RPX MAD040 OHMM 0.53 17.1 RPS MAD040 OHMM 0.42 28.83 RPM MAD040 OH~9~ 0.51 32.06 RPD MAD040 OHMM 0.79 24.87 FET MAD040 HR 3.4 54.1 First Reading For Entire File .......... 12142 Last Reading For Entire File ........... 12652 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Mean 12397 670.562 30.036 4.85655 7.4124 9.0159 11.3996 21.9605 First Last Nsam Reading Reading 1021 12142 12652 929 12188 12652 930 12142 12606.5 931 12152 12617 931 12152 12617 931 12152 12617 931 12152 12617 931 12152 12617 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/04/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name. ............ LISTPE Date ..................... 02/04/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File