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Home My WebLink About200-151Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:200-151 6.50-029-20593-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13137 13092 8828 9430 8406 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 37 - 117 37 - 117 Surface 2639 13-3/8" 36 - 2675 36 - 2675 5380 2670 Intermediate 8636 9-5/8" 33 - 8669 33 - 7792 6870 4760 Production 1131 7" 8497 - 9628 7657 - 8571 7240 5410 Perforation Depth: Measured depth: 11950 - 13045 feet True vertical depth:8806 - 8821 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 31 - 9465 31 - 8436 9430 8406Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 3671 4-1/2" 9466 - 13137 8436 - 8833 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 8351986142038 47051008 1759 477 171 209 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brodie Wages david.wages@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5006 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8833 Sundry Number or N/A if C.O. Exempt: 320-519 4-1/2" Tendeka SSSV 2187 2187 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Install/Test New SSSV Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028260 & 028282 PBU M-12A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:42 pm, Jan 22, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.01.22 13:49:37 -09'00' DSR-1/22/21 SFD 1/23/2021RBDMS HEW 1/27/2021MGR05FEB2021 ACTIVITY DATE SUMMARY 12/15/2020 ***WELL S/I ON ARRIVAL*** (sssv maintenance) DRIFT 3.84" CENT, EQ K VLV @ 2187' MD PULL 4-1/2" K VLV @ 2187' MD DRIFT 3.7" CENT TO DEVIATION @ 10,082' SLM SET 4-1/2" XLOCK w/ GAUGES IN SSSV NIP @ 2187' MD CHECK SET XLOCK @ 2187' MD ***WELL S/I ON DEPARTURE, DSO NOTIFIED TO BRING ONLINE*** 12/21/2020 ***WELL FLOWING ON ARRIVAL*** PULLED X-LOCK W/ GAUGES FROM SVLN @ 2,187' MD SET TENDEKA EAV SSSV (ser# P8-19) IN SVLN @ 2,187' MD (confirmed w/ check set) ***WELL FLOWING ON DEPARTURE*** 12/23/2020 T/I/O= 1050/1800/550. Temp= SI. LRS Unit 72 Assist Slickline (PULL SSSV). Freeze protect the F/L with the westside recipe (9 bbls of 60/40 Meoh and 65 bbls of crude). S/L had control of the well upon departure. 12/23/2020 ***WELL S/I ON ARRIVAL*** (sssv maintenance) EQUALIZED & PULLED 4-1/2" TENDEKA SSSV FROM X-NIP @ 2,187' MD. ***JOB COMPLETE, WELL LEFT S/I*** 12/23/2020 T/I/O= 1800/1800/550. Temp= SI. LRS Unit 72 Assist Slickline (PULL SSSV). Freeze protect the TBG with 38 bbls of crude. Final T/I/O= 1200/1800/550. 12/25/2020 ***WELL S/I ON ARRIVAL***(set sssv) SET TENDEKA EAV SSSV (ser# P8-19 IN SVLN @ 2,187' MD (confirmed w/ check set) WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU M-12A Well: M-12a PTD: 200-151 API: 50-029-20593-01 Discussion of SSSV testing: For the first deployment, the tool was set up with one fail-close function to close if it detected a voltage drop of less than 10v. This is a standard fail close parameter. Due to the relatively lower well temperatures of M-12a, the tool drew slightly more current during the last closure of the tool and when it dropped below the 10v threshold it subsequently closed. As a fail-close function, it locks out the valve (closed) and cannot be re- opened from surface. This was not a tool failure but was, in fact, the tool functioning as it was programmed to do and responding to operating conditions. We could class this as a successful demonstration of one of the fail- close functions of the tool. After interrogating the tool at the shop, it was established that this was the reason the valve had closed. The tool was updated with a new threshold of 7v. This lower threshold allows the tool to operate at these slightly lower well temperatures but still provides a working threshold to fail-close in the event that a low voltage drop occurs. After re-deploying the tool, the well was popped under evaluation with a 72-hr flow permission from the AOGCC on 12-26-2021 at 3 am. Later that day, prior to state representatives arriving to witness opening and closing operations of the valve, we performed two successful closures and openings. The well and SSSV were closed at the end of our tests. On 1-9-21 the well was popped again at 0900. State representatives arrived on location 1-10-21 and witnessed the successful function testing of the battery powered SSSV. The new 7v threshold appears to allow the valve to operate as designed. In addition to the 7v threshold, the following parameters have been programmed into the tool: A detailed operating program and flowchart have been posted to the wellhouse to assist operations with functioning the tool and is available upon request. Battery life is expected to last ~892 days from install date (12/21/20) Well: M-12a PTD: 200-151 API: 50-029-20593-01 Tool Schematic: Well: M-12a PTD: 200-151 API: 50-029-20593-01 Wellbore Schematic: MEMORANDUM TO: Jim Regg I`C 117��z'�� P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 12, 2021 FROM: Brian Bixby SUBJECT: SVS Test — Tendeka EAV SSSV Petroleum Inspector PBU M -12A - Hilcorp Alaska Inc. PTD 2001510; Sundry 320-519 1/10/2021: 1 arrived location and discussed with Dave Kindred (Hilcorp Lead Operator) the plan on testing the well. PBU M -12A is equipped with a battery -powered Tendeka Electric Ambient Subsurface Safety Valve (SSSV) as a test to see if this can be used in lieu of K -valves. Previous tests have been inconclusive — refer to test report from AOGCC Inspector Jeff Jones dated 12/22/2020. Mr. Kindred indicated the test will be ✓ the same as they way the SSSV in all their wells are tested. Pre-test pressures: Tubing/Inner Annulus/Outer Annulus= 207/1800/740 psi 1 2 3 4 5 6 7 8 9 Rigged up a calibrated gauge to the low pressure pilot (LPP). Closed the wing valve to build pressure. At 540 psi on the tubing, I directed Dave to bleed the pressure to test the pilot, tripping at 118 psi. [PASS] - The SSV fully closed and I monitored the swab valve pressure gauge to unsurE the wing valve held (PASS). I then directed Dave to open the wing valve and bleed the pressure down to the common line pressure of 200 psi. I then directed Dave to close the wing valve and we monitored the swab valve pressure gauge for any build up — none, indicating the SSV held solid. [PASS] With the wing valve left closed, I directed Dave to open the SSV. There was 640 psi below the SSV, so I directed Dave to open the wing valve again to create a drop in pressure as the battery powered SSSV needs to see 120 -psi pressure drop within 3 minutes to signal it to close. At about 2 minutes, I witnessed the pressure gauge on the swab valve move which I believed to be the SSSV starting to close. At just under 3 minutes, the SSSV was fully closed. I directed Dave to close the wing valve and we monitored the swab valve pressure gauge for build up — none, indicating the SSSV held solid. [PASS] ' I stayed another 40 minutes, which is the time it takes to get the SSSV opened again. There was 1200 psi below the SSSV. Good double check that the SSS\j was holding. 2021-0110 SVS_Tendeka-EAV_PBU_M-12A_bb.docx Page 1 of 1 r MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �(�� l'f z�zcZl DATE: 12/27/2020 P. I. Supervisor FROM: Jeff Jones SUBJECT: Tendeka EAV SSSV Test Petroleum Inspector PBU M -12A Hilcorp North Sipe LLC PTD 2001510; Sundry 320-241 December 22, 2020: 1 traveled to Hilcorp's PBU M -pad to witness a subsurface safety valve test performed on a Tendeka Electric Automatic Valve (EAV), installed in production well M-1 2A. On arrival I met with Hilcorp Lead Operator Dave Kindred and Tendeka representative Paul Lynch and we discussed the test procedure. A large atmospheric bleed tank was set up and connected via 2 -inch hard line to the production tubing. The well was flowing in normal condition: flowing tubing pressure (FTP) = 206 psi, common flow line = 168 psi, inner annulus = 1750 psi, outer annulus = 650 psi, and artificial gas lift = 1.9 MMcfg/d. The wing valve to the 8 -inch common flow line remained open and the surface safety valve (SSV) was bypassed to remain open and the 2 -inch hard line to the bleed tank was fully opened from the tubing to the bleed tank to simulate a leak from the well. - PBU M-1 2A was flowed for 10 minutes in this configuration and the Tendeka EAV SSSV did not close. - At this point the wing valve to the common flow line was closed and FTP increased to 370 psi and at 4 minutes it increased to 438 psi. The 2 -inch hard line to the bleed tank was closed and FTP increased to 465 psi. The wing valve to the common line was opened and after 2 minutes the wing valve was closed, and pressure steadily increased indicating the SSSV had not closed. - The wing valve was opened again and the well allowed to flow for 4 more minutes at which time the FTP decreased to 175 psi. The wing valve to the common flow line was closed; the 2 -inch hard line remained closed and the FTP was monitored for 10 minutes. The FTP increased to 208 psi, stabilized and appeared to hold pressure indicating the SSSV was closed. This SSSV is opened by a pressure increase/wait time step procedure that failed to open the SSSV after several attempts. The EAV SSSV will have to be removed from the well for data download with a wireline unit. Summary: I witnessed a Tendeka EAV SSSV function pressure test at Hilcorp's PBF well M-12. The SSSV did not close in some leak scenarios created but did eventually close in 4 minutes and hold pressure. As with other similar types of remotely actuated SSSV's tested in the past, opening the Tendeka EAV SSSV after closure was problematic, which may reduce production. Attachments: none 2020-1222—SVS—Tendeka-EAV — PBU—M- 12Ajj.docx Page l of 1 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:200-151 6.API Number:50-029-20593-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028260 & 028282 Property Designation (Lease Number):10. 8. PBU M-12A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Install New SSSV Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13137 Effective Depth MD: 13Cr80 11. Commission Representative: 15. Suspended Contact Name: Brodie Wages Contact Email: david.wages@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8833 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9430, 8406 Date: Liner 3671 4-1/2"9466 - 13137 8436 - 8833 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 36 - 2675 36 - 2675 14. Estimated Date for Commencing Operations: BOP Sketch 37 - 117 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 11950 - 13045 8806 - 8821 4-1/2" 12.6#31 - 9465 Production 13092 8827 37 - 117 13-3/8" 9-5/8" Contact Phone:(907)564-5006 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2639 5380 Intermediate 9611 1131 7" 8497 - 9628 7657 - 8571 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 33 - 8669 2307 33 - 7792 4-1/2" K Valve 2187, 2187 12/28/20 By Samantha Carlisle at 11:25 am, Dec 14, 2020 320-519 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.12.14 11:15:29 - 09'00' Stan Golis DLB 12/14/2020 X DSR-12/14/2020 Mel Rixse MGR21JAN21 to Brodie Wages, Hilcorp 12-23-2020 10-404Yeson Required? Comm 1/21/21 dts 1/21/2021 JLC 1/21/2021 RBDMS HEW 1/26/2021 Well: M-12a PTD: 200-151 API:50-029-20593-01 Expected Start Date:12-17-2020 Current Condition of well:Producer, Operable, Offline Latest test information: Est Flow Information Oil Rate 38 bopd Oil Rate 300 BOPD Gas Rate 477 mcf/d Gas Rate 10 MMSCFD Water Rate 1420 bpd Water Rate 1800 BPD Flowing Tbg Press 835 psi Flowing Tbg Press 174 psi Shut-in WH Press 91 psi Shut-in WH Press 91 psi Reservoir Pressure 3167 psi @ 8600’ TVDss Program Objective(s): The purpose of this program is to pull and replace the existing K-valve with a new battery operated SSSV. Proposed Program: 1. Equalize and pull K-valve SSSV from SSSV nipple at 2187’ 2. Install memory gauges in the SSSV nipple 3. Flow well for ~2 days a. Use this period to obtain programming parameters for the new SSSV 4. Install new SSSV (specific valve information below) 5. POP and flow well Tendeka Battery Operated SSSV detail: x Uses built in pressure monitoring system and battery operated motor to autonomously actuate the valve based on safety critical events or a predetermined pulse routine. We will program a set of gates that, as long as the well pressures are flowing withing these gates, the valve will remain open and allow the well to flow: x Based on historical flowing pressure data, the following settings will be uploaded: o A pressure increase of 250 psi at surface over a period of less than 15 minutes will activate the valve to close o A pressure decrease of 120 psi at surface over a period of less than 5 minutes will activate the valve to close o If flowing tubing pressure drops below 100 psi (per 25.265), the valve will close With the K-valve out of the well, the new expected flowing tubing pressure will be the pad header pressure, currently 174 psi o Thesevalues are subject to change based on a pop and flow period to happen right before install Well: M-12a PTD: 200-151 API:50-029-20593-01 x The valve is fail-safe-close based on several mechanisms tied to battery life: o Internal battery life calculator - evaluates thermal degradation of battery life based on actual exposed temperature in addition to measured power usage through function. The valve to be run into M-12a will be set to close at 5 days battery life remaining. o An internal voltage measurement – if battery power drops below 10 volts, the tool moves to a closed position. The tool will still operate below 10 volts but will be slower in closure. o Sensor failure If annulus pressure/temperature sensor below the tool fails, the valve will close If tubing pressure/temperature sensor above the tool fails, the valve will close x The valve is a zero-leak barrier, it has a sliding sleeve type choke piston which provides a gas tight seal. The valve design has been tested to 3500 psi to gas, 5000 psi to liquid and up to 230 degF. As part of FAT & System Integration Testing, the deployed valve was tested to 9,000psi absolute pressure with 5000psi differential across the tubing to annulus seals with liquid, and 1,300psi gas differential test conducted also. x The fail-close mechanisms above are supported by the vitality pulse functionality confirming continued operability: o Sends a daily signal to surface confirming tool operability (uses both sensors, battery power and closure mechanisms) o Changes Time - associated with battery life calculation falling into last 90 days of life. To allow for a scheduled change out before depletion If the set vitality pulse time is at midnight, a change to 1:00 AM would indicate the battery life is low. x The tool is autonomous in that it replaces the existing K-valve system entirely. The tool does communicate to surface by sending a vitality pulse at 24 hour intervals confirming that it is functioning correctly, this can be reviewed on our pressure monitoring system (SCADA) as a pressure response in the production stream at surface. Tendeka will have access to live data. Well: M-12a PTD: 200-151 API:50-029-20593-01 x Previous versions of this system has been run with learnings incorporated into this design including: o Deployment 1 -Pilot test successfully illustrated that the tool could recognise events which would cause the tool to close. o Deployment 2 –Semi Successful installation – TOOL CLOSED – UNABLE TO REOPEN - NO LEAK RECORDED. Unable to open valve after successful loss of well control simulation and inflow test, found that upon topping up the well prior to sending a reopening command a volume of debris (approx. 7ft fill) was deposited on top of the tool preventing it from seeing the reopen command. Attempts to latch the assembly for retrieval were problematic and caused the BHA to be dropped. Tool maintained 100% integrity through weeks in hole 1,500psi differential with gas pressure. Outcome - Tool remained operational despite debris and drop. x procedural change to flow well for longer period prior to first LOWC event simulation. x Procedural change to prevent dirty surface lines from injecting debris in the well. x Larger volume debris catcher option o Deployment 3 –Unsuccessful installation – TOOL CLOSED – UNABLE TO REOPEN - NO LEAK RECORDED Tool suffered a leak into actuator section after closing in response to successful LOSC simulation and inflow test, gas ingress to actuator section via a damaged elastomeric seal (manufacturing error) allowing gas ingress into the tool actuator section. No leak recorded Outcome - Tool was still able to function, but did as intended and remained in closed position due to issue Change of design to replace offending elastomeric seal with MTM seal qualification tested to 3000psi gas differential @ 230F x Testing the closing functionality of the valve: o To test the closing functionality of the valve, the well is shut in and opened in stages: Well: M-12a PTD: 200-151 API:50-029-20593-01 o To open the valve, the well is opened up in stages, the tool recognises the staged pressure increases and closes o To close the valve on purpose, the same staged pressure signal sent to the tool will activate the motor to close the valve. o Per 25.265, h, the valve will be performance tested upon installation and within 6 months of install. 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Tuesday, December 8, 2020 1:16 PM To:Winston, Hugh E (CED) Subject:FW: Cancellation: M-12A (PTD#200-151) 10-403 Request #320-241 Attachments:Apprvd Sundry_320-241_060520.pdf From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Tuesday, December 8, 2020 1:13 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Brodie Wages <David.Wages@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: Cancellation: M‐12A (PTD#200‐151) 10‐403 Request #320‐241 Good Afternoon, We would like to request that Sundry #320‐241 (copy attached) be cancelled. We will not be executing the work covered under by this 10‐403 request. Please let us know if you need additional information. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564‐4915 Cell: (907)351‐2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RBDMS HEW 12/9/2020 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:200-151 6.API Number:50-029-20593-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028260 & 028282 Property Designation (Lease Number):10. 8. PBU M-12A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown SSSV Redesign Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13137 Effective Depth MD: 13Cr80 11. 6/26/2020 Commission Representative: 15. Suspended Contact Name: Stechauner, Bernhard Contact Email: Bernhard.Stechauner@bp.com Authorized Name: Stechauner, Bernhard Authorized Title:GC2 Lead PE Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" K Valve Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8833 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9430 / 8406 2187 / 2187 Date: Liner 3669 4-1/2"9468 - 13137 8438 - 8833 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 36 - 2675 36 - 2675 14. Estimated Date for Commencing Operations: BOP Sketch 37 - 117 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 11950 - 13045 8806 - 8821 4-1/2" 12.6#31 - 9465 Liner 13092 8827 37 - 117 13-3/8" 9-5/8" Contact Phone:+1 907 564 4594 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2639 5380 Intermediate 8636 33 - 8669 33 - 7792 1131 7"8497 - 9628 7657 - 8571 7240 5410 Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:58 am, Jun 04, 2020 320-241 Bernhard Stechauner Digitally signed by Bernhard Stechauner Date: 2020.06.04 10:30:05 -08'00' DLB 6/4/2020 X DSR-6/4/2020 10-404 MGR04MAY20dts 6/5/2020 6/5/2020 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.06.05 10:23:28 -08'00' RBDMS HEW 6/9/2020 10-403 Sundry Application for Well PBU M-12A PTD #200-151 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Expected Start Date: June 26, 2020 Current condition of well: Producer, Operable, Online: Oil Rate:23 BOPD Gas Rate:373 Mscf/Day Water Rate:1020 BWPD Flowing Tubing Pressure:888 psi Shut-in Wellhead Pressure:1psi Reservoir Pressure:3255 psi Program Objective(s): The plan is to add perf job to restore well production to where it was last year. We believe that M-12A is another UZI victim and by stepping further up in the lateral we think that we can get away from the water and re-tap into some gas. Once the add perf is completed, we fully expect this well to be a natural flow producer and at that point we will have to re-set a K/PB-valve to be in compliance with the regulations. Before UZI water hit M-12A it was a ~300 IOR producer and we expect to restore it to those kind of rates with the add perf job. Post coil add perf we cannot flow this well until SL sets a DH gauge in the SSSV nipple and WIC makes well UE to evaluate natural flow potential and determine correct K- valve design. Proposed Program: 1. Add perf per attached perf sheet, set CIBP @ 11,920' MD 2. POP well to evaluate performance for K-valve design. (Send valve specifications to the AOGCC for approval) 3. SBHPS, set pressure/temp gauge in SSSV nip, Coordinate with WOE and WIC to POP well post job 4. Pull P/T gauge and send data to gas lift engineer 5. Set K-valve in SSSV nipple. 6. Once K-valve is installed, POP well and keep FTP above required limit according to GL engineer to avoid tripping K-valve. 10-403 Sundry Application for Well PBU M-12A PTD #200-151 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Wellbore Schematic: 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Wednesday, June 3, 2020 9:41 AM To:Winston, Hugh E (CED) Subject:FW: M-12A (PTD# 200-151) Sundry #319-474 cancellation For RBDMS From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Tuesday, June 2, 2020 4:31 PM To: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: FW: M‐12A (PTD# 200‐151) Sundry #319‐474 cancellation From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday, June 2, 2020 4:19 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: M‐12A (PTD# 200‐151) Sundry #319‐474 cancellation Mel, Please cancel this approved sundry (#319‐474) for M‐12A (PTD #200‐151). If you have any questions, please don’t hesitate to let me know. Thanks! Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 | Office: (907) 564-4091 --------------------------------------------------------------------------------------------------- BP Exploration Alaska | 900 E. Benson Blvd. | Room: 717B | Anchorage, AK --------------------------------------------------------------------------------------------------- THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Samuel Infanti Petroleum Engineer Challenger BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU M -12A Permit to Drill Number: 200-151 Sundry Number: 319-474 Dear Mr. Infanti: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the 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, . Price Chair DATED thisga day of October, 2019. B'BDMS��pCT 2 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other SSSV Redesign 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: 4 Exploratory ❑ Development [a 5. Permit to Drill Number. 200-151 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20593-01-00 ' 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? B. Well Name and Number: �� oa 1 Will planned perforations require a spacing exception? Yes E] No H PBU M -12A 9. Property Designation (LeaNumber): OCTse 10. Field/Pools: IJ1 7 2�� /� ADL 028260 8. 028282 PRUDHOE BAY, PRUDHOE OIL Q ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Jun 13137 8833 13050 8822 None None Casing Length Size MD TVD Burst Collapse Stmctural Conductor 80 20" x 30" 37-117 37-117 Surface 2639 13-3/8" 36-2675 36-2675 5380 2670 Intermediate 8636 9-5/8" 33-8669 33-7792 6870 4760 Liner 1131 7" 8497-9628 7657-8571 17240 15410 Liner 3669 4-1/2" 9468-13137 8438-8833 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11950 - 13045 8806 - 8821 4-1/2" 12.6# 13Cr80 13Cr80 1 31-9465 Packers and SSSV Type: 4-1/2" Baker S-3 Penn Packer Packers and SSSV MD (ft) and TVD (ft): 9430/8406 41/2" K Valve 2187/2187 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: 10/24/2019 15. Well Status after proposed work: Oil 0 - WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Infanti, Samuel be deviated from without prior written approval. Contact Email: samuel.infantitabp.com Authorized Name: Intent Samuel Contact Phone: +19075645676 Authorized Title: Petroleum Engineer Challenger Authorized Signature: / Date: 0 I7/�%A COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(q - q�/ q V I Plug Integrity, ❑ BOP ❑ Mechanical Integrity Test ❑ Clearance ❑ Other: //Test /Location / Post Initial Injection n MIT ired? Yes ❑ No ❑ 'i - gBDWS Spacing Exception 2 2 yp� Required? Yes ❑ No h—Y/ Subsequent Form Required: /Q .. J(/(aj r/ APPROVED BYTHE A Approved by: T COMMISSIONER COMMISSION Date:l U Pa , ORIGINAL 10/ Form 10403 Revised 04/2017 Approved application is valid for 12 months from thetoad of aooroval. Submit Form and Attachments in Duplicate cn,kA inkAlm 17 10-403 Sundry Application for Well PBU M -12A PTD #200-151 Expected Start Date: October 24, 2019 Current condition of well: Producer, Operable, Offline: Oil Rate: 207 BOPD Gas Rate: 8549 Mscf/Da Water Rate: 1337 BWPD Flowin Tubin Pressure: 1727 psi Shut-in Wellhead Pressure: 1820 si Reservoir Pressure: 3255 osi Program Objective(s): The purpose of this program is to pull and inspect the current K -Valve SSSV and determine if there is any damage. If damage is found, we will run a brand-new K -Valve SSSV with the same design. If no damage is found, we will proceed with redesigning the SSSV by setting gauges downhole to monitor the flow (<14 days) and use that information to design a new SSSV. Several well tests need to be obtained throughout the UE period, at different rates, to best understand the well. A similar program was completed in 2016 and the current SSSV was set on 10/30/2016. Proposed Program: Equalize and pull K -Valve SSSV from SSSV nipple at 2187' 2. Inspect K -Valve SSSV - Two Possible Scenarios a. If K -Valve SSSV inspection shows damage to the valve 1. Drift to deviation 2. Replace with same K -valve SSSV design and RIH 3. Program Completed b. If K -Valve SSSV inspections shows no damage, then it is a design issue. 1. Drift to deviation 2. Set gauges with flow through sub in the SSSV nipple at 2187' 3. Flow well for no more than 14 days _ 4. Continue to Steps 3 and 4 (shown below) 3. After allowing the well to flow for no more than 14 days, pull gauges, send results to APE and Johnny/John Kenda to be used to de ign a 4. Install new SSSV design BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 SI, and new SSSV cs !;"oUdrn C 10-403 Sundry Application for Well PBU M -12A PTD 6200-151 Wellbore Schematic: ELEV. ELEV. -13wCSg72a,La0,D•1�.— 2871' Nln6oum tD =3.725" @ 9453' 41/2" HES XN NIPPLE 9 -SIB' CSG, 471, L-80, D= 8.681' 4-1? TBG,12.61,17CR-86, R7%,—F94W5— SAFETY NOTE=weLL REQUIRE 668v PRo)mtTY TO K ARU R—CHROMETtM3*K7"88aLANGLE>TO' M -12A ( GAS LFT L1AFQa7 S ,ST FS*ORATION SLAWARY ND DEV Rff LOG SF84RY-SMMM VLV LATCH ANGLEATTOPFBZF: 99' Q 1195(r D\TE' Nyle: FWu m Rod=Wn CB10(h &Writ data SIZE SF MHNAL OFMSOZ MTE 2-7A3' 6 11950-12100 O O62&M 2-1? 6 12760-12895 O 11fD= 2-1(C 6 12925 13000 O 11A3fD0 bV2" 6 13BM-13045 O 11X43100 SAFETY NOTE=weLL REQUIRE 668v PRo)mtTY TO K ARU R—CHROMETtM3*K7"88aLANGLE>TO' M -12A ( GAS LFT L1AFQa7 S ,ST LD ND DEV TYPE VLV LATCH F73Hr D\TE' 6 3023 2984 1 WA@A DW RK 0 1NOM 5 3787 3736 9 MAGA1 DOBE w 16 12wM0 SD 4 6428 5037 39 ►µ7F11 RK 2212/07100 3 7175 6528 37 MGM EW FB( 0 17/OTAxi 2 8257 7398 39 M GGA CW RK 0 12107/00Ir 1 9383 6280 35 KBC-2 0W BK 0 17x17100 ILNRT0PF70Z D=6313' FALLOUT VW4XAN 6669-B68T 9828 4-/2-FESx NP, D=3.813' ® FLAD L.000ED ON 12107100 4-1?LNFL 1z.6a. LA6, olsz enr. wesa- ,-ta�ar�- BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 L-80 BTGµ PRUOHIE BAY LMT WEU W12A PEFBAT 9961050 APIW 5042&2658301 BP E.Pwvd n(Naw) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS ' 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:K Valve Redesign IZI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-151 3. Address: P.O.Box 196612 Anchorage, Development EI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20593-01-00 7. Property Designation(Lease Number): ADL 0028260 8. Well Name and Number: PBU M-12A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13137 feet Plugs measured feet true vertical 8833 feet Junk measured feet N O V 3 0 2016 Effective Depth: measured 13050 feet Packer measured See Attachment feet fv true vertical 8822 feet Packer true vertical See Attachment feet AOGOC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 37-117 37-117 Surface 2639 13-3/8"72#L-80 36-2675 36-2675 4930 2670 Intermediate 8636 9-5/8"47#L-80 33-8669 33-7792 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11950-12040 feet 12040-12100 feet 12760-12895 feet 12925-13000 feet 13030-13045 feet True vertical depth: 8806-8793 feet feet 8793-8788 feet 8787-8803 feet 8807-8816 feet 8819-8821 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"K Valve 2187 2186.89 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED 14 PR 1 2017 3 ti. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 338 14250 1944 1838 1613 Subsequent to operation: 371 16131 1839 1983 1558 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 121 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-533 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature f— Phone +1 907 564 4424 Date 11/29/16 Form 10-404 Revised 5/2015 VT-1- ✓/ 2 O i /7- RBDMS L v DEC - U C. 2016 Submit Original Only ' ?'$? 7 • 0 Packers and SSV's Attachment PBU M-12A SW Name Type MD TVD Depscription M-12A SSSV 2187 2186.89 4-1/2" K Valve M-12A PACKER 8497.37 7657.42 7" Baker ZXP Top Packer M-12A TBG PACKER 9430.2 8406.19 4-1/2" Baker S-3 Perm Packer M-12A PACKER 9475.56 8443.85 5" Baker ZXP Top Packer • w co s. O0000O �v � cD � o � o p N r- Io N- V CO7 Os .4' M M 0) CO N N m CD 00 Is 00 r- L) N N M CD f� O M M 1 0 r CO M N fss 00 00 00 N- CO Ns CD M 0 M MMMCDMM 00 NsD N CCD CO CD N 000 co M W o 2 ' I I I i I . • Q Q• CNC r- CO 0100 ' - 0101 =C 00 O ca a O o co O J 00 O O (U ch J 00 00 = CU M N 4* J J 4t .H x N CO N C DO N = N (Ni U M 0 N CN = N r O 7 t CAO CO CY) M CD M C 00 CD CD O Nr J N 00 — M 0) W Q C W W .N U U V o c CLZ Z Z r W W W m 03 O D F Z Z D D U co Z J J 1— 1— • • 0 2w - 0 N 'y Z cj X 2Y O4t cca� W Nw 2 N co - coct * E iuQ 4 N �* E L• 2 NO Q 7 Q rpm cn >, c > U ao E (13wNZ u- co U) Q OwO O m -°2 0 w J Q co 5NJYw Q p Y cr �CI O J o N d 2 0 se u Ci X U — fnNWNNU J � J 7 J i J Q w Z * 0Q * a) Wfnd' W CO 0 N rrr N O _a > M m O U TREE= 6"CM/ • SAFIOTE:WELL REQUIRES SSSV PROXIMITY TO WHIHEAD FMC AC7UATC3R= OTIS M-1 2A KUPARUK R.***CHROME TUBING***WELL ANGLE>70* KB.ELEV= 58.85' 10050'. BF.BEV= KOP= 4000' 2187' H4-1/2"FES X NI'D=3.813" Max Angle= 100"@ 11002' I I LL Datum AD= 13137' 2187' _I4-1/2'FES K VALVE w/EC)DEV(09/29/16) Datum ND= 8774'SS 13-3/8"CSG,72#,L-80,D=12.347" H 2671' I-'-A , GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE L 6 3023 2964 1 MNGM DMY RK 0 12/07/00 5 3797 3736 9 MMGM DOME RK 16 12/07/00 Minimum ID =3.726" @ 9463' 4 6426 5937 39 MMGM SO RK 22 12/07/00 4-1/2" HES XN NIPPLE 3 7175 6526 37 A/MGM DMY RK 0 12/07/00 2 8257 7398 39 MMGM DMY RK 0 12/07/00 1 9363 8280 35 KBG-2 DRAY BK 0 12/07/00 $ g-- 8497' —7"X 9-5/8"BAKER ZXP LNRTOP PKR,D=6.313" P LLOUT WINDOW 8669'-8687' I I 9420' H4-1/2"FBS X NP,ID=3.813" 5111 9430' --I4-1/2"X7"BAKER S3 PKR,D=3.875" 9453' --I4-1/2"FES XN NP D=3.725" 9518"CSG,47#,L-80,D=8.681" H 9644' , I r 11 9465' —14-1/2"WLEG,D=3.958" 4-1/7 TBG,12.6#,13C R-80,FOX, — 9465' 9466' H EIA] LOGGED ON 12/07/00 .0152 bpf,D=3.958' 9468' I—4-1/2'X 7"BAKER ZXP LAIR TOP PKR,ID=5.25' •1 PERFORATION SUMMARY 4.� REF LOG: SPERRY-SUN AMBO 111111111 ANGLE AT TOP PERF: 99'@ 11950' 111111/1/1/• 111111♦ 11111111 /I 9628' —7"LN bp26#,L-80 BTGM Note:Refer to Production DB for historical pert data .1.1.1.1.1.1.1.1.. SIZE SPF INTERVAL OPWSQZ DATE 0383 bpf,ID, =6.276' 2-7/8" 6 11950-12100 0 08/28/06 , 2-1/2" 6 12760 12895 0 11/03/00 2-1/2" 6 12925-13000 0 11/03/00 2-1/2" 6 13030-13045 0 11/03/00 , FBTD --I 13092' stilistiI•i, ! N;;`;%. 4-1/2"LAR,12.6#,L-80,.0152 bpf,D=3.958" —I 13137' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/14198 ORIGINAL COMPLETION 09/20/16 ZV/JWD CHANGED NGED SAFETY NOTE WELL: M-12A 10/09/00 SRN PROPOSED COMPLETION 10/03/16 MGS/JMD PULLED GAUGES/SET PB VALVE PERNT No:'1982050 01/18/12 TMWJAA ADDED HRS SAFE!Y NOTE 11/02/16 ZV/J1443 PULLED PB&SET K VALVE(10/30/16) AR No: 50-029-20593-01 02/03/16 GRC7l1H PB VLV UPDATE PER STATE BEGS SEC 1,T11N,R12E,605'WEL&2047'SNL 07/18/16 TBCYJI D RESET XLOCK&PB VALVE 09/20/16 ZV/NAA FULL PB/SET XLOCK w/GAUGES BP Exploration(Alaska) OF Tye • S w �\IyyysA THE STATE Alaska Oil and Gas 71, ofLASIt:A Conservation Commission A }£— 333 West Seventh Avenue GOVERNOR BILL WALKER """"••••- Anchorage, Alaska 99501-3572 Q, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Bergene Production Engineer Challenger PANNE / i '! , BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-12A Permit to Drill Number: 200-151 Sundry Number: 316-533 Dear Mr. Bergene: 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 oerster Chair DATED this 2$ day f October, 2016. RBDMS OCT 2 8 2016 RECEWED STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM./1)N (/ y 1 �� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 ,A j own❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other K-Valve SSSV Design I1• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-151• Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0• 3. 6. API Number: 50-029-20593-01-00 99519-6612 Stratigraphic 0 Service 0 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No D1 PBU M-12A • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028260 " PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 13137 8833 i 13050 8822 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"x 30" 37-117 37-117 Surface 2639 13-3/8"72#L-80 36-2675 36-2675 4930 2670 Intermediate 8636 9-5/8"47#L-80 33-8669 33-7792 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 3"PB Valve 2187, 2186.85 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development El . Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1 Oil I3 ' WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ ❑ SPLUG GSTOR 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Bergene,Matthew be deviated from without prior written approval. Email Matthew.Bergene@bp.com Printed Name Bergene,Matthew Title Production Engineer Challenger • Signature Phone +1 9075644849 Date r 7 Ock .2.6,i 6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No V Spacing Exception Required? Yes 0 NoI Subsequent Form Required: /0— 4-0‘j-- ,-4,.--_--, ` L' .7 i, /// / APPROVED BYTHE Approved by: et7� (�/-'+"_ _ COMMISSIONER COMMISSION Date:/g,.-25_/ V1-L- I 0/24 /IC. O RBDMS Ut,I L8 2016 OR\G1IM , tribfib Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate „....---1 /c›,z o_/'6 • • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: M-12A Well Type: Natural Flow Producer API Number: 50-029-20593-01 Well Activity Conventional 4 Classification: Activity Description: Replace PB SSSV Cost Code/AFE: APBWELIR Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: SSSV Estimated Cost, $K: State whitnessed test required AWGRS Job Scope: SSSV MAINTENANCE Other regulatory after replacing valve. This is a new requirements? design,a 10-403 is required Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Matt Bergene Contact numbers: (907) 564-4849 (307)630-9653 Well Intervention Engineer: Contact numbers: No Data No Data Lead Engineer: Ryan Rupert Contact numbers: (907)564-4238 (907)301-1736 Date Created: October 17,2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 9/24/2016 338 1922. bwpd, 14,250 42,110 56 0 1,613 WC 85.17% Current Status: Not Operable Shut In Inclination>70°at Depth(ft) 10,033' MD Maximum Deviation(Angle and Recent H2S (date,ppm) 1/1/2016 16 ppm ' Depth) 100° 11,002' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 24° 9,783' MD Reservoir pressure(date, 8/13/2010 3,255 psi Minimum ID and Depth 3.725" 9,453' MD psig) Reservoir Temp,F 200°F Shut-in Wellhead Pressure 1,800 psi Known mech.integrity problems(specifics) Last downhole operation(date, 9/29/2016 Pulled gauges and re ran old SSSV design operation) Most recent TD tag(date,depth, 12/24/2014 10,090' MD 30'x 2-7/8'dummy gun toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, M-12A is a naturally flowing producer that was sidetracked to its current location in 2000. Due to AOGCC background information, regulations this well is required to have a SSSV,since it is within 660'of the Kuparuk River. This well has etc: historcially been difficult to POP. In September the PB valve was pulled,gauges run,and multiple well tests obtianed. With this information an optimized SSSV could be designed. The purpose of this program is to pull the current PB valve,and set the K valve. • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Non-optimized PB valve design Specific Intervention or Well Objectives: 1 Pull old PB valve and run a new K valve 2 3 Key risks,critical issues: Mitigation plan: 1 Being out of compliance with the state. Ensure that the 10-403 has been approved prior to performing the work. 2 3 Summary Step# Service Line Activity 1 SL Pull PB valve, set new K valve 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 SL Pull PB valve, set new K valve in SSSV nipple at 2187'. Design sheet is attached for new valve design 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 320 MMSCFD: 10 BWPD: 1500 Expected Production Rates: FTP(psi): 1650 Choke setting: 55 PI(bfpd/psi dp) n/a Post job POP instructions: POP post valve c/o,choke setting appears optimized at 55-57 degrees. Attachments-include in separate excel worksheets • Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • III • • • ,HEE= 6'LIVI I ANAL-EAT)- FIC 'SAFETY NOTE:H2S RLAU1NGS AVLRAU,125 ppm ACTUATOR= OT6 WHEN 001 MI,WELL REQUIRES A SSSV.**`CHROM F X..8 H Hi. 5885' 1V11-1 2A TI IlqNl;""WFI I Are-4 F,70 /"A 10033* BF ELEV= . . . (CP, 4000' lAitx Angle= 100"81 110132' I 11.•3 11 RT 1—14-1I2'1-I X NIP,ID-3 61r Da tu _m MO-- 13137' —----- 218T i—4-iir PS VAI VF PASTA I I FD oalori5 i )muro rvo- 8774'SS 1 13 316'cc,G.7 ,L at),11-17 347' I I 21371' I-- I GAS 1 FT MA NIXRR . STI AO'ND DEV TY FE VLV :LA To-1 FoRT DATE MIL/ 6,3023 2964 1 ABAGM DAN RK 12/076)0 5 3797 3736 9 MAGM'DONE RA, 12/3700 'Minimum ID to 3.725"@ 9453' 4 6476>5937 39 114U SO R', 112/0700 3 i 7175,8526 37 ISCIA CAW FiX 1216700 4-112"HES XN NIPPLE . 2 18257 7398 39 PAIAGM DMY Ric 12/076)0 1 9363 8280 35 K.130-2 CAN BK 12/0700 1149T _1—r X98 BAKER ZXP I „,....,„__......_ I NR TOP RAID a 5 313* r41 our~CM 6659 eAer7 I I 9420' --,4_1/2-Fizs x r•42,io=1013' I E x %Mr I 14 1/7 X P IlA Kilt.r.:3 PKR,0-_3 875' I II 1 9453 14 lit ILS XN NV 11) 19-5/8'CSG,47*,L46,13=8 OM" — 11844* I I 4-1/2'7BG,12 M.13CR-80,R)X. I-I_ 94115' J I 9466* —ELM)LOGGED ON 1210760 I ....._...., .,„ ()152 bpi,ID-3 958" 1 ...e Mr 1—4-i/2*x r-LIAKIli LAP LNR TOP FKR,13=525' 4v RORATION SLMRY EFFAA 4:444 REF LOG SPERRY-SUN WO NOL04,440.4411.4. AE AT TOP F'f3W:. 99"@ 11950' 1vv" A 04,104,vo .. 4/•014 4. /I war b r LW,26#,L-80 BTC-11, Nolo Papier 10 Production 03 for holoncal port data .0383 bpl,D-6 276' SIZE SWNTERVAL CFNSOZ DATE 2-7/8" 6 11950-12100 0 0808/06 \ 444 7 1.17 6 17160 17895 0 1131310) 2-1/? 6 12925-13000 0 11,63/00 2-1/2' 6 13030 13045 0 11,03/00 I I 111, 117Th1 13092. 14 4- 14-1/T 1P 126*,L-80, 0157 bpi,13.3 115,0' 1 i 13137..1 DATE REV BY COMIENTS [ TE WV BY r COMMENTS PRUHOE BAY MT 11/14/98 ORIGINAL COMPLETION 01,'1812 MUM]AWED I-QS SAFE l Y.NOTE I Nat: M-12A 10/09100 SRK PROPOSED COM PLETION 02101 16 GRO1LH F13 VLV 11.11PDNIE PER STATE REOE POINT 1,b..F19132050 03/22/01 CIVILP COffECT12*6 i AR P . 50 029 20593 01 08/2806 GLANPAG AS , S& 1 T11N,R12E,665'wa&204T SRL nwrflin tailor rommrxn • m a 00 0000 m ( co ‘gr 00 C N V Lf) f- LO N- U N 0 0 0 0 0 0 1- co I- d- co ct co O co N m d CO I� 00 00 N N M CO N- f- O CO c LO CO CO ":1- •- r-- N- 00 CO CO H N- co CO CO LO CO N- CO CO CO CO cr CO CO') r- CO o r LO O 00 M (c)f-- CO N CO CO CO O (7co V N CO O) - 0) C.) i i i I I .F.� Q N O) co I (D T � O M ()) O � •z1- C) ' M CO CO V M CO c2 (0 � M C a O CO O LTI co co _ Opp W co = d M N *k J J .N N x CV 4 _ O O N NObo N _ N - N = cNI �O CO CO CO CO M C co M O CO M J N CO '— co O) W CC 1- 0) 0)O • F- W 0co ▪ uLZZ Z W W W m m O J ~ Z Z J D (..) 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Downhole pressure gauges were set to meausre data for new K Valve SSSV. Initial Problem Review SSSV shutting prematurely,will replace PB SSSV with K SSV and lower flowing Pwh shut in from 950 psi to Pwh 650 psi Well rerquires GL to unload but with SSSV in well have to unload into HP,thus complicating unloading process. Have to unload into high Pwh and try to get well going without closing SSSV. This design lowers closing pressure to aid in the unloaidn process by lowering Pwh that closes valve. Remedial Plan-WIRELINE ACTION Install K Valve. DSO: Flow well at WHP greater than 650 psi.Valve set to close when flowing wellhead pressure drops belovt 650 psi. HES Test rack set pressure to be 734 psi at 60 degrees F. Date Work Completed _ Well Status/Results Date by Problem Resolved?_ Y _ N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate(STBL/D) Expected NOB: Avg. WC(%) _ Actual NOB: Lift Gas(MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP(psi)/Steady? -- -- MAINTENANCE ONLY CLP(psi)/Steady? .g. Fix AC,Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen,optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "K"Valve Calculation Sheet M-12A Date: 10/10/16 Test Date 09/20/16 HB Est Gross Fluid Rate 4490 BLPD Flowing Well Head Pressure 849 psi 650 Flowing Well Head Temperature 133 deg F 133 GOR 43752 scf/bbl TGLR 6103 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation and downhole pressure gauge data "K"Valve Setting Depth TVD 2180 ft Tubing Pressure at Depth 1200 psi 1072 Temperature at Depth 151 psi Valve set to close at 650 psi Pwh Flowing Tubing Pressure @455 psi Pwh 1200 psi "K" Valve Test Rack Set Pressure at 60 deg F 734 psi Valve Size&Volume Ratio 4.5" 1.314 NOTE: Well needs to flow at> 650 psi Pwh Valve set to close at 650 psi Pwh • • Tubing Pressure at Valve 1160 BFT(psia) 1174 >1238 <1238 Temperature(deg F) at Valves 151 a 1.674E-05 2.77914E-05 b 1.209118 1.175994 Base Pressure 999.489362 c -1198.697 -1174.60566 Base Temp(TV-60) 91 978.13224 976.2943264 Corrected Pressure 976.294326 psia TCF 0.83131329 /olume Ratio for Valve Size = 1.314 Pb @ 60 = 964.323415 Test Rack Pressure = 734 I Volume Ratios 4 1/2" & 5 1/2" 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, October 14, 2016 4:50 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Well Pad MN;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Daniel, Ryan;Cismoski, Doug A; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Producer M-12A (PTD#2001510) New K-Valve Design All, Producer M-12A(PTD#2001510) has been reclassified as Not Operable until the required 10-403 for new K-Valve design is completed and new K-Valve is installed. This well is currently shut-in and there are no plans to POP prior to setting the new K-Valve. Thanks! Jack Lau SCANNED FEB 2 I 2 0 I?, (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W:907.659.5102 C: 907.943.0296 H:x2376 Fro . K, GWO SUPT Well Integrity Sent: Sat ay, October 01, 2016 6:07 PM To: AK, OPS OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad MN; AK, OPS Prod Controllers; AK, OPS Ops Lead; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Daniel, Ryan; Cis i, Doug A; Bergene, Matthew; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO-Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep;Tis.wallace@alaska.gov' (chris.wallace@alaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UPDATE 10/01/16: UNDER EVALUATION: Producer M-12A(PTO#2001510) SSSV Installed All, Producer M-12A(PTD#2001510)was classified Under Evaluation on 09/18/16. It was produced for 11 of the permissible 14 days without a PB-valve installed, in order to obtain well tests and downhole pressure gauge data for a potential valve redesign.On 09/29/16,Slickline pulled the downhole gauges and set a PB-valve of the same design, so that the well can produce while a redesign is evaluated. 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, October 01, 2016 6:07 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Well Pad MN;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Daniel, Ryan;Cismoski, Doug A; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J Subject: UPDATE 10/01/16: UNDER EVALUATION: Producer M-12A(PTD#2001510) SSSV Installed All, ANNE 1 FEB 1 32817 Producer M-12A(PTD#2001510)was classified Under Evaluation on 09/18/16. It was produced for 11 of the permissible 14 days without a PB-valve installed, in order to obtain well tests and downhole pressure gauge data for a potential valve redesign. On 09/29/16,Slickline pulled the downhole gauges and set a PB-valve of the same design,so that the well can produce while a redesign is evaluated. The initial Under Evaluation period (used as a tracking mechanism to ensure the well was not online for more than 14 days without an SSSV) will soon expire.The well is currently shut in, but should be brought online in approximately 5 days. The Under Evaluation period is extended for an additional 14 days(total of 28 days), in order to maintain visibility and ensure that an AOGCC-witnessed flow test of the PB-valve is performed within 5 days of the well being brought online. Work Completed/Plan Forward: 1. Slickline: Pull PB-valve and set memory gauges in SSSV nipple—Completed 09/15/16 2. Operations: Bring online Under Evaluation to collect data for possible new PB-valve design—Completed 09/28/16 3. Slickline:Set PB-valve with same design pressure—Completed 09/29/16 4. Operations: Bring online 5. Full-Field Compliance Representative:Schedule PB-valve flow test within 5 days of POP If the PB-valve redesign is deemed necessary,a 10-403 will be submitted to the AOGCC. Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator(a)BP.com 1 • Pt3u pt -(7–A Regg, James B (DOA) Zciv cl�r From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Friday, September 16, 2016 6:48 AM gem 9 1I',( I' To: Regg, James B (DOA) Cc: AK, OPS GC2 Wellpad Lead;AK, OPS GC2 Field O&M TL; AK, OPS FF Well Ops Comp Rep Subject: AOGCC Notifcation of M-12A steps to POP Jim, Notification to AOGCC concerning flowing M-12A without SSSV installed is below. Please reference the below note from the M Pad Engineer for specifics concerning M-12A. The Well will flow without the SSSV installed for"testing and maintenance" purposes starting 9-16-16. We understand that the 14 day clock has begun and will monitor and submit SVS test request when the SSSV is re-installed. — Please call with any questions that you may have. Vince Vince PokryfkiS eUn 9 ri 9017 Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony-7187 From: AK, OPS GC2 Wellpad Lead Sent: Thursday, September 15, 2016 3:10 PM To: AK, OPS FF Well Ops Comp Rep Cc: AK, OPS Well Pad MN; AK, OPS GC2 Field O&M TL Subject: FW: M-12A steps to POP Vince, M-12 is getting some wellwork done and will be popped without the SSSV. Slickline is on the well right now and we expect to POP it tonight.The WOE and WIC have been talking, they will make it under eval. See the town engineer's plan below. Regards, Dave Dave Kindred GC2 Wellpad Lead Operator 659-4128 Har#440 Alt/Rick Roberts 1 • From: Bergene, Matthew Sent: Monday, September 12, 2016 4:05 PM To: AK, OPS GC2 Wellpad Lead; AK, GWO SR Slickline WSL; AK, GWO SUPT Well Integrity; AK, GWO SUPT Slickline Cc: Rupert, C. Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Farinez, Javier; AK, OPS GC2 Field O&M TL; AK, OPS Well Pad MN Subject: M-12A steps to POP Hi Everyone, This email is meant to summarize the plan forward for M-12A. In order to maximize production while the GL system is down, M-12A will need to be POPd prior to the outage on 9/22/16. Since we have been having so much trouble with this well lately, we will flow the well without the K valve, obtain well tests at different choke settings, and then evaluate the need for a new design. Below are the following steps to get the well POPd. To kick this whole procedure off, I will write an SOR and send it to the slope tomorrow morning. 1) SL to pull current K valve, drift to deviation, and set memory gauges in the SSSV nipple. a. At this time well integrity will need to make the well UE, with a modified start date to reflect that we have 14 days to let the well flow before the state mandates it needs to be SI 2) Allow the well to stabilize at its historical operating WHP (the choke has historically been set at 53 to 55 (1600 WHP). We will obtain a first well test at this stabilized condition. 3) Several more well tests will be taken, at varying choke settings to allow for increased draw down. We want several tests each at different rates to provide as much information as possible when evaluating a redesign. 4) After collecting our well tests, SL will go back to the well, pull the gauges, and set the OLD design. This will provide us the option to flow the well if possible, while we evaluate a new design. 5) If a new design is needed a 10-403 will be submitted to the state and, once approved, a new K valve will be run to replace the one currently in the ground. Thanks for everyone's help in getting this done, if the well can be online while the GL system is down, every barrel produced will be IOR, since the LP system won't have a marginal for those days. The well routinely produces around 400 bopd. Let me know if you have any questions, Thanks, Matt 2 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N • REPORT OF SUNDRY WELL OPERATIO S 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well �' Re-enter Susp Well 0 Other:PB-Valve 13 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-151 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20593-01-00 7. Property Designation(Lease Number): ADL 0028260 8. Well Name and Number: PBU M-12A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 13137 feet Plugs measured feet true vertical 8833 feet Junk measured feet FEBr 2 ®6 2016 G measured 9430.2 feet Effective Depth: measured 13050 feet Packer true vertical 8822 feet Packer true vertical 8406.19 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 37-117 37-117 0 0 Surface 2639 13-3/8"72#L-80 36-2675 36-2675 4930 2670 Intermediate 8636 9-5/8"47#L-80 33-8669 33-7792 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11950-12040 feet 12040-12100 feet 12760-12895 feet 12925-13000 feet 13030-13045 feet True vertical depth: 8806-8793 feet feet 8793-8788 feet 8787-8803 feet 8807-8816 feet 8819-8821 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 3"PB Valve 2187 2187 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: C Ek, i7 <'4 ;'), 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 696 23248 2772 860 937 Subsequent to operation: 711 24866 3096 1880 643 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-090 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature c Phone +1 907 564 4424 Date 2/25/16 fir /e04 RBDMS L V FEB 2 9 2016 Form 10-404 Revised 5/2015 /"`�/`� Submit Original Only • • a) Q, 000000 Ca N CO �- O - COt� v � v � N ch Lf) N- in r-- C.)V 57 - q C) V- C) 00 N N N Nr CO• • CO f- CO I- CO iss LO CV N Cr) CO I� O N- Cr) CO CO t- Cn CO M N r- CO CO CO • Ii I i I I i I- f-- 00 I- COCOcoMT � C) Cr) Cr) CCOO Nr C7 CO rs- CO N M CO `- N COCO 00))CO Ch Cr) al C.) 2 i Q Q ' r- o0 r N- (O co o) CD N- 13) 1 co CO CO c) c) co co C 2 1- W M 0 0 coo c2 0) Oa. co (0 ( C M N *k J coSJ 4 'Nt.1 X r *k N *k UP VN N O\O675 C V _ C V M ti N O 4 t _ 0)0 CO co Cr) CO M M C 00 J N CO0Cr') O0) W Q c0 0 ' U wW Q p u I Q Z Z Z w W W W m m Z Z OU U) Z J J F- F- • • Packers and SSV's Attachment PBU M-12A SW Name Type MD TVD Depscription M-12A SSSV 2187 2186.89 3" PB Valve M-12A PACKER 8497.37 7657.42 7" Baker ZXP Top Packer M-12A TBG PACKER 9430.2 8406.19 4-1/2" Baker S-3 Perm Packer M-12A PACKER 9475.56 8443.85 5" Baker ZXP Top Packer • • 0 Q > `n LI- O > 2 ‹ m .N as,_ r sZ c co c O II Cr)0 �U`II II <r a c U > 2 a o Q _ Q o c > 2 w __ > Q Q d m -ago N Q 00 (7 > 02 co Ns Q2 a c E1 > 0 , -J 0 �` * * moo L * to E N O v J CO I- , cor * * e- r coA * o o > N CO O _ © > J N2 � Q gQF- � � Z� F-LLI RI � F- cas Q N`O O H � co � � F- co0_ NI- J > N o m p V� F- O m � � - m ib Eo < woo .� co ww ce O o r LL r LL Co Cfl LL. • o © c Ci I]. 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"'CHROME KB.EiEi/= . BF.ELEV= KOP_= 4000' Max Angle= 1-0-e©11002' 1 2187' —141/2'HES X NP,D=3.813" Datirm MD=_ 13137' 218T —141/7 PB VALVE INSTALLED 06134115 Datium TV D= 8774'SS 13 „� 1 GAS LFT MANDRELS/8"CSG,72#,L-80,D=12.34T H 2671' ST 14) TVD DEV TYPE VLV LATCH PORT DATE I 'J 6 3023 2964 1 MMGM CON RK '12/07/00 5 3797 3736 9 M41C�fN DOLE RK 12/07/00 Minimum ID =3.725" @ 9453' 4 6426 5937 39 !MGM SO RK 12/07/00 4-112" HES X N NIPPLE 3 7175 6526 37 MGM DEN RK 12/07/00 2 8257 7398 39 IMNGM DMY RK 12/07/00 1 9363 8280 35 KEG-2 01W BK 12/07/00 Z g---I 849T —T X 9-5/8"BAKER ZXP Lift TOP FKR,D=6.313' MLLOUT WIDOW 8669'-8687' ' ' 9420' H41/2'FMXha?D=3.813' 11 g I 9430' —14-1/2'X r BAKER S-3 FKR,D=3.875" 9453' I--412'HES XN lsP D=3.725" 9-5/8'CSG,47#,L-80,13=8.881" H 9644' , , 9465' H4_117 WLEG,D=3.958 4-1/2'TBG,12.611,13CR.80,FOX, H 9465' I 9466' H E-' LOGGED ON 12/07/00 .0152 bpf,D=3.958' 9468' 1--4-12'x T BAKER ZXP LIR TOP PKR,ID=525" *4 PERFORATION SUMMARY �4�4t REF LOG: SPS ERRYUN MVvI) 44444444 ANGLE AT TOP PERF: 99" . 11950' 44444414444\s 4444444440 4 /I 9628' 1—T 1/12,261,L-80 BTC-M. Note:Refer b Production 06 for historical pert data .4.4...4.4.4A.4. .0383 bpf,D=6276" SIZE SFT MBtVAL OPWSQZ DATE 2-7/8" 6 11950-12100 0 0828/06 2-12' 6 12760-12895 0 11/03/00 _ 2-112" 6 12925-13000 0 11/03/00 2-12' 6 13030-13045 0 11/03/00 • fililliikk ; ;lk .PBTD 13092' . � s 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" —I 13137 DATE REV BY COMA 34TS - DATE REV BY CX)MGEN1S PF&DHOE BAY LNT 11/14/98 OF4G1NAL COMPLETION j 01/18/12 TMWJMD ADDED HIS SAFETY NOTE WELL: 111-12A 10/09/00 SI8( PROPOSE])COMPLETION 02/03/16 GRCIRH PB VLV UPDATE PER STATE FM FERMI No:'1982050 03/22/01 (]-*TLP CORRECTIONS AR No: 50-029-20593-01 08/28/06 GLMFAG ADFERFS SEC 1,T11N,R12E,605 W18 2047'SM._ 0627/10 RJ/PJC TREE CJO 1220/10 MB/JMD ADDED SSSV SAFETY NOTE BP EKploratlon(Alaska) i • • ��7,'s9 THE STATE Alaska Oil and Gas �, -s-- - 0 of j\ LAsKA Conservation Commission t t,--__, _- 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "0.),411011*- Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel J 3 2016, Alaska Wells Integrity and Compliance Team Leader � � g y p < BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-12A Permit to Drill Number: 200-151 Sundry Number: 316-090 Dear Mr. Daniel: 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, Q41 Cathy . Foerster Chair DATED this 23 day of February, 2016. RBDMS t.. FEB 2 5 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPRO ALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate D Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tabing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other PB-Valve Design RI 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-151 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development [JJ- 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20593-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No Q PBU M-12A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028260 ' PRUDHOE BAY,PRUDHOE OIL - r�-7U/i -s z�z3/l1 11. PRESENT WELL CONDITION SUMMARYrr l�'` q Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi):(P ) Plugs(MD): Junk(MD): 13137 ' 8833 . 13050 8822 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 37-117 37-117 Surface 2639 13-3/8"72#L-80 36-2675 36-2675 4930 2670 Intermediate 8636 9-5/8"47#L-80 33-8669 33-7792 6870 4760 Production 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 Packers and SSSV MD(ft)and TVD(ft): See Attachment 3"PB Valve 2187, 2186.85 12.Attachments: Proposal Summary Q Wellbore Schematic B 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development Q ' Service ❑ 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil RI . WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Daniel,Ryan be deviated from without prior written appr al. , Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader i Signature Phone +1 907 564 5430 Date d /v b 7,,,e- COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3\Le - 0 9 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No M Subsequent Form Requirec APPROVED BYTHE Approved by: ..../,60,7 -�� COMMISSIONER COMMISSION Date: Z. ' 2'3-/‘ ORIGINAL RBDMS 1, :- FEB 2 5 2016 tSQ 211 itt, Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • 40 aO O o O O o o v ..n u, C N V In Is LO f— V y 0 0 0 0 0 0 Cn 00 C d N 4 CO V CO 0 co N LL, N N M 0 r CA I�co in co c M N N- CO CO CO CI H 00 CO M LO Cr) M M 0 d' CO CO CO C O) to ) co N C'') 0 `— N CO000) CO NI- 0)) V I I i I I I I < Nco r f CO CO rn CD .— M cococo co C• C 00 0) 1—• apO 00 co co - COpJ p M CO C d M N *k J co J .y N X N 0 C Cl) N ( N - N CJ CO 6 ( N 'ct t CA CO v- CA (N CriO CO CO CO COM C CO CO CO — CO M 0 N CO — CO 0) —J W C 0 Tn0OW U 0 L r Z Z Z E W W W m m OO) ZJZHH • • a) of m ' M r N M to In CO CO • N CO Cf) a) C) OO N O I� CO CO CO CO CO CO CO CO G O N. Imo- a) .0 CO V CO NI- CL O N f- CO O p 0 o CO O v- W O W N- N. O O p O co co co 0 2 UJ 0 p p m Z w w O w I- I- U0 C0 O O 1 ~ 2 L a' O O) O 'Cr J J J Q Q (n W a' a)• O r co O O Q Q Q w a a N N N CO CO _U _U _U J W W U J O r r Z Z Z OJ J J p J CO Q Q Q S p p a W a 00 0 w Z p Z N 2 2 2 o c~ n ccn c¢n n ccnn . I Q a o .c OOOLno a L) v- N cm ,- CI N N N c- r r r r L a ai G � m 0 (I) 2 O CO m cn to m a. v 0 .2 U u. u. tri claw ww 4-) ¢ < aaa C. O t a. a ar I- 0 COCoOOO D 0 0 0 0 0 p D D 0 O O O O O O W J J Z N N N N N Z 1 a Q w m f (o CO M CO 0 W W p W N LL a N N r r z a :9 1-.31 O U p W a W C2 CO CO a- �- r Q a ❑ - Q' a 0 m actpiYw J --1 Q O W W < macocn L u a CO a CL a) E m Z Q Q Q Q Q N N N N N CO w a CO OJ a N a LL 22222 < < m m LL si cCn) CO a m • • I Packers and SSV's Attachment ADL0028260 SW Name Type MD TVD Depscription M-12A SSSV 2187 2186.89 3"PB Valve M-12A PACKER 8497.37 7657.42 7" Baker ZXP Top Packer M-12A TBG PACKER 9430.2 8406.19 4-1/2" Baker S-3 Perm Packer M-12A PACKER 9475.56 8443.85 5" Baker ZXP Top Packer • 06/6/01 Wireline Work Request M-1 2A ADWDistribution MAMMA KWIC S IMES Wireline(4) Well: M-12A AFE: APBMPDWL12 Reading File Date: 11/27/2014 Engineer:_ _ Kenda IOR: 200 FTS: AWGRS Job Scope:SSSV for Reg.Compliance H2S Level: Problem Description Well failed state test, PBSSV failed to close. Suspect valve closilng pressure too low or bad SSSV. Pull and replace PB SSSV with higher closing pressure in order to pass state test Initial Problem Review A Weatherford"PB"SSSV will be installed in this well. Remedial Plan -WIRELINE ACTION Install "PB"SSSV set to close at 1000 psi @ 60 degrees. Note: Valve set to remain open at wellhead pressure of>800 psi _ Valve set to close at wellhead pressure of< 800 psi Pad Operator to produce well at the normal 1500 psi WHP. Date Work Completed _ Well Status/Results Date by Problem Resolved ? Y N Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas(MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? _ (e.g. Fix AC,Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: _ _/ / Follow-up Recommendations: • • "K"Valve Calculation Sheet M-12 Date: 04/15/11 Test Data Test Date 11/21/14 Gross Fluid Rate 2313 BLPD Flowing Well Head Pressure 1515 psi Flowing Well Head Temperature 118 deg F GOR 34957 scf/bbl TGLR 7343 scf/bbl Flowing Pressure Calculations Based on MEASURED DATA- PRESSURE GAUGES "PB"Valve Setting Depth TVD 2187 ft Flowing Tubing Pressure 1878 psi Valve set to close at<800# Pwh Flowing Tubing Pressure @ 1000# Pwh 1438 psi Flowing Tubing Temperature @ 650# Pwh 135 deg. PB"Valve Test Rack Set Pressure at 60 deg F 1000 psi NOTE: Well needs to flow at> 800# Pwh Valve set to close at<800#Pwh • • Tubing Pressure at Valve 1438 ' BPT(psis) 1452 >1238 <1238 Temperature (deg F) at Valve 135 a 0.0000138 0.000022905 b _ 1.17235 1.14505 Base Pressure 1269.32437 c -1472.425 -1452.5695 Base Temp (TV-60) 75 1237.9214 1237.910456 Corrected Pressure 1237.92144 psia TCF 0.85232817 /plume Ratio for Valve Size = 1.314 Pb @ 60 = 1225.64791 Test Rack Pressure = 933 Volume Ratios 4 1/2" & 5 1/2" 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 - MEE= 6"C1W AELLI-EA D= FMC • SAFE.OTE:H2S READINGS AVERAGE 125 ppm ACTUA TOR= OTIS WHEN ON MI. WELL REQUIRES A SSSV..***CHROME KB°.ELEV= 58.85' M -1 2A TUBiNG'''WELL ANGLE>70°@ 10033'. F.ELEV= (OP= 4000' 1i.- x-Aligle= 100@11007 ILIPAL218T 1H4-1/2"FES X NP,ID--=1813' DatumM= 13137' 2187' -14-1/2"PB VALVE NSTALLED 06/30/15 Datum TVD= 8774'SS 13-3/8'CSG,72#,L-80,ID=12,347" — 2671' —41 k GAS LIFT MANDRELS ST AC - ND DEV TYPE VLV LATCH FORT DATE . 11 6 3023 2964 1 P4AGM DMY RK 12/07/00 5 3797 3736 9 MMGM DOSE RK 12/07/00 Minimum ID = 3.725" @ 9453' 4 6426 5937 39 MGM SO RK 12/07/00 3 7175 6526 37 MMGM DMY RK 12/07/00 4-1/2" HES XN NIPPLE 2 8257 7398 39 kliAGM DMY RK 12/07/00 1 9363 828,0 35 KBG-2 DIA' BK 12/07/00 2. X- 8497' —7"X 9-5/8'BAKER ZXP LM TOP FKR,ID=,6313" Iti_LOUT wuxaw 8669'-8687' I 1 9420' -4-1/2"F-ES X NP,ID=3.813" 21I ‘g 9430' —I4-1/2"X 7"BAKER S-3 PKR ID=3.875" I l 9453' —4-1/2"FF_S XN Nip,D-=3.725' 9-5/8"CSG,474,L-80,ID=8.681" — 9644' I k I 9465' —14117 WLEG,ID=3.958" 4-1/2"TBG, 12.64, 13CR-80,FOX, — 9465' 19466' 1—ELMD LOGGED ON 12/07/00 .0152 bpf,ID--3.958' 9468' I—4-1/2'X 7'BAKER ZXP LNR TOP FKR,/ID=5.25" • A PERFORATION SLMkAARY .1‘ ...• /*** REF LOG: SPERRY-SUN MO ....• ..11.\ ANGLE AT TOP PERF: 99°@ 11950' ......• ......4 A 9628' —7'LM,26#,L-80 BTC-M Note:Refer to Production DB for historical pe data .0383 bpf,D=6.276" SIZE I SW INTERVAL OF1sYSCIZ DATE 2-718" 6 11950-12100 0 08/28/06 2-1/2" 6 12760-12895 0 11/03(00 2-1/2" 6 12925- 13000 0 11/03/0D • 2-1/2" 6 13030- 13045 0 11/03/00 • • .0 •.,,,,.... .4,....... FBTD —{ 13097 Alk-iiirit. Nik14‘01' NO' 4-1/2 LM, 12.64,L-80,.0152 bpf,ID=3.958' — 1313T DATE REV BY COMMENTS DATE REV BY CC/AMBITS PRLCHOE BAY UNIT 11/14/98 ORIGINAL COMPLETION 01/18/12 PAWN) ADDED H2S SAFETY NOTE MIL: M-12A 10/09/00 SR( PROPOSED COMPLETION 02/03/16 GRUTLH EB VLV UMATE RR STATE REGS. FERMI No:'1982050 03/22/01 CHITLP CORRECTIONS AR No' 50-029-20593-01 08/28/06 GLANPAG ADFERFS SEC 1,T11N,R12E,605'WH &2047'Slki. 06/27/10 RJ/PJC TREE C/O 12/20/10 M3/3.4) ADDED SSSV SAFETY NOTE BP Exploration(Alaska) 2.:,-...........„........_... ge Project Well History File rer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c:~O0- J -~.t Well History File Identifier Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: b,~ Grayscale items: [] Other, No/Type · [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY; BEVERLY ROBIN VINCENT DATEa ~ S! Scanning Preparation x 30 = + - TOTAL PAGES _ ,.., Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO IF NO IN STAGE 1, PAGE(S) DISCREP~RE FOUND: YESNO III IIIIIIIIIII II III RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is~ Quality Checked 12/10/02Rev3NOTScanned,wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 4140 AU G 2 ?OP Mr. Jim Regg Alaska Oil and Gas Conservation Commission D D _ 333 West 7 Avenue Anchorage, Alaska 99501 -n ,,, I Subject: Corrosion Inhibitor Treatments of GPB M -Pad 144 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator I • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 ---, M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -188 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 11/15/07 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wpll _Inh ~ ~~~~~~ ~~V ~ ~ ~ I nn nocrrir.tinr. ns,. NO. 4498 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Pt. Mac. Milne Pt. o~ n..~_- MPS-37 11594513 OH LDWG EDIT tt (0 06/26/07 6 2 1 J-25A 11767130 MCNL t#. 6p _ 06/18107 1 OWDW-SW 11483588 RST v -S„~ pp(j - ~~ °~- 11117/06 1 1 OWDW-NW 11626127 RST (~~ 10/09/07 1 1 OWDW-SE 11225967 RST G C7U r 04/19/06 1 1 M-12A 11216184 MCNL - ~ '+t 04104107 1 1 P1-09 11773114 RST / L ~j '" 04/24!07 1 1 OWDW-SE 11855823 RST.rJ aL ~ ~ ~ ~ 10/28/07 1 1 , ~~r,~~ env ~"~y ~~ccyvc f~GUCIr ~ 01 JIV1\IIYV MI`IV nGl VRI\It7 V„VrYC liV r'i CA{,.r1 1 V: BP Exploration (Alaska) Inc. F, ~~~ Petrotechnical Data Center LR2-1 ~ ~ _' ~ ~- ~~ ~~'~"~`-~ 900 E. Benson Blvd. Anchorage, Alaska 99508 , Date Delivered: 'Z~fg~ttl' Jir'I? ,~~i9 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: -~' • • . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 0'" \5 \ ~Ð RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) 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 : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 EDE Disk M - 12A M - 12A Coil Flag Coil Flag 27-Au~6 25-Au~6 1) 2) 3) 4) 5) 6) 7) EDE Disk SCANNED ~¡ . í Signed: c j~ / {'^------'-- Date : Print Name: ': ' I, 1,1 í--'. t¡ ( ì-<; r I I ii ~'/ / F ¡ (). ¿'i ,r! 1(,' P (/\ IJ:¡."",· : ~ ~) ~L:Un ;)¿<) - I .<; { fT / . ( " (-/ / \L~ ~~í +- iLl ¡-rÖ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAI..AIRPORT RD SUITE C, ANCHORAGE. AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIl..: .":<))..":'~:·/>':)E:0,'·'.::'i>ê··:.:>3.·J >1 WEBSITE: -.'\F¡//,.; _¡-;;;:::;:.ij,:~~/:.';:"':>J.,:::::\: D' 00 _ PDSAl'( C- 2006\Z _ W ord\Distnbullon \T ransmlttai _ Sheets\ TransmIt _ Ongmal. doc . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVEC OCT 0 5 2006 Alaska Oil & Cons. Comr /¡,.... 1. Operations Perfonned: v Abandon 0 Repair WellD PIUR PerforationsD Stimulate 0 OtherD Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate ŒJ Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ:I ExploratoryD .h 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20593-01-00 7. KB Elevation (ft): 9. Well Name and Number: 58.85 M-12A 8. Property Designation: 10. Field/Pool(s): ADL-028282 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 13137 feet true vertical 8833.0 feet Plugs (measured) None Effective Depth measured 13092 feet Junk (measured) None true vertical 8827.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 94# H-40 33 - 143 33.0 - 143.0 1530 520 SURFACE 2639 13-3/8" 72# L-80 32 - 2671 32.0 - 2671.0 4930 2670 PRODUCTION 9613 9-5/8" 47# L-80 31 - 9644 31.0 - 8585.0 6870 4760 LINER 1131 7" 26# L-80 8497 - 9628 7657.0 - 8571.0 7240 5410 LINER 3672 4-1/2" 12.6# L-80 9465 - 13137 8435.0 - 8833.0 8430 7500 Perforation depth: Measured depth: 11950-12100,12760-12895,12925-13000,13030-13045 ~~, .,¢ ?DíJ·" S~C&\",~~"!ri~.Þ , - True vertical depth: 8806-8788,8787-8803,8807-8816,8819-8821 " TubinR ( size, Rrade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 28 - 9465 Packers & SSSV (type & measured depth): 9-5/8" Baker ZXP LNR TOP PKR @ 8497 7" Baker S-3 Packer @ 9430 7" Baker ZXP LNR TOP Packer @ 9468 4-1/2" HES X Nipple @ 2187 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft 0 CT 0 9 2001ì Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubing Pressure Prior to well operation: 588 13,280 2236 --- 1081 Subsequent to operation: 874 12,877 2419 --- 1202 14. Attachments: 15. Well Class after proposed work: Exploratory(] DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ~ Oil!]] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 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 N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature h~- . L2r? j¿ 11. ~ Phone 564-5174 Date 10/4/06 " .~...II\I Form 10-404 Revised 4/2004 C R \ b \\\1 A L . . M-12A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/02/2006 TestEvent --- BOPD: 1,066 BWPD: 2,442 MCFPD: 13,958 AL Rate: 08/28/2006 CTU #5. Adperf. POOH pumping CT displacement with 50/50 MeOH. At surface all shots fired. RDMO CTU. Notified Pad Operator and PCC well ready to pop. T/I/O = 72/1660/180. *** Job Complete *** 08/27/2006 CTU #5. Adperf. Confirmed good data (+9' correction correlated to SWS MCNL dated 04/07/2006). RIH with gun #3, 2.875" x 30' PJOmega 2906 HMX 6 SPF. Correct to top shot at flag. Perforate from 12010' - 12040' corrected depth. POOH. RIH with gun #4, 2.875" x PJOmega 2906 HMX 6 SPF. Correct to top shot at flag. Perforate from 11980' - 12010'. POOH. RIH with gun #5, 2.875" x PJOmega 2906 HMX 6 SPF. Correct to top shot at flag. Perforate from 11950' - 11980'. POOH pumping 50/50 MeOH down backside for CT displacement. 08/26/2006 CTU #5. Adperfs. RIH with gun #1, 2.875" x 30' PJOmega 2906 HMX 6 SPF. Correct depth to top shot at flag. Perforate from 12070' - 12100' corrected depth. RIH with gun #2,2.875" x 30' PJOmega 2906 HMX 6 SPF. Correct depth to top shot at flag. Perforate from 12040' - 12070' corrected depth. POOH. RIH with Weatherford 2.875" MHA and 2.375" PDS memory tools. Log from 12400' to 11200' @ 40 fpm. POOH. 08/25/2006 CTU #5. Add Perf. RU CTU. Perform weekly BOP test. MU BHA #1 PDS GR/CCL in carrier..RIH. Tag 13041' ctm. Log up hole @ 40fpm to 11000' with flag @ 12000'. POOH. Confirm good data (+12' correction correlated to SWS MCNL dated 04/07/2006). Corrected tag depth @ 13056'. RIH with gun #1,2.875" x 30' PJOmega 2906 HMX 6 SPF. 08/24/2006 CTU #5. Add Perf. MIRU CTU. 08/16/2006 *** WELL FLOWING ON ARRIVAL *** (d&t pre-ctu adperfs) DRIFT W/ 3.60" CENT. & SAMPLE BAILER TO 10,061' SLM STOPPED DUE TO DEV. ( NO SAMPLE) ***LEFT WELL SHUT IN*** 04/10/2006 T/I/O=890/1760/330, Temp=Hot. WHP's & IA FL. (For FB). IA FL @ 6426' sta#4 S/O (344 bbl). TBG is fluid to surface. FO said the well tripped and SI for 2 hours and was just POP'ed. FLUIDS PUMPED BBLS 375 50/50 Methanol Water 185 1 % KCL Water 60 1 % KCL with 0.6% Safe Lube 620 TOTAL Page 1 TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP = 4000' Max Angle = 100 @ 11002' Datum MD = 13137' Datum TVD = 8774' SS 6"CNV FMC OTIS 58.85' 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 3.725" @ 9453' 4-1/2" HES XN NIPPLE 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 4-1/2" TBG, 12,6#. 13-CR-BO. FOX, .0152 bpf, 10 = 3.958" 9644' 9465' ÆRFORA TION SUMMARY REF LOG: SPERRY -SUN MWD ANGLEATTOPÆRF: 99 @ 11950' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL OPNISQZ DA TE 2-7/8" 6 11950-12100 0 08/28/06 2-1/2" 6 12760 - 12895 0 11/03/00 2-1/2" 6 12925 - 13000 0 11/03/00 2-1/2" 6 13030 - 13045 0 11/03/00 M-12A 5 NOTE: ***CHROME TUBING*** 2187' -14-1/2" HES X NIP, 10 = 3.813" I ST MD TVD 6 3023 2964 5 3797 3736 4 6426 5937 3 7175 6526 2 8257 7398 1 9363 8280 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 1 MMGM DV RK 9 MMGM DOME RK 39 MMGM SO RK 37 MMGM DV RK 39 MMGM DV RK 35 KBG-2 DV BK PORT DATE 12/07/00 12/07/00 12/07/00 12/07/00 12/07/00 12/07/00 8497' 7" X 9-5/8" BAKER ZXP LNR TOP A<R, 10 = 6.313" MILLOUT WINDOW 8669' - 8687' 9420' 9430' 9453' I PBTD I 13092' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3,958" 13137' DATE 11114/98 10109100 03/22/01 08/28/06 REV BY SRK CI-VTLP GUWPA COMMENTS ORIGINAL COM PLETION PROPOSED COMPLETION CORRECTIONS ADÆRFS DATE REV BY COMMENTS -14-1/2" HES X NIP, 10 = 3.813" I -14-1/2" X 7" BAKER S-3 A<R, 10 = 3.875" -1 4-1/2" HES XN NIP, 10 = 3.725" I -1 4-1/2" WLEG. 10 = 3.958" I HELMD/WLEG -LOGGED 12/07/00 4-1/2" X 7" BAKER ZXP LNR TOP A<R, 10 = 5.25" 9628' 7" LNR, 26#, L-80 BTC-M, .0383 bpf, 10 = 6,276" PRUDHOE SA Y UNIT WELL: M-12A ÆRMIT No: '1982050 API No: 50-029-20593-01 SEC 1, T11 N, R12E, 605' WEL & 2047' SNL BP Exploration (Alaska) MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill 2001510 MD 13137 ~ 'i'VD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. PRUDHOE BAY UNIT M-12A Operator BP EXPLORATION (ALASKA) INC 8833 ~ Completion Dat 11/5/2000 -~ Completion Statu 1-OIL Current Status l-OIL APl No. 50-029-20593-O1-00 UIC N __.. REQUIRED INFORMATION Mud Log N.__~o Sample No Directional Survey No .... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fj33t ..... (data taken from Logs Portion of Master Well Data Maint Log Log Run Name Scale Media No Interval OH I Start Stop CH Dataset Received Numb~e~Comments 3/9/2001 09947 9305-~-~;' 9305 9852 Open ED D Ver LIS Verification ED C Ne NeutronZ-,'''/ Lo Pro Productio~,~~-' R ~ ED C Ne Neutro¢~_....~. ED C. Ne NeutmflC'''~- Lo Ne Neutr..~..~ ED C GR Gamma ~ MWD Survey Report MWD Survey Report 9947~....-~- 1 1 2 BS 1 FINAL FINAL FINAL 1 1 25 Blu 1 1 8662 13087 Open 9396 13062 Case 12286 13060 Case 9305 9852 oh 9606 13054 Case 9606 13054 Case 9606 13054 Case 8669 13137 Case 3/13/2002 10730j~'' 1/11/2002 10557{,,-,'/' 6/4/2002 1/9/2001 Survey Report Digital Da~ 1/9/2001 Survey Report Paper Copy 3/9/2001 9947/,'/'9305-9852 Digi~l Da~ 7/12/2002 10957(,// 7/12/2002 10957..~~ 7/12/2002 7/2/2002 11222e'~ Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y '~ Chips Re ceived ~---~Y"f'~l"- Analysis ~ R ~.c~.iv~.rl? Daily History Received? ~ N Formation Tops ~Y~N Comments: Permit to Drill 2001510 MD 13137 TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. PRUDHOE BAY UNIT M-12A Operator BP EXPLORATION (ALASKA) INC 8833 Completion Dat 11/5/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20593-0t-00 UIC N Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 27, 2002 MWD Formation Evaluation Logs' M-12A, AK-MM-00219 M-12A: Digital Log Images 50-029-20593-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A coPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED 2-2002 AlaldmDil &Ga~Con$.Commille~n 07/09/02 Scblumbe~ Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2198 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Usa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Pmdhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD B-23A I o} '7- 0 ~)~J ~;~7 RST-SIGMA 0412gl02 I ! 1 M-12A _---~..OO-I.5! ~,~:,-';; MCNL 04125/02 1 1 M-17A g;:~O0"O,.~ ~05 SCMT 06/08102 2 D-~ra ,'-~,~-,/O~ ~72 USIT 06107/02 2 BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED ~UL 1° 200~ ~JaskaOil & Gas Cons. Comded~ Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A~N: Sherrie Received b~~'~_ ~ 05/30/02 Scklumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2110 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 1-32 I °~'~o "~'¢~ "J ~)00 RST-SIGMA 04~09~02 1 1 1 D.S. 16-12A J c/qoOIq PSP PROD PROFILE/DEFT 04/29/02 I 1 M-12A c~l~)"J ~ ! PROD PROFILE 0,4/25/02 1 I A-07 J ""~.'~.. ~)~rI PROD PROFILE 04129/02 I ! A-07 -~ PROD PROFILE 0412a/02 1 1 O.S. 9-07A J ~ ¢~--O~,~ PROD PROFILE/DEFT 05~03~02 1 1 R-08 I ~1-"i3~. ~;,' PROD PROFILF_/GLS 04~06~02 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnlcal Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Dote Delivered: RECEIVED .!! IN n ,!,.. -- - - v - Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AT[N: Sherrie WELL LOG TRANSMITTAL To: State of Alaska March 12, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7t~ Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs M- 12A, AK-MM-00219 1 LDWG formatted Disc with verification listing. API#: 50-029-20593-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY O1~ THE TRANSMITTAL LETTER TO THE ATTENTION O1~: Sperry-Sun Drilling Services Attn: ~rtm Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED t AR 1,5 200 01 / 10/02 Scklumberl Alaska Data & Consulting Sewices - 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-571 ! ATTN: Sherde NO. 1711 Company: State of Alaska Alaska OII & Gas Cons Camm Altn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Pdnts CD L1-09 /~5 - 00 1 LI;;AK DETECTION LOG 12/05/01 1 I W-37 ' I'~;;~- (~t./ t ;a,K DETECTION LOG 12/25101 ! 1 D.S. 1-06A I-C~5.-f..~(~ PRODUCTION PROFILE 12/22/01 i 1 D.S. 3-20A ~ C,] .'~ "O~"~ PROD PROFILE W/DEFT 12/11101 ! 1 D.S. 18-34 J ('~?~'~'~ "1 (P q I I=AK DETECTION LOG 07107101 I 1 o.s. 2-13A l cfq _ I/~5 2200? SCaT 12m/0~ 2 E-~SB~ Icf~f-Oq~- e932S ~sT-eOnAX 08~8/0~ ; ~ ~ H~4 } ~1~ ~ 21525 RST~IGMA 1~7101 I 1 1 J42 (nEOO) /~1~ =~e nST;m~A oe/os/01 ; ; 1 M-lan ~'~-I ~ i 20S17 MCNL 1=1S/00 ; 1 ; H.22AU --... 2~S26 nST~muA 1=08/01 ; 1 ; O.S. ~S46A ~O~ ~( ~ ~ 21S06 =CNC ~lne/o~ t 1 t 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 11 2OO2. Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A1TN: Sherrie H ,--LL LOG TRANSMITTAL II. P~oAct.tv~ Diagnostic S~vices, llnc. To' State of Alaska A~ Lori Taylor 3001 Porcupine SL Anchorage, Alaska 99501 RE' Distribution- Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmitzal letter to the attention of' Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT' WELL DA~ TYPE OR SEPIA PRINT(S) OR CI~ROM FILM BLUELINE Open Hole I I 1 , Res. Eval. CH I I I , , M-12a 12~)7~)0 Mech. CH 1 Caliper Survey I Rpt or I BL Signed' Print Name: D.te' 5- q- 01 ProActive Diagnostic Services, Phone:(907) 245-8951 Fax:(907) 245-8952 ( Inc., 310 K Street Suite 200, Anchorage, AK 99501 E-maih pdsanchorage~memorylog.com Website: www.memo~lo~.com (. ... ., ALAS ~IL AND GAS CONSERVATION COM ,.,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED Alaska 0il & Gas Cons. Commission Anchorage 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-151 3. Address t,QCA'I3ONS. 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ¥~ 50- 029-20593-01 .................. ?,~,~,~,~,~,~,~,~,~u~ 9. Unit or Lease Name 4. Location of well at surface ~..:.-c.,.:: .... -:,.~. . 2047' SNL, 605' WEL, SEC. 01, T11N, R12E, UM ; ' ' ' ; ~ ~ Prudhoe Bay Unit At top of productive interval i ;~ ~:~:'--.,,. ! --.. 642' SNL, 2681' WEL, SEC. 06, T11 N, R13E, UM '-/_L,'..,>._.-.'.O_/2._ 1 ~ ,.;'. ....... 10. Well Number At total depth ~ :-.::., ~-..: .: 1340' SNL, 4890' WEL, SEC. 05, T11N, R13E, UM i .... ~ i M-12A ~ ........... ,.., :'.::'::7: .' 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 58.85' ADL 028282 12. Date Spudded 113. DateT..D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. Nc. of Completions 10/18/2000 10/30/2000 11/5/2000 N/A MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 1 19. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 13137 8833 FT[ 13050 8822 FTI [] Yes [] NoI (Nipple) 2187' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PUl i ~o 20" x 30" Insulated Conductor Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2671' 17-1/2" 3720 cuft Permafrost II 9-5/8" 47# L-80 Surface 8670' 12-1/4" 1362 cuft Cla_~s 'G', 130 cuft PF 'C' 7" 26# L-80 8497' 9628' 8-1/2" 260 cu ft Class 'G' 4-1/2" 12.6# L-80 9468' 9465' 6-1/8" 585 cu ft Class 'G' 24. Perforations pp. en to. P.roducti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~mervak s~ze an(] numoer) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9465' 9430' MD TVD MD TVD 12760' - 12895' 8787' - 8803' 12925' - 13000'. 8807' - 8816' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 13030' - 13045' 8819' - 8821' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel 27. PR~)DUCTION TEST ' Date First Production Method of Operation (Flowing, gas lift, etc.) December 18, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO " 12/26/2000 4 TEST PERIOD 7257 4352 447 94.77I 600 :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. RECEIVED JAN ?., $ ZOO1 Alaska Oil & Gas Cons. Commission Anchoraoe Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests , Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Sag River '9684' 8616' Shublik 9750' 8657' Sadlerochit 9918' 8748' Zone 4A (Inverted) 10330' 8827' Sadlerochit 11265' RECEIVFD Sadlerochit (Revert #2) 11284' 8747' JAN 2, 6; 2001 Sadlerochit (Invert #2) 11840' 8818' Alaska Oil & Gas Cons. Commission Sadlerochit (Revert #3) 12562' 8762' Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,'~~,__,~~_~._ Title TechnicalAssistant Date M-12A 200-151 Prepared By Name/Numbec 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 cementir~g and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECEIVED Form 10-407 Rev. 07-01-80 JAN Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION JAN ?~ 6 ;~0Pn~geu. 1 of 7 Operations Summa Report Alaska Oil & Gas Cons, Commission Legal Well Name: M-12 Anchorage Common Well Name: M-12 Spud Date: 10/13/2000 Event Name: REENTER+COMPLETE Start: 10/13/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 7ES Rig Number: · . : Sub Date From-To Hours Task Code Phase Description of Operations · 10113/2000 00:00 - 03:00 3.00 MOB PRE Rig down off DS 2-10 B. Hold PJSM with Peak. Mobilize rig to drill site M. 03:00 - 16:00 13.00. MOB PRE Move rig from DS 2 to DS M. 16:00 - 17:00 1.00 RIGU PRE Spot rig on herculite. 17:00 - 20:30 3.50 RIGU PRE PJSM. Raise derrick. Rig up floor. Install cattle chute, bridle down and )in block. 20:30 - 23:30 3.00 RIGU :~RE Move in and spot shop, camp and mud pits. Berm rig and connect lines and wiring. 23:30 - 00:00 0.50 WHSUR INT1 Accept rig at 2330 hrs. and install secondary valve on annulus. 10/14/2000 00:00 - 01:30 1.50 WHSUR INT1 Install secondary valve on annulus. Take on 600 bbls. of seawater and check tanks. 01:30 - 02:00 0.50 WHSUR INT1 Held prespud meeting & PJSM re nipple down tree. 02:00 - 03:30 1.50 WHSUR INT1 Rigged up DSM lubricator and pulled BPV. Set TWC and tested to 1000 psi. 03:30 - 07:00 3.50 BOPSUI~ INT1 Removed tree and nippled up BOPE. 07:00 - 14:00 7.00 BOPSUI~ INT1 Tested BOPE, pipe rams, blind rams, annular preventer, choke manifold valves, safety valve, dart valve, top drive valves and kelly hose to 250 psi LOI3500 psi HI pressure per BP Amoco and AOGCC requirements and regulations. Witness of test waived by John Spaulding, ^OGCC agent. 14:00 - 15:30 1.50 BOPSUI~ INT1 Pulled BOP test joint. Pulled tubing hanger and 1 joint tubing. Pulled TWC from tubing hanger. Installed wear bushing. 15:30 - 16:30 1.00 STWHIP INT1 Rig up SWS electric line unit to cut 7" tubing. Hold PJSM with rig crew and SWS personned. 16:30 - 19:00 2.50 STWHIP INT1 RIH with string shot. Ran CCL log across crossover at 8923 ft. and detonated string shot in interval 8904 - 8888 ft. to remove possible tubing scale. POOH. 19:00 - 22:00 3.00 STWHIP INT1 RIH with chemical tubing cutter. Tagged tubing crossover at 8923 ft. and fired cutter in 7" tubing at 8900 ft. POOH. Cutter fired OK. 22:00 - 23:00 1.00 STWHIP INT1 Rigged down SWS. 23:00 - 00:00 1.00 STWHIP INT1 Make up spear fishing BH^ w/oil, bumper and accelerator jars and 9 X 6 112" DC. 10/15/2000 00:00 - 01:30 1.50 STWHIP INT1 Finished making up spear BH^ and picking up 6 112" drill collars. 01:30 - 03:30 2.00 STWHIP INT1 Picked up 4" drill pipe. RIH with spear to 2346 ft. 03:30 - 04:30 1.00 STWHIP INT1 Circulated 160 bbls. of freeze protect diesel from wellbore to cuttings tank thence to vacuum truck. 04:30 - 06:00 1.50 STWHIP INT1 Picked up 4" drill pipe while running spear to top of fish at 4745 ft. 06:00 - 07:00 1.00 STWHIP INT1 Took operating parameters and worked spear into top of fish. Worked fish to maximum net pull at cut of 150 K lbs. Jarred on fish to maximum overpull of 125K. Worked cut free after 45 minutes. 07:00 - 08:30 1.50 STWHIP INT1 CBU with seawater. 08:30 - 11:00 2.50 STWHIP INT1 POOH with fish at modest pace with fish dragging intermittently. 11:00 - 11:30 0.50 STWHIP INT1 Stood back drill collars and laid down jars, etc. 11:30 - 12:00 0.50 STWHIP INT1 Rigged up tubing handling tools. 12:00 - 15:00 3.00 STWHIP INT1 POOH laying down 7" tubing. Recovered 4181 ft. End of tubing indicated approx. 2" on circumference not cut. 15:00 - 15:30 0.50 STWHIP INT1 Rigged down tubing handling tools and cleared floor. 15:30 - 16:00 0.50 STWHIP INT1 Broke down spear and laid out fishing tools. 16:00 - 18:00 2.00 STWHIP INT1 Made up cleanout mill BHA and picked 19 joints 5" HWDP. 18:00 - 19:30 1.50 STWHIP INT1 RIH to 5349 ft. running 4" DP out of derrick. 19:30 - 20:00 0.50 STWHIP INT1 Service rig. 20:00 - 21:30 1.50 STWHIP INT1 Picked up 4" drill pipe running mill to 7169 ft. 21:30 - 22:30 1.00 STWHIP INT1 Mill sat down at 7169 ft. and stuck. Pulled free and repaired elevator Pdnted: 11/28/2000 8:48:57 AM RECEIVED BP EXPLORATION JAN ~, 6 Z00~age 2 of 7 Operations Summary Report Alaska Oil & Gas Cons. Commission Anchorage Legal Well Name: M-12 I Common Well Name: M-12 Spud Date: 10/13/2000 Event Name: REENTER+COMPLETE Start: 10/13/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 7ES Rig Number: ...... Sub Date From-To Hours Task Code Phase Description of Operations 10115~2000 21:30 - 22:30 1.00 STWHIP INT1 bail cylinder. Washed and reamed with no evidence of junk. 22:30 - 00:00 1.50 STWHIP INT1 Finished picking up 4" drill pipe to 8806 f. 10/16/2000 00:00 - 01:30 1.50 STWHIP INT1 Pump hi vis sweep surface to surface followed by dry job. 01:30 - 05:00 3.50 STWHIP INT1 POOH with drill pipe and SLM to 867 ft. 05:00 - 06:00 1.00 STWHIP INT1 Slip and cut drill line. 06:00 - 07:30 1.50 STWHIP INT1 Handle BHA, lay down jars and break out mill. Clear floor of tools. 07:30 - 08:30 1.00 STWHIP INT1 Rig us SWS and hold PJSM re wireline operations. 08:30 - 10:00 1.50 STWHIP INT1 Run wireline junk basket with 8.52" gauge ring to 8850 ft. Run GR correlation log 8850-8600 ft. Recovered pieces of rubber in junk basket. 10:00 - 13:00 3.00 STVVHIP INT1 Ran and set HES bridge plug two feet above casing collar nearest to 8710 ft. with top at 8699 ft. electric log depth. POOH and rigged down SWS. 13:00 - 14:00 1.00 STWHIP INT1 Tested 9 5/8" casing to 3500 psi for 30 mins. OK. 14:00 - 17:00 3.00 STWHIP INT1 Made up whipstock BHA #3. Orient and load MWD. 17:00 - 21:30 4.50 STWHIP INT1 RIH with Whipstock BHA at modest pace. 21:30 - 22:30 1.00 STWHIP INT1 Oriented whipstock tool face to 59 degrees right. Set whipstock bottom trip anchor on HES bridge plug at 8694 ft. drill pipe measure depth. WINDOW INTERVAL WILL BE 8670 FT. TO 8688 FT. drill pipe depth. 22:30 - 00:00 1.50 STWHIP INT1 Circulate well to 11.2 #/gal LSND mud. 10117/2000 00:00 - 11:00 11.00 STWHIP INT1 Milled 8 1/2" window in 9 5~8" casing off face of whipstock from 8669 ft. to 8688 ft. with starter mill TD at 8700 ft. 11:00 - 12:30 1.50 STWHIP INT1 Circulate well with Lo-Vis sweep and ream casing window with mills. Pump dry job. 12:30 - 15:00 2.50 STWHIP INT1 POOH to top of BHA. 15:00 - 16:00 1.00 STWHIP INT1 Stand back HWDP and lay down mills and jars. 16:00 - 17:00 1.00 STWHIP INT1 Clear floor and load out tools. Flush metal cuttings from BOP stack. 17:00 - 20:00 3.00 STWHIP INT1 Make up directional drilling BHA wi1.15 degree motor. Load and calibrate MWD tools. 20:00 - 21:00 1.00 STWHIP INT1 Pick up 9 stands drill pipe and stand in derrick. 21:00 - 22:00 1.00 STWHIP INT1 RIH to 6300 ft. Check MWD tools. 22:00 - 22:30 0.50 STWHIP INT1 Service top drive. 22:30 - 23:30 1.00 STWHIP INT1 RIH with directional BHA to 8669 ft. Tag top of window with bit. 23:30 - 00:00 0.50 s'rWHIP INT1 ~ Orient tool face and work bit thru window. 10/1812000 00:00 - 01:30 1.50 STWHIP INT1'~ Reamed in window and reamed mill rathole. Drilled to 8720 ft. 01:30 - 02:00 0.50 STWHIP INT1 Performed FIT test to 577 psi (12.58 ppg) EMW. OK. 02:00 - 00:00 22.00 STWHIP INT1 Directionally drilled from 8720 ft. to 9294 ft. AST - 7 1/2 hrs; ART - 10 1/4 hrs. 10/19/2000 00:00 - 13:30 13.50 STWHIP INT1 Directionally drilled to 9628 ft. Geologist picked TD 14 ft. high to well plan. AST- 1 hr; ART- 9 1/4 hrs. 13:30 - 15:30 2.00 STWHIP INT1 Circulated bottoms up for samples. 15:30 - 16:30 1.00 STWHIP INT1 Made short wiper trip into casing at 8660 ft. No excessive drags. Monitored well. RIH to 9628 ft. TD to complete wiper trip. No fill. 16:30 - 19:00 2.50 STWHIP INT1 Circulated and conditioned mud. Pumped hi vis sweep and spotted 80 bbl. liner running pill in interval 9628-8660 ft. 19:00 - 20:00 1.00 STWHIP INT1 Dropped ESS survey tool, took check survey at 9435 ft. and POOH to window. Pumped dry job at 8660 ft. 20:00 - 22:00 2.00 STWHIP INT1 POOH to BHA. 22:00 - 00:00 2.00 STWHIP INT1 Broke down and laid out BHA. Cleared floor. 10/20/2000 00:00 - 00:30 0.50 CASE INT1 Rigged up casing handling tools. Held PJSM with rig crew. 00:30 - 01:00 0.50 CASE INT1 Made up casing shoe joints and checked same for circulation and back pressure. Printed: 11/28/2000 8:48:57 AM RECEIVED BP EXPLORATION JAN ~, 6 ZOOPage 3 of 7 Operations Summary Report Alaska 0il & Gas Cons. Commission Anchorage Legal Well Name: M-12 Common Well Name: M-12 Spud Date: 10/13/2000 Event Name: REENTER+COMPLETE Start: 10/13/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 7ES Rig Number: Sub Date From-To Hours Task Code Phase DesCription of Operations. · . 10120/2000 01:00 - 04:30 3.50 CASE INT1 RIH picking up 7" liner. Ran total of 27 joints (1111 FT.) 04:30 - 05:00 0.50 CASE INT1 Made up liner hanger and liner top packer and cimulated volume of liner. 05:00 - 09:00 4.00 CASE INT1 Ran liner in hole on 4" DP to 8650 ft. 09:00 - 09:30 0.50 CASE INT1 Repaired drum clutch on drawworks. 09:30 - 11:30 2.00 STWHIP INT1 Made up cementing head and CBU at 8650 ft. 11:30 - 12:00 0.50 STWHIP INT1 RIH with 7" liner to 9628 ft. TD. 12:00 - 14:30 2.50 CEMT INT1 Circulated and conditioned mud to cement liner. Held PJSM with Nabors, Schlumberger, Peak, Baroid personnel. Batch mixed 222 sacks Class G cement in blender. 14:30 - 15:30 1.00 CEMT INT1 Pumped 5 bbls. FW and tested lines to 4000 psi. Pumped 46 bbls. cement and dropped DP wiper plug. Pumped 5 FW and displaced cement from DP with 120 bbls. mud. Bumped plug with 3000 psi and set liner hanger. Released pressure and floats held OK. Released liner setting tool and set liner top packer. 15:30 - 17:30 2.00 CEMT INT1 Circulated excess cement from hole long way. Cleared surface equipment and mud pits of cement. 17:30 - 21:00 3.50,CEMT INT1 POOH with DP and liner setting tool.. Laid down tools and broke out cement head. 21:00 - 22:00 1.00 DRILL PROD1 Pulled wear bushing and made up BOP test equipment. 22:00 - 00:00 2.00 DRILL PROD1 Began testing BOPE. 10/21/2000 00:00 - 03:00 3.00 DRILL PROD1 Test BOP, pipe rems, blind rams, annular preventer, safety valve, dart valve, top drive, kelly hose, kill line and choke manifold to 250/3500 psi per BP Amoco and AOGCC specifications and regulations. Witness of test waived by John Crsip, AOGCC agent. 03:00 - 03:30 0.50 DRILL PROD1 Pulled BOP test plug and installed wear bushing. 03:30 - 07:00 3.50 DRILL PROD1 Made up 4 3/4" directional drilling BHA. 07:00 - 10:30 3.50 DRILL PROD1 RIH to 4600 ft. 10:30 - 12:00 1.50 DRILL PROD1 Slipped and cut drill line and serviced top drive. 12:00 - 13:30 1.50 DRILL PROD1 RIH to 7866 ft. 13:30 - 14:00 0.50 DRILL PROD1 Circulated drill pipe volume and prep to test casing. 14:00 - 15:00 1.00 DRILL PROD1 Attempted to pressure test casing. Pressured to 2838 psi and pumped into casing. Checked all surface equipment. Retested casing and pumped in at 2400 psi. Pressure bled to 1300 psi and stabilized in 45 minutes. 15:00 - 17:00 2.00 DRILL PROD1 Conducted kick while tripping D-1 and stripping drill. 17:00 - 18:00 1.00 DRILL PROD1 RIH to 9529 ft. Washed thru cement stringers to float collar at 9544 ft. 18:00 - 21:30 3.50 DRILL LHGR PROD1 Opened PBL sub and circulated and conditioned mud. Pumped dry job. 21:30 - 00:00 2.50 DRILL LHGR PROD1 Began POOH with drill pipe to run test seals and packer. 10/22/2000 00:00 - 02:30 2.50 DRILL LHGR PROD1 Finished POOH to BHA. 02:30 - 04:00 1.50 DRILL LHGR PROD1 Stood back BHA, laid down jars and downloaded MWD. 04:00 - 05:00 1.00 DRILL LHGR PROD1 Made up seal assembly for Baker liner top packer PBR below HOWCO RTTS packer. 05:00 - 09:00 4.00 DRILL LHGR PROD1 RIH with test seals and packer to top of liner hanger at 8497 ft. Tool operating parameters. Inserted test seals into PBR and located with 60K down weight. Tested liner to 3500 psi for 10 rains. - OK. While pressuring annulus, liner top packer set and packed off @ 480 psi. Tested annulus and liner top packer to 3500 psi for 10 mins. - OK. Pulled seals. Tested liner and liner top packer to 3500 psi for 30 rains. - OK. 09:00 - 11:00 2.00 DRILL LHGR PROD1 Took operating parameters. Inserted test seals into PBR bore and located with 60K down weight. Tested liner to 3500 psi for 10 mins. - OK. While pressuring annulus for test, liner top packer set and packed Printed: 11/28/2000 8:48:57 AM RFCFIVFD BP EXPLORATION JAN 2 $ Z001 Page4of7 Operations Summary ReportAlaska Oil & Gas Cons. Commission Legal Well Name: M-12 Common Well Name: M-12 Spud Date: 10/13/2000 Event Name: REENTER+COMPLETE Start: 10/1312000 End: 1115/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 7ES Rig Number: · . Date From - To Hours TaSk SUb' Phase Description of Operations COde 10/22/2000 09:00 - 11:00 2.00 DRILL LHGR PROD1 off. Tested liner top packer to 3500 psi for 10 rains - OK. Pulled seals from PBR. Tested liner top packer to 3500 psi for 30 rains - OK. 11:00 - 14:00 3.00 DRILL LHGR PROD1 Pumped dry job and POOH with test packer. 14:00 - 15:30 1.50 DRILL LHGR PROD1 Laid down packer and cleared floor. 15:30 - 17:30 2.00 DRILL LHGR PROD1 Made up directional drilling BHA #.4 with rerun bit. 17:30 - 21:30 4.00 DRILL LHGR PROD1 RIH with bit to float collar at 9544 ft. 21:30 - 00:00 2.50 DRILL PROD1 Drilled landing collar, float collar and shoe track. Had approximatey 30 ft. of hard cement in shoe. 10/23/2000 00:00 - 03:30 3.50 DRILL PROD1 Displace 11.2 ppg LSND mud from hole with 8.5 ppg Quik-DriI-N mud. 03:30 - 04:30 1.00 DRILL PROD1 Drilled float shoe and 20 ft. of new hole to 9648 ft. 04:30 - 05:00 0.50 DRILL PROD1 Circulated for 10 mins. and pressured hole to 480 psi for FIT test to 9.56 ppg EMW. 05:00 - 00:00 19.00 DRILL PROD1 Directionally drill from 9648 ft. to 9894 ft. AST- 11 114 hrs; ART- 4 1/2 hrs. 10124/2000 00:00 - 09:00 9.00 DRILL PROD1 Drlg to 10108; AST 2.25, ART 3.5 09:00 - 10:30 1.50 DRILL PROD1 Sweep Hole, CBU 10:30 - 12:30 2.00 DRILL PROD1 Short Trip to Shoe @ 9635, Tight {~ 9720-9635, Backream. RIH WINo Problem 12:30 - 00:00 11.50 DRILL PROD1 Drlg to 10380, AST 2.75, ART 4.25 Hrs 10/25/2000 00:00 - 11:00 11.00 DRILL PROD1 Drlg to 10733, Pump Pressure Increased Rapidly, Drag Normal, ART 5, AST 2.75, DP Plugged 11:00 - 13:30 2.50 DRILL LMWD PROD1 Pull Into CSG Shoe, Drag 10-15 Over 13:30 - 14:00 0.50 DRILL LMWD PROD1 Attempt to Unplug Drill String 14:00 - 19:30 5.50 DRILL LMWD PROD1 POH, Wet, Break Bit, Mud Drained From Motor 19:30 - 22:30 3.00 DRILL LMWD PROD1 RIH MWD, Break HOC, Plugged ~ Pulsor, Change Out Probe, Carbide Oriface Retainer Had Fractured & Fallen On Top Of Stator, Surface Check Motor, Leaking From Carbide Inserts on Kick Pad, L/D Motor, M/U New Motor 22:30 - 23:30 1.00 DRILL MOTR PROD1 Slip & Cut 100' Drill Line 23:30 - 00:00 0.50 DRILL MOTR PROD1 Service Top Drive 10/26/2000 00:00 - 01:30 1.50 DRILL LMWD PROD1 Change Out Pad & Adjust Motor to 1.5 Deg, M/U Bit, RIH W/BHA 01:30 - 03:30 2.00 DRILL LMWD PROD1 C/O Elevators & P/U 51 Jts 4" DP 03:30 - 08:00 4.50 DRILL LMWD PROD1 RIH, Fill Pipe {~ 4509 & 9546, Wash Through Tight Spots @ 9940 & 10030, Check Shot ~ 10663 08:00 - 08:30 0.50 DRILL LMWD PROD1 Mad Pass f/10720-10733 08:30 - 12:00 3.50 DRILL PROD1 Drlg to 10853, ART 2.25, AST .5 Hrs 12:00 - 00:00 12.00 DRILL PROD1 Drlg to 11212, ART 5.5, AST 3.5 Hrs 10~27~2000 00:00 - 09:00 9.00 DRILL PROD1 Drlg 11212-11357, MWD Stopped Sending Signal 09:00 - 11:00 2.00 DRILL PROD1 Drlg W/O MWD Signal to 11413, Surge & Bleed Off String ~ Connection, Re Start MWD 11:00 - 12:00 1.00 DRILL LMWD PROD1 Mad Pass Over section Missed Due to MWD Temp Failure; 11357-11413, AST 6, ART 3.5 Hrs 12:00 - 00:00 12.00 DRILL PROD1 Drlg to 11787, AST 2.75, ART 5 Hrs, Recieved 1 day BOP Test Extension From AOGCC 10/28/2000 00:00 - 12:00 12.00 DRILL PROD1 Drlg to 12191, ART 4.5 AST 4.75 Hrs 12:00 - 18:00 6.00 DRILL PROD1 Drlg to 12412, Tight Hole @ 12,355, Temporarily Stuck after Slide, Broke Loose With Rotary ART 2.5, AST 1.5 Hrs 18:00 - 20:00 2.00 DRILL PROD1 POH FI 12412-9628 (7" Shoe) Tight @ 11140 & 10142 20:00 - 21:00 1.00 DRILL PROD1 Service Top Drive, Clean Shaker Pit for New Mud 21:00 - 21:30 0.50 DRILL PROD1 Check Brake Linkage While Prep for Mud Displacement 21:30 - 22:30 1.00 DRILL PROD1 RIH, Wipe Tight Area F/9825-9839 22:30 - 00:00 1.50 DRILL PROD1 Displace To New Lighter Weight, Lower Solids Mud 10/29/2000 00:00 - 01:00 1.00 DRILL PROD1 Finish Displace Mud Printed: 11/28/2000 8:4S:57 AM (" RECEIVED BP EXPLORATION JAN 2 6 ZOO'Page 5 of 7 Operations Summary Report AlaskaOil & Gas Cons. Commission Anchorage Legal Well Name: M-12 Common Well Name: M-12 Spud Date: 10/13/2000 Event Name: REENTER+COMPLETE Start: 10/13/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 7ES Rig Number: ..... Sub Date From - To Hours Task Code Phase Description of Operations lO/29120o0 o1:o0 - 12:oo 11.oo DRILL PROD1 Drlg to 12707 ART 4.75, AST 4.5 12:00 - 14:30 2.50 DRILL !PROD1 Drlg to 12817 ART 1, AST 1.25 Hrs 14:30 - 16:30 2.00 DRILL PROD1 Ciro Sweep Around 16:30 - 23:00 6.50 DRILL PROD1 POH, 25K Overpull From 12638-12555 & 12487 23:00 - 00:00 1.00 DRILL PROD1 Handle BHA, Download MWD .10/30/2000 00:00 - 01:00 1.00 DRILL PROD1 Down Load MWD, L/D Probe, Break down BHA, Check Motor 01:00 - 01:30 0.50 DRILL PROD1 Clean Floor 01:30 - 02:30 1.00 DRILL PROD1 Pull Wear Bushing, Set Test Plug, M/U Test String 02:30 - 05:30 3.00 DRILL PROD1 Test BOP, All Lines, Valves, Rams, Annular, Manifold to 250 Low for 5 Min, 3500 High For 10 Min. as per BP, Witness Waived by Jeff James AOGCC 05:30 - 06:30 1.00 DRILL PROD1 Pull Test Plug, Install Wear Ring 06:30 - 09:30 3.00 DRILL PROD1 PJSM, RA, Load Sperry Soumes & M/U BHA ,09:30 - 16:00 6.50 DRILL PROD1 RIH, Take Check Shots @ 11778 & 12807, Wash Thru Tight Spots @ 9950, 10050, 11021, 12372 16:00 - 22:30 6.50 DRILL PROD1 Drlg to 13137 ART 3.5 Hrs 22:30 - 00:00 1.50 DRILL PROD1 Circ Sweep Around 10/31/2000 00:00 - 01:30 1.50 DRILL PROD1 Ciro Sweep Around, Slight Increase In Sand In Returns 01:30 - 02:00 0.50 DRILL PROD1 POH F/13137-12842 to Position MWD for MAD Pass w/Nukes 02:00 - 10:00 8.00 DRILL PROD1 Run MAD Pass Log from 12842-12042 @ 90 ft/hr, Rotating @ 20-25 RPM, Torque 5,000-6,000 Ft/~, Except in Doglegs, Circ (~ 224 gpm, 1345 Pump Pressure, No Overpulls 10:00 - 11:30 1.50 DRILL PROD1 POH F/12042- 7" Shoe @ 9628, SLM, No Problems 11:30 - 12:00 0.50 DRILL PROD1 Clear Floor 12:00 - 13:00 1.00 DRILL PROD1 Cut & Slip 80 ft Drill Line 13:00 - 13:30 0.50 DRILL PROD1 Service Top Drive 13:30 - 14:30 1.00 DRILL PROD1 RIH to 13137, No Excess Drag or Restrictions 14:30 - 17:30 3.00 DRILL PROD1 Cir Sweep Around, Increase in Sand @ Shakers on Bottoms Up, Spot 140 BBL Liner Running Pill 17:30 - 19:30 2.00 DRILL PROD1 POH F/13137 to 9628, Drop Rabbit, No Problems 19:30 - 22:30 3.00 DRILL PROD1 POH to 4400, SLM 22:30 - 00:00 1.50 DRILL PROD1 Change Elevators, POH L/D 21 Jts 3 112" HWDP 1111/2000 00:00 - 02:00 2.00 DRILL PROD1 POH 02:00 - 04:00 2.00 DRILL PROD1 Remove Nuke Sources, Download MWD Data, L/D BHA, Break Bit 04:00 - 04:30 0.50 DRILL PROD1 Clear/Clean Floor 04:30 - 05:30 1.00 CASE PROD1 R/U CSG Tools 05:30 - 10:30 5.00 CASE PROD1 PJSM, Run 88 Jts 4.5" 12.6~ L80 IBT-Mod, R3 10:30 - 11:00 0.50 CASE PROD1 M/U Baker HGR/PKR Assy 11:00 - 12:00 1.00 CASE PROD1 Circ Liner Volume 12:00 - 15:30 3.50 CASE PROD1 RIH W/Liner on 4"DP to 7" Shoe 15:30 - 16:00 0.50 CASE PROD1 Circ DP & Liner Volume, UP 170K, Down 145K, 460psi @ 4 BPM 16:00 - 17:30 1.50 CASE PROD1 RIH W/Liner, Started Taking Weight ~ 9939, Dog Leg 16, After Dog Legs of 22.56 @ 9961 & 34 Deg @ 9692, RIH to 10032, Work Pipe Repeatedly & Make Slow Progress to 10125, Dog Legs of 16-18 Deg, Better Progress Below 10125, RIH to 13137, Taking Weight 17:30 - 20:30 3.00 CASE PROD1 Break Circ Slowly, Working Pipe, Initially 225K UP, 120K Down, Full Returns, Final Reciprocation; 180K Up,130K Down, 6 BPM ~ 1125psi, Batch Up CMT 20:30 - 22:30 2.00 CASE PROD1 PJSM, Pump 5 BBL B45 Spacer @ 9.5 ppg, Shut Down, Test Lines to 4500 psi, OK, Pump Remaining 45 BBL Spacer, Pump 104 BBL (500 sx) G CMT @ 15.8 ppg, Flush Line, Launch Dart, Displace W/70 BBL Perf Pill Followed By Mud, Bump Plug, Floats Held, Confirm Liner Hung, Release, Pressure Up to 1000 psi, P/U to Kick out Dogs Observe Printed: 11/28/2000 8:48:57 AM (' (" RECEIVED BP EXPLORATION JAN 2'6 ZOO1 Page6 of 7 Operations Summary Report Alaska Oil & Gas Cons. Commission Anchorage Legal Well Name: M-12 Common Well Name: M-12 Spud Date: 10/13/2000 Event Name: REENTER+COMPLETE Start: 10/13~2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 1115/2000 Group: RIG Rig Name: N^BORS 7ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 111112000 20:30 - 22:30 2.00 CASE PROD1 Pressure Loss, Set Down on Liner Top PKR, Observe 2 Bumps as PKR Set, Set Down Again & Rotate 6 Turns for BackUp Set, CIP 2200 Hrs 11 I1 ~2000 22:30 - 00:00 1.50 CASE PROD1 Continue to Displace W! Seawater, 5 BBL CMT in Returns 11/2/2000 00:00 - 03:30 3.50 CASE PROD1 Displace to Clean Seawater, Able to Salvage 600 bbl Mud 03:30 - 04:00 0.50 CASE PROD1 Clean Under Shakers, Mix & Pump Dry Job ,04:00 - 06:30 2.50 CASE PROD1 POH f/9468-3170 06:30 - 09:00 2.50 CASE PROD1 POH & L/D 102 Jts 4" DP 09:00 - 09:30 0.50 CASE PROD1 Break & L/D Baker Setting Tool 09:30 - 10:00 0.50 CASE PROD1 Replace Paddle & Seat on 2" Damco Valve 10:00 - 11:00 1.00 CASE PROD1 Close Blind Rams & Pressure Test, Liar/Liner Top PKR to 3500 psi, 30 Minutes, OK 11:00 - 12:00 1.00 CASE PROD1 PJSM, PJU to Run Guns 12:00 - 13:00 1.00 CASE PROD1 P/U 225' Halliburton 2.5"6 SPF,11 gram, JRC, RDX Perf Guns & Blanks 13:00 - 13:30 0.50 CASE PROD1 Change Out Elevators, R/U Nabors CSG Tools 13:30 - 14:00 0.50 CASE PROD1 MlU Firing Head & Ported Sub 14:00 - 17:30 3.50 CASE PROD1 PIU 107 Jts 2 7~8" 7.7# Fox R2 Tbg, 3341' 17:30 - 18:00 0.50 CASE PROD1 R/D CSG Tools, Change Out Elevators 18:00 - 21:30 3.50 CASE PROD1 RIH WI Guns to LC ~ 13050, Tag Up, Locate,Space Out, Position Guns ~ 13045-13030, 13000- 12925 & 12895--12760, 6 SPF, 2 1/2" Guns, 11 gram, JRC, RDX 21:30 - 22:30 1.00 CASE PROD1 PJSM, Close Annular, Pressure Up Well, Shot Detected 22:30 - 23:00 0.50 CASE PROD1 Bleed Off Pressure, Open Bag, POH 12518, Fluid Loss 1 BBL/HR 23:00 - 00:00 1.00 CASE PROD1 POH 11/3/2000 00:00 - 02:30 2.50 CASE PROD1 POH FI 11400-7379; wet, Standing Back 61 stds 4" DP, Wet 02:30 - 03:30 1.00 CASE PROD1 Slip & Cut 90' Drill Line 03:30 - 07:30 4.00 CASE PROD1 Pull Out of Hole, Laying Down 4" DP FI 7379 to 3646 07:30 - 08:00 0.50 CASE PROD1 Change Elevators, PJU CSG Tools 08:00 - 11:30 3.50 CASE PROD1 Pull Out of Hole, Laying Down 2 7/8" TBG, wet 11:30 - 13:00 1.50 CASE PROD1 PJSM, Break & L/D Firing Head & Ported Sub, L/D Spent Guns & Blanks, All Shots Fired 13:00 - 14:00 1.00 CASE PROD1 Clean Rig Floor of Gun Debris, Hole Taking Less Than 1 BPH 14:00 - 14:30 0.50 CASE PROD1 Pull Wear Ring 14:30 - 00:00 9.50 CASE PROD1 PJSM, Rig UP & Run 4 1/2" 12.6# 13CR FOX R-2 TBG 1114/2000 00:00 - 05:30 5.50 CASE PROD1 Run 4.5" 12.6# 13CR Fox Class A R-2 Completion to 8497 05:30 - 06:00 0.50 CASE PROD1 Service Top Drive 06:00 - 07:30 1.50 CASE PROD1 Finish Running 294 Jts 4.5" 12.6# 13CR Fox Class A R-2 TBG to 9465 07:30 - 09:30 2.00 CASE PROD1 Space Out, Land Hgr, RILDS 09:30 - 13:30 4.00 CASE PROD1 Reverse Circ Corrosion Inhibited Seawater into Well, Keeping Rate ~ 3 BPM 13:30 - 16:00 2.50 CASE PROD1 Drop Ball, Set PKR, P.T. TBG to 3500 psi, 30 Minutes, Bleed TBG to 1500 psi, P.T. Annulus to 3500 psi, 30 Minutes, Bleed TBG ~ Shear RP 16:00 - 17:30 1.50 BOPSUF PROD1 L/D Landing Joint, SET TWC, Test to 2500 From Below, OK 17:30 - 18:00 0.50 BOPSUF PROD1 Blow Down Lines & Unhook Same 18:00 - 19:00 1.00 BOPSUF PROD1 N/D BOP & Set Back 19:00 - 19:30 0.50 WHSUR PROD1 Move Tree & Adapter Into Cellar 19:30 - 22:30 3.00 WHSUR PROD1 Install SBSM Seal, Adapter Flange & Tree. Test to 5000 psi 22:30 - 23:30 1.00 WHSUR PROD1 Pull TWC, R/D Lubricator 23:30 - 00:00 0.50 WHSURI PROD1 PJSM, Freeze Protect 11/5/2000 00:00 - 02:30 2.50 WHSUR' PROD1 Reverse Circ 150 BBL Diesel With Little Reds Hot Oil Service ~ 2.5 BPM, 1000 psi. FUD Hot Oil Service, Let U Tube Printed: 11/2812000 8:4Ei:57 AM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: M-12 Common Well Name: M-12 Spud Date: 10/13/2000 Event Name: REENTER+COMPLETE Start: 10/13/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 7ES Rig Number: SUb Date From - To Hours Task. Code Phase Description of Operations 111512000 02:30 - 03:00 0.50 WHSUR PROD1 Set BPV, PT to 2500 psi 03:00 - 04:00 1.00 WHSUR PROD1 NID Second Annulus Valve 04:00 - 04:30 0.50 WHSUR PROD1 NIU Companion Flange on CSG Head Valve, Secure Tree, Rig Released 0430 Hrs 1110512000 RECEIVED JAN ~ 6 ZOO1 Alaska Oil & Gas Cons. Commissio~ Anchorage Printed: 11/28/2000 8:48:57 AM 12-Dec-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well M-12A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,653.65' MD 8,669.80' MD 13,137.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) North Slope Alaska Alaska Drilling & Wells PBU_WOA M Pad, Slot M-12 M-12A Surveyed: 30 October, 2000 S UR VEY REPORT 12 December, 2000 Your Ref: APl 500292059301 Surface Coordinates: 5974309.18 N, 628213.30 E (70° 20' 16.9705" N, Kelly Bushing: 58.85ft above Mean Sea Level '148° 57' 34.7252" W) DRII--I-ING SERVICE=: Survey Ref: svy10661 A Halliburton Company Sperry-Sun Drilling Services Survey Report for M-f2A Your Ref: APl 500292059301 Surveyed: 30 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8653.65 38.160 68.410 7721.19 7780.04 8669.80 38.130 68.510 7733.89 7792.74 8719.78 39.330 76.350 7772.90 7831.75 8752.66 39.280 81.570 7798.35 7857.20 8780.09 38.920 85.950 7819.64 7878.49 8810.65 38.410 90.830 7843.51 7902.36 8844.16 37.360 96.130 7869.96 7928.81 8872.54 37.020 99.620 7892.57 7951.42 8904.56 36.720 102.000 7918.19 7977.04 8935.39 36.000 103.590 7943.02 8001.87 8967.53 35.230 105.510 7969.15 8028.00 8998.50 35.100 105.610 7994.46 8053.31 9034.43 35.190 105.820 8023.84 8082.69 9062.41 35.370 107.680 8046.69 8105.54 9092.59 35.460 110.180 8071.28 8130.13 9154.45 35.480 111.240 8121.66 8180.51 9248.09 35.380 111.710 8197.96 8256.81 9340.75 35.020 113.770 8273.68 8332.53 9435.44 34.070 116.660 8351.68 8410.53 9529.23 33.130 118.580 8429.80 8488.65 9564.82 32.890 119.530 8459.65 8518.50 9631.49 33.140 122.970 8515.56 8574.41 9661.22 37.880 131.160 8539.77 8598.62 9692.18 46.980 139.120 8562.61 8621.46 9723.41 53.030 140.580 8582.67 8641.52 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (rt) (ft) 1684.74N 2099.45 E 5976029.57 N 630283.63 E 1688.40 N 2108.73 E 5976033.39 N 630292.85 E 1697.80 N 2138.49 E 5976043.30 N 630322.45 E 1701.79 N 2158.92 E 5976047.63 N 630342.81 E 1703.67 N 2176.11 E 5976049.81 N 630359.96 E 1704.21N 2195.18 E 5976050.67 N 630379.02 E 1702.97 N 2215.70 E 5976049.79 N 630399.56 E 1700.62 N 2232.69 E 5976047.73 N 630416.59 E 1697.02 N 2251.56 E 5976044.45 N 630435.51 E 1692.98 N 2269.38 E 5976040.71 N 630453.40 E 1688.28 N 2287.50 E 5976036.32 N 630471.60 E 1683.49 N 2304.68 E 5976031.83 N 630488.86 E 1677.89 N 2324.59 E 5976026.57 N 630508.86 E 1673.23 N 2340.06 E 5976022.18 N 630524.41 E 1667.56 N 2356.60 E 5976016.79 N 630541.05 E 1654.87 N 2390.18 E 5976004.67 N 630574.83 E 1635.00 N 2440.69 E 5975985.67 N 630625.68 E 1614.36 N 2489.95 E 5975965.87 N 630675.28 E 1591.50 N 2538.52 E 5975943.85 N 630724.24 E 1567.45 N 2584.51 E 5975920.59 N 630770.63 E 1558.04 N 2601.46 E 5975911.47 N 630787.74 E 1539.20 N 2632.50 E 5975893.16 N 630819.10 E 1528.75 N 2646.20 E 5975882.96 N 630832.98 E 1513.90 N 2660.81 E 5975868.35 N 630847.84 E 1495.61N 2676.22 E 5975850.33 N 630863.55 E Dogleg Rate (°/'tOOft) 0.43 10.10 10.06 10.15 10.11 10.20 7.53 4.56 3.85 4.22 0.46 0.42 3.89 4.81 0.99 0.31 1.34 2.00 1.51 1.60 2.84 22.56 34.08 19.70 Alaska Drilling & Wells PBU WOA M Pad Vertical Section Comment 1619.02 1627.11 1653.64 1672.45 1688.64 1706.99 1727.19 1744.23 1763.40 1781.67 1800.39 1818.22 1838.89 1855.04 1872.47 1908.14 1961.99 2014.82 2067.53 2118.02 2136.77 2171.50 2187.36 2205.18 2224.62 Tie on Survey MWD Magnetic Top of Window Continued... 12 December, 2000- 11:54 -2- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for M-f 2A Your Ref: APl 500292059301 Surveyed: 30 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 9753.67 55.720 139.610 8600.30 8659.15 9783.41 56.010 131.080 8617.01 8675.86 9814.63 57.510 124.450 8634.13 8692.98 9836.28 56.770 118.960 8645.89 8704.74 9882.33 58.690 112.760 8670.49 8729.34 9907.48 58.480 111.490 8683.60 8742.45 9939.41 63.260 113.680 8699.14 8757.99 9972.96 66.460 112.420 8713.39 8772.24 10001.39 66.600 112.310 8724.71 8783.56 10032.68 69.180 116.980 8736.49 8795.34 10065.15 73.860 118.520 8746.78 8805.63 10096.88 78.280 120.550 8754.42 8813.27 10126.98 82.100 119.140 8759.55 8818.40 10160.82 85.440 116.880 8763.22 8822.07 10188.75 86.740 111.880 8765.13 8823.98 10219.48 88.400 109.410 8766.43 8825.28 10253.49 88.460 105.820 8767.36 8826.21 10315.14 89.630 104.390 8768.39 8827.24 10406.56 90.680 103.720 8768.14 8826.99 10438.19 93.380 107.960 8767.02 8825.87 10468.73 94.000 113.920 8765.06 8823.91 10499.48 94.120 115.230 8762.88 8821.73 10531.71 94.550 116.000 8760.44 8819.29 10563.44 94.680 116.650 8757.89 8816.74 10594.53 94.750 117.030 8755.33 8814.18 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 1476.75 N 2692.00 E 5975831.74N 630879.65 E 1459.27 N 2709.28 E 5975814.56 N 630897.23 E 1443.30 N 2729.91 E 5975798.94 N 630918.13 E 1433.74N 2745.37 E 5975789.66 N 630933.75 E 1416.79 N 2780.39 E 5975773.31N 630969.06 E 1408.71 N 2800.27 E 5975765.56 N 630989.07 E 1397.99 N 2826.01 E 5975755.29 N 631014.99 E 1386.11N 2853.95 E 5975743.88 N 631043.13 E 1376.18 N 2878.07 E 5975734.37 N 631067.42 E 1364.09 N 2904.40 E 5975722.73 N 631093.95 E 1349.75 N 2931.64 E 5975708.86 N 631121.43 E 1334.57 N 2958.43 E 5975694.14 N 631148.47 E 1319.81 N 2984.15 E 5975679.82 N 631174.45 E 1304.02 N 3013.84 E 5975664.54 N 631204.41 E 1292.52 N 3039.21 E 5975653.48 N 631229.97 E 1281.70 N 3067.94 E 5975643.15 N 631258.88 E 1271.41 N 3100.34 E 5975633.42 N 631291.45 E 1255.35 N 3159.85 E 5975618.38 N 631351.22 E 1233.15 N 3248.53 E 5975597.69 N 631440.27 E 1224.53 N 3278.93 E 5975589.59 N 631470.81 E 1213.64 N 3307.38 E 5975579.19 N 631499.45 E 1200.88 N 3335.28 E 5975566.92 N 631527.56 E 1186.99 N 3364.25 E 5975553.52 N 631556.77 E 1172.96 N 3392.60 E 5975539.98 N 631585.35 E 1158.97 N 3420.25 E 5975526.47 N 631613.23 E 9.26 23.75 18.40 21.57 12.12 4.39 16.12 10.13 0.61 16.10 15.10 15.25 13.50 11.89 18.46 9.68 10.55 3.00 1.36 15.88 19.58 4.27 2.73 2.08 1.24 Alaska Drilling & Wells PBU WOA M Pad Vertical Section Comment 2244.56 2265.62 2289.55 2306.89 2345.01 2366.27 2393.86 2423.87 2449.69 2478.19 2508.13 2537.83 2566.40 2599.07 2626.49 2657.00 2690.94 2752.57 2843.99 2875.58 2905.83 2936.01 2967.52 2998.45 3028.70 Continued... 12 December, 2000.11:54 - 3 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for M-f 2A Your Ref: AP1500292059301 Surveyed: 30 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 10627.46 94.930 116.850 8752.55 8811.40 10656.77 96.280 114.250 8749.69 8808.54 10689.17 96.840 109.210 8745.99 8804.84 10719.11 98.140 107.080 8742.08 8800.93 10751.13 96.040 106.570 8738.13 8796.98 10783.28 95.780 106.020 8734.82 8793.67 10813.58 94.860 106.310 8732.01 8790.86 10874.68 93.690 106.820 8727.46 8786.31 10905.59 95.600 107.010 8724.96 8783.81 10967.53 96.160 108,190 8718.61 8777.46 11002.24 99.640 107.860 8713.84 8772.69 11036.88 98.680 107.440 8708.33 8767.18 11062.07 99.390 107.710 8704.37 8763.22 11123.19 92.770 108.840 8697.90 8756.75 11155.99 92.580 110.140 8696.37 8755.22 11250.16 95.170 110.390 8690.00 8748.85 11343.03 80.970 108.790 8693.12 8751.97 11374.69 80.430 108.920 8698.24 8757.09 11435.76 80.480 111.470 8708.37 8767.22 11496.56 80.220 107.810 8718.56 8777.41 11528.70 80.780 105.140 8723.87 8782.72 11590.00 82.220 102.500 8732.93 8791.78 11622.42 83.150 100.750 8737.06 8795.91 11710.21 83.470 100.580 8747.29 8806.14 11802.54 84.200 103.580 8757.21 8816.06 1144.11N 3449.50 E 5975512.10 N 631642.73 E 1131.53 N 3475.81E 5975499.97 N 631669.26 E 1119.61 N 3505.70 E 5975488.57 N 631699.35 E 1110.37 N 3533.91E 5975479.81N 631727.71E 1101.17 N 3564.32 E 5975471.14 N 631758.27 E 1092.20 N 3595.02 E 5975462.69 N 631789.12 E 1083.80 N 3623.99 E 5975454.79 N 631818.23 E 1066.43 N 3682.39 E 5975438.42 N 631876.92 E 1057.47 N 3711.87 E 5975429.96 N 631906.54 E 1038.84 N 3770.60 E 5975412.34 N 631965.58 E 1028.20 N 3803.29 E 5975402.26 N 631998.45 E 1017.83 N 3835.87 E 5975392.45 N 632031.21 E 1010.32 N 3859.59 E 5975385.35 N 632055,05 E 991.27 N 3917.27 E 5975367.28 N 632113.04 E 980.34 N 3948.15 E 5975356.88 N 632144,11E 947.80 N 4036.28 E 5975325.85 N 632232.79 E 916.75 N 4123.50 E 5975296.30 N 632320.52 E 906.66 N 4153.07 E 5975286.71 N 632350.26 E 885.87 N 4209.58 E 5975266.90 N 632407.12 E 865.72 N 4266.03 E 5975247.72 N 632463.90 E 856.74 N 4296.42 E 5975239.25 N 632494.44 E 842.26 N 4355.29 E 5975225.78 N 632553.55 E 835.78 N 4386.78 E 5975219.84 N 632585.15 E 819.64 N 4472.47 E 5975205.18 N 632671.10 E 800.43 N 4562.22 E 5975187.50 N 632761.17 E Dogleg Rate (°llOOff) 0.77 9.96 15.55 8.28 6.75 1.88 3.18 2.09 6.21 2.10 10.07 3.02 3.01 10.99 4.00 2.76 15.39 1.75 4.12 5.95 8.38 4.86 6.07 0.41 3.33 Alaska Drilling & Wells PBU WOA M Pad Vertical Section Comment 3060.71 3089.31 3121.22 3150.83 3182.58 3214.54 3244.69 3305.57 3336.34 3397.85 3432.15 3466.29 3491.13 3551.72 3584.35 3677.79 3769.96 3801.11 3861.01 3920.67 3952.35 4012.96 4045.08 4132.10 4223.82 Continued... 12 December, 2000. f1:54 - 4. DrillQuest ZOO.05 Sperry-Sun Drilling Services Survey Report for M.f 2A Your Reft APl 50029205930f Surveyed: 30 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11841.40 90.310 101.930 8759.07 8817.92 11872.48 94.750 100.570 8757.69 8816.54 11896.87 98.200 99.680 8754.94 8813.79 11932.62 99.380 99.630 8749.48 8808.33 11991.72 99.380 100.900 8739.85 8798.70 12027.22 96.350 99.670 8734.99 8793.84 12057.23 94.680 97.910 8732.11 8790.96 12084.14 94.740 98.140 8729.90 8788.75 12120.48 93.260 97.170 8727.36 8786.21 12147.93 93.200 97.820 8725.82 8784.67 12178.93 93.390 98.590 8724.03 8782.88 12210.73 93.140 98.130 8722.22 8781.07 12272.49 93.070 94.710 8718.88 8777.73 12335.76 92.640 92.820 8715.72 8774.57 12364.32 92.710 93.280 8714.39 8773.24 12397.82 92.950 93.400 8712.74 8771.59 12459.33 94.310 93.840 8708.84 8767.69 12531.36 93.630 93.090 8703.86 8762.71 12560.09 90.060 93.020 8702.93 8761.78 12614.16 83.720 91.500 8705.86 8764.71 12654.10 80.420 91.520 8711.37 8770.22 12679.14 80.100 91.130 8715.61 8774.46 12738.95 80.790 89.170 8725.54 8784.39 12770.74 83.150 88.670 8729.98 8788.83 12796.67 83.460 87.970 8733.00 8791.85 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (fi) (fi) (fi) 791.87 N 4600.06 E 5975179.59 N 632799.14 E 785.81N 4630.50 E 5975174.05 N 632829.69 E 781.55 N 4654.36 E 5975170.20 N 632853.61E 775.63 N 4689.18 E 5975164.87 N 632888.54 E 765.24 N 4746.56 E 5975155.46 N 632946.08 E 758.96 N 4781.16 E 5975149.78 N 632980.78 E 754.40 N 4810.68 E 5975145.72 N 633010.37 E 750.65 N 4837.23 E 5975142.43 N 633036.99 E 745.82 N 4873.16 E 5975138.22 N 633072.99 E 742.25 N 4900.33 E 5975135.11 N 633100.22 E 737.83 N 4930.96 E 5975131.22 N 633130.93 E 733.22 N 4962.37 E 5975127.14 N 633162.41 E 726.32 N 5023.65 E 5975121.29 N 633223.79 E 722.17 N 5086.70 E 5975118.22 N 633286.91 E 720.66 N 5115.19 E 5975117.19 N 633315.42 E 718.71 N 5148.59 E 5975115.81 N 633348.85 E 714.83 N 5209.85 E 5975112.99 N 633410.17 E 710.49 N 5281.58 E 5975109.87 N 633481.96 E 708.96 N 5310.25 E 5975108.83 N 633510.65 E 706.83 N 5364.17 E 5975107.62 N 633564.60 E 705.78 N 5403.70 E 5975107.26 N 633604.15 E 705.21 N 5428.38 E 5975107.11 N 633628.83 E 705.06 N 5487.35 E 5975107.96 N 633687.80 E 705.65 N 5518.82 E 5975109.09 N 633719.25 E 706.41 N 5544.57 E 5975110.29 N 633744.98 E Dogleg Rate ("/'l OOft) 16.28 14.94 14.60 3.30 2.12 9.20 8,06 0.88 4.87 2.37 2.55 -1.64 5.53 3.06 1.63 0.80 2.32 1.40 12.43 12.06 8.26 2.00 3.43 7.59 2.94 Alaska Drilling & Wells PBU WOA M Pad Vertical Section Comment 4262.60 4293.6O 4317.77 4352.98 4411.15 4446.22 4475.95 4502.61 4538.62 4565.84 4596.61 4628.19 4689.27 4751.40 4779.38 4812.23 4872.56 4943.14 4971.30 5024.08 5062.65 5086.70 5143.89 5174.25 5199.01 Continued... 12 December, 2000 - 11:54 - 5 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for M-f 2A Your Reft APl 500292059301 Surveyed: 30 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 12858.00 83.460 88.240 8739.99 8798.84 708.42 N 5605.46 E 12951.53 82.970 88.980 8751.04 8809.89 710.68 N 5698.31 E 13044.06 82.970 90.960 8762.36 8821.21 710.73 N 5790.14 E 13065.16 82.540 91.270 8765.02 8823.87 710.32 N 5811.07 E 13137.00 82.540 91.270 8774.35 8833.20 708.74 N 5882.28 E Global Coordinates Northings Eastings (ft) (ft) 5975113.34 N 633805.83 E 5975117.19 N 633898.63 E 5975118.80 N 633990.44 E 5975118.75 N 634011.37 E 5975118.39 N 634082.60 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.736° (15-Oct-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 104.280° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13137.00ft., The Bottom Hole Displacement is 5924.82ft., in the Direction of 83.130° (True). Dogleg Rate (°/'lOOft) 0.44 0.94 2.12 2.51 0.00 Alaska Drilling & Wells PBU WOA M Pad Vertical Section Comment 5257.52 5346.95 5435.93 5456.31 5525.71 Projected Survey Continued... December, 2000.11:54 -6- DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for M. f 2A Your Ref: AP1500292059301 Surveyed: 30 October, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA M Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8653.65 7780.04 1684.74 N 2099.45 E 8669.80 7792.74 1688.40 N 2108.73 E 13137.00 8833.20 708.74 N 5882.28 E Comment Tie on Survey Top of Window Projected Survey Survey tool program for M-f2A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 8653.65 7780.04 8653.65 7780.04 13137.00 8833.20 Survey Tool Description AK-1 BP_HG MWD Magnetic 12 December, 2000.11:54 - 7- DrillQuest ZOO.05 ALASKA OIL AND GAS CONSERVATION CO~iSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 27%1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 gez Prudhoe Bay Unit M-12Al BP Exploration (Alaska) Inc. Permit No: 200-151 Sur. Loc. 2047'SNL, 605'WEL, Sec. 01, T1 IN, RI2E, UM Btmhole Loc. 1373'SNL, 4624'WEL, Sec. 05, TI IN, RI3E, UM Dear Mr. Stone: 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours)of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely,. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ,~ ,,--,d day of October, 2000 dlf/Enclosures CCl Department ofFish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 09/27/2000 .. 11:30 FAX 907 564 4040 bl~ EXPLORATION .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 003 . Type of Request: [] Abandon [] Nra, Casing [] Change Approved Program [] Repair Well [] Pull Tubing [] Vafiar~e I--I Operation Shutdown [] Re-Enter 8USl~nded Well [] Stimulate 2. Na..me of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2047' SNI., 605' WEL, SEC. 01, TllN, R12E, UM At top of productive interval N/A - Water Injection Well At effective depth 98' SNL, 2336' EWL, SEC. 06, T11N, R12E, UM At total depth 54' SN~, 2555,'.EWL~ SEC. 06, T11N, R12E, UM 12. Present well condition summary Total depth: measured 10615 feet true vertical 9364 feet Effective depth: measured 10169 feet true vertical 9232 feet Type of well: I-'l Development [] Exploratory l-'l Stretigraphic [] Sewi~e Back k~' Sidee'a~k 6. Datum Eiew4;~,n (DF or KB) KBE -- 55.20' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8, Well Number M-12 9. Permit Number 81-63 10. APl Number 50-029-20593 11. Field and Pool Prudhoe Bay Field / Prudhoe .Bay Pool RECEIVEh Plugs {measured) Junk (measured) Cement Cap at 9960' (08/96) Fill at 10169' MD (10/90) Casing Length Slze Structural Conductor 110' 20" x 30" Surface 2646' 13-3/8' Intermediate 9625' 9-5/8" Production Uner 1474' 7" Cemented 8 cu ycls concrete 3720 cuff Permafrost II 1362 cuff Class 'G', 130 cuff PF 'C' 434 ouft Class S EP 2.9 1998 N~$1~ 0il & G~ Cons. Comm~ MD AnCtwr~e 110' 110' 2671 ' 2871' 9650' 8564' 9144' - 10813' 8153' - 9383' Perforation depth: measured true vertical 9858' - 9863', 9869' - 9888', 9900' -9992', 101S7' - 10212' Sqzd: 10007' - 10157' (four intervals) subsea 8681.' - 8981' (four open intervals) Tubing (size, grade, and measured depth) 7", 26#, L-50 to 8924' wRh 5-1/2", L-80 to g0gg' DUPLICATE Packers and SSSV (type and measured depth) 9-518" TIW packer at 8969'; 7" Otis WD packer with TP assembly at 9992'; 4-1/2" SSSV Landing Nipple and insert at 2087' ;i3. Attachments [] Description summary of proposal I"1 Detailed operations program r'] BOP sketch 14. Estimated date for commencing operation October 6, 1998 16. If proposal was verbally approved Nar~, e of approver Oentaat Engineer Nallle/Numbe~. J. A#erl Elherriff, 564.6204 oa.te approv ,ed 15, Status of well classifications as: I-] O!1 [] Gas [-I Suspended Water Injection -- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~----~.._ .-~,.~,. ~ D= ste.e Title Engineering ,Supervisor Commission use Only iCondltions of Approval: Notify Commission so representative may witness Plug integrity.~==._,~ - BOP Test ~ Location clearance ___._ Mecha.'... J_ ty fo--requires 10- Approved by order of the Commissio~~ _._ _N~..~ Commissioner Form 10-403 Rev. 06/15/88 - - ~ Submit/In ~'riplicate ared ryices nlling To: From: Subject: AOGCC, Attn: Steve Davies Scott Kolstad M-12A Drilling Permit Date: September 25, 2000 Nabors 7ES will be moving to M-12A upon completion of sidetrack operations on DS 2-30B, which are estimated to be complete around October 5m. A permit to drill, number 98-205, was issued for M-12Ai on October 14, 1998. Proposed M-12A drilling operations may not commence by October 14, 2000. To ensure permit number 98-205 does not expire before commencing drilling operations, please cancel permit number 98-205 and assign a new permit number to the M-12A sidetrack. Operations for the M-12A sidetrack have been modified from the 98-205 permit and are reflected in the current permit to drill application. Contact me with any further questions. Scott Kolstad Operations Drilling Engineer .WK: 564-5347 HM: 349-4811 Cell: 240-8060 RECEIVED- SEP 27 2000 Alaska Oil & Gas Cons. Commission Anchorage ..:., are. d ,'?:-' _u ervlces rilling AlaSKa V BP Ex~laratJ~-/ ARCO AlliBka Inc. To: Blair Wondzell - AOGCC Data; November 10, 1998 From: C. Michael Jackson Subject: M-12Ai Suspension DESCRIPTION OF SCOPE CHA~G_E. Wall M-~ 2Al(APl #50-029-20593-01) was planned as a Zone 4 undul~llng MI injector, extended horizontal sidetrack. The original'7" completion was collapsed at 4cas' md during an attempted pre-rig MIT on the 9-5/8" casing. Consequently fishing operations with Nabors 7E,.q have not been a~la t~ retrieve the completion string with a current cost of $1,113M and are not eoonoml= to continue. TherdOt8 tl~e well will be suspended with a 15.8 ppg cement plug Into and acmes the perforations, As we discussed the open perforations existing from g984' to 9858' Will §e squeezed with 5 barrels o~ cement and covered with a 10 barrel cement plug to ~9700'. A prel~ia~(G) blend weighted to 15.8 ppg and yielding 1.18 oubfo feet per sack with a total volume of 15 bbls I 1t4 ft= t 72 eke will be pumped from the top of the cement cap at 9960'. Five(Ii) barrels will be squeezed away t~ the formation I perforations for an estimated TOC O 9700'. The' oemenl plug will be weight tested and pressure tested with a N~J~ ~lope field AOGCC representative on site. ' Sho[~ld you have any questions please feel free to give me a call. Sir~erely, Operations Drilling Engineer 564-5486 Wk 275-t544 Pgr 349-1383 Hm John (~i~hrist Dan Stone Z00~ EOI~¥~0~&Z~ dq 0t0t tgs ~06 :[¥~ 0C:~T 000Z/~/60 09/25/2000 14:41 FA/L 907 564 404U , DP Alaska hared ervlces rilling TO: Steve Davies DATE: COMPANY: AOGCC 9/25/O0 FAX: 276-7542 PHONE: FROM: Scott Kolstad FAX: (907) 564-4040 PHONE: (907) 564-53, 47 #1111 i i i#1 !: :111~1 i iI , i i'i i , ii RE: M-12A permit to drill number, Number of attachments not including fax cover: I [ '14:41 YA/k 907 5B4 4040 d ry .ces nll ng b~ ~2[I"LURA'J.' J. UN ~ uuz TO: From: Subjeot: AOGCC, Attn: Steve Davies Scott Kelstad ~/~ M*12A Drilling Permit Date: September 2B, 2000 Nabors 7ES Will be moving to M-12A upoN completion of sidetrack operations on DS 2-30B, which are estimated to be oomplete around October 5". ^ permit to drill, number 98-205, was issued for. M-12Ai on Ootober 14, 1998. Proposed M-12A drilling operations may not commence by October 14, 2000. To ensure permit number 98-205 does not expire before commencing drilling operations, please cancel permit number 98-205 and assign a new permit number to the M-12A sidetraok. Operations for the M-12A sidetrack have been modified from the 98-205 permit and are refleoted in the ourrent permit to drill application, Contact me with any further questions.' Scott Kolstad Operations Drilling Engineer WK: 564-5347 HM: 349-4811 Cell: 240-8060 STATE OF ALASKA . ALASKa(" .,IL AND GAS CONSERVATION COM~ .,SION PERMIT TO DRILL Revised: 09112/00 20 AAC 25.005 Drill Reddll 1 I b. Type of well I [] Service [] Development Gas [] Single Zone [] Multiple Zone la.'Type of work B Re-Entry [] Deepen [] Exploratory [] Stratigraphic Test [] Development Oil 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 55.2' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ,~Z~,~ ADL 028282,,,!~ 4. Location of well at surface ,/ ,J' ,./ 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2047' SNL, 605' WEL, SEC. 01, T11N, R12E, UM Prudhoe Bay Unit At top of productive interval ~8. Well Number 800' SNL, 2332' WEL, SEC. 06, T11N, R13E, UM M-12Ai Number 2S100302630-277 At total depth 9. Approximate spud date 1373' SNL, 4624' WEL, SEC. 05, T11N, R13E, UM 10/05/00 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 028279, 1373'I R-1 lA is 600' Away 2560 13447' MD / 8842' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8725' MD Maximum Hole Angle 101.3 ° Maximum surface 2434 psig, At total depth ('I'VD) 8661' / 3300 psig 18. Casing Program Setting Depth ~(.,,~ ~ ~-~,~..-~-~-~_.3'~,-~..-~.~,~,,... ~._'~ Size Specifications Top Bottom Quantity of Cement Hole Casing Wei.qht Grade Couplin.cl Len_eth MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 1085' 8575' 7767' 9660' 8580' 258 cu ft Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3937' 9510' 8455' 13447' 8842' 584 cuft Class 'G' ....... 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary SEP I $ Z000 Total depth: measured 10615 feet '/' Plugs (measured) Cement Plug at 9600' (11/98) true vertical 9384 feet v'" Alaska 0~ & Gas Coa$, Effective depth: measured 10169 feet Junk (measured) Fill at 10169' MD (10/90) true vertical 9232 feet . . Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2646' 13-3/8" 3720 cuft Permafrost II 2671' 2671' Intermediate 9625' 9-5/8" 1362 cuft Class 'G', 130 cu ft PF 'C' 9650' 8564' Production Liner 1474' 7" 434 cu ft Class 'G' 9144' - 10613' 8153' - 9383' Perforation depth: measured 9858' - 9863', 9869' - 9888', 9900' - 9992', 10157' - 10212' Sqzd: 10007' - 10157' (four intervals)ORIGINAL true vertical subsea 8681' - 8981' (four open intervals) 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: Scott, Kolstad, 564-5347 Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~....,..w~¥t, ~ Title Senior Drilling Engineer Date ~ ~! 3~ Permit Number APl Number Approval D~e ,~ See cover letter I~C205 :iA ~ -/..~'// 50- 029-20593-01"" j ~ _.~;~, (~/_,,7 for other requirements Conditio~'f Approval: Samples Required [] Yes [] No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required I~ Yes [] No~ Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~.SK psi Other: ORIGINAL SIGNED BY by order of Seamoun Approved By D Taylor ~ommissioner the commission Date ]' O-".--~-' Form 10-401 Rev. 12-01-85 Submit In Triplicate STATE OF ALASKA ALASK IL AND GAS CONSERVATION COM" ~I-'PLICATION FOR SUNDRY APPROVA~L SION 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska . 12. 99519-6612 [] Suspend [] Repair Well [] Operation Shutdown Location of well at surface 2047' SNL, 605' WEL, SEC. 01, T11 N, R12E, UM At top of productive interval N/A - Water Injection Well At effective depth 98' SNL, 2336' EWL, SEC. 06, T11N, R12E, UM At total depth 54' SNL, 2555' EWL, SEC. 06, T11N, R12E, UM [] Plugging [] Time Extension [] Pull Tubing [] Vadance ~ Re-Enter Suspended Well [] Stimulate Present well condition summary Total depth: measured 10615 feet true vertical 9384 feet Effective depth: measured 9600 feet true vertical 8524 feet Casing Length ' Structural Conductor Surface Intermediate Production Liner 110' 2646' 9625' Size 1474' 5. Plugs (measured) [] Perforate Ba Other 20" x 30" 13-3/8" 9-5/8" 11 Junk (measured) Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 55.20' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number M-12 9. Permit Number 181-063 / 398-264 10. APl Number 50- 029-20593-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Cement Plug at 9600' (11/98) Cemented MD 'I'VD 8 cu yds concrete 110' 110' 3720 cu ft Permafrost II 2671' 2671' 1362 cu ft Class 'G', 130 cu ft PF 'C' 9650' 8564' 434 cu ft Class 'G' 9144' - 10613' 8153' - 9383' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 7",26#,L-80 4745'-8924'; 5-1/2"from 8924'-9099' RECEIVED .. · SFP 18 000 Alaska 0{i & Gas Cons. C0mmissi Packers and SSSV (type and measured depth) 9-5/8" TIW packer at 8969'; 7" Otis WD packer with TP assembly at 9992' '~ 3. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation October 5, 2000 [] Detailed Operations Program. [] BOP Sketch I 15. Status of well classifications as: 16. If proposal was verbally.approved [] Oil [] Gas [] Suspended Service Water Injection Name of approver Date Approved Cor~;=ct Engineer Name/Number: Scott, Kolstad, 564-5347 Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-46P_8 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~------------~.,.,.... ,~. ~ Title Senior Ddlling Engineer Date c~/! ~/~ ~ Conditions of Approval: Notify Commission so representative may witness I ^pp ov No ~ ~ ~~ '1 Plug integrity ~ BOP Test ' Location clearance '.' I '.,_,~ ~ /¢:;~'~ I Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 0.6/15/88 Commissioner Date Submit In Triplicate M-12A Permit to Drill I Well Name: I M-12A Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location: Target Location: Bottom Hole Location: X: 628,213.29' Y: 5,974,309.18' 2,047' FNL 605' FEL T11N R12E S01 Umiat X: 631,350.00' Y: 5,975,610.00' 800' FNL 2,332' FEL T11N R13E S6 Umiat X: 634,350' Y: 5,975,090' 1,373' FNL 4,624' FEL T11N R13E S5 Umiat I AFE Number: 14P1415 ]Estimated Start Date:110/5/00 I MD: I ~3,447' I I TVD= 18,842' I I Rig: I Nabors 7ES I Operating days to complete: 123 I BF/MSL= 1 30.68' I IRKS= 155.2' I Well Design (conventional, slimhole, etc.): I Horizontal Sidetrack I Objective: I Development producer targeting Zone 4 sands. Mud Program: Milling/Cutting Casin9 Mud Properties: LSND DensitY11.2(PPg) IFunnel45 - 55Vis I Yield20 - 30P°int Whipstock Window in 9-5/8" I pH I HTHP FL 9 - 9.5 <9 Intermediate Mud Properties: LSND I 8-1/2" hole section From sidetrack depth to TD at 9,660' MD (8,580' TVD). Density(ppg) I FunnelVis I Yield Point I PV tauO 11.2 I 45 - 55I 20 - 28 I 10 - 17 3 - 7 .. IPh APl FL 9 - 9.5 <9 Production Mud Properties: Low Density QUICKDRILn Density (ppg) I Funnel vis LSRV I PV 8.3 - 8.5 I 40 - 50 < 20,000 cPI 5 - 8 6 1/8" hole section YP Ca++ APl FI 20-27 <100 <10 pH 9.0-9.5 RECEIVED SEP 18 ~000 Alaska ~; & Gas Cons. ~mmi~ion An~omge ' M-12A Permit to Drill Directional: KOP: I 8,725' MD Maximum Hole Angle: Close Approach Well: R-1 lA Iniector 101.3° @ 12,137' (8,793' TVD) Center to Center Distance 600' Passed Risk Based Rules R-24 Producer 708' Passed Risk Based Rules Logging Program: Intermediate Section Production Hole IDrilling: MWD / GR / Resistivity Open Hole: None Cased Hole: None Drilling: MWD / GR / Resistivity / DEN / NEU Open Hole: None Formation Markers: Formation Tops MD TVDss Comments TJF 7,593' Kick-Off Point 8,725' 7,767' Kick-off with-in the Kingak JF TJE 8,768' 7,800' TJD 8,993' 7,978' TJC 9,381' 8,295' TJB 9,479' 8,375' TJA 9,571' 8,450' Sag River 9,660' 8,524' Est. pore pressure 3,300psi (7.4 ppg EMW) Shublik 9,725' 8,573' Top Sadlerochit 9,873' 8,661' Est. pore pressure 3,300 psi (7.4 ppg EMW) TZ4A DL 1 10,250' 8,744' TZ4A Invert 1 10,333' 8,750' TZ4A UL 1 10,427' 8,742' TZ4B Revert 1 11,300' 8,643' TZ4A DL 2 11,870' 8,730' TZ4A Invert 2 12,000' 8,747' TZ4A UL 2 12,176' 8,728' TZ4B Revert 2 12,762' 8,625' TZ4A DL3 13,165' 8,711' TD 13,447' 8,785' Casincl/Tubing Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tb9 O.D. MD/TVD MD/TVD 8-1/2" 7" 26# L-80 BTC-M 1,085' 8,575'/7,767' 9,660'/8,580' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3,937' 9,510'/8,455' 13,447'/8,842'. Tubing 4-1/2" 12.6# 13Cr-80 New Vam 9,510' Surface 9,510'/8,455' RECEIVED SEP I 8 _ .000 Aiaska 0~ & Gas C~ns. Anchorage · M-12A Permit to Drill Cement Calculations: Liner Size 1 7" Intermediate I Basis: Lead: None Lead TOC: N/A Tail: Based on 80' shoe track volume, 935' of open hole with 30% excess, 150' liner lap, and 200' of 4" DP x 9 5/8" annulus volume Tail TOC: At top of 7" liner at 8,575' MD (-7,767' TVD). I Total Cement Volume: I Lead I None ITail I 46 bbl/258 ft~ / 221 sks of Dowell Premium 'G' at 15.8 ppg and 1 1.17 cf/sk. Liner Size I 4 Y2" Production I Basis: Tail: Based on 3,787' of open hole with 50% excess, 150' of 7" x 4.5" liner lap, 200' of 7" x 4" drill pipe annulus volume, and 80' of 4-1/2" shoe joint. Tail TOC: At top of liner -9,510' MD (8,450' TVD). Total Cement Volume: I Tail I 104 bbl / 584 ft= / 500 sks of Dowell Premium 'G' at 15.8 ppg and I 1 1.17 cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Section- . Maximum anticipated BHP: 3,500 psi @ 8,580' TVDss- Sag River · Maximum surface pressure: 2,642' psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) Production · Maximum · Maximum (based on Interval- anticipated BHP: 3300 psi @ 8,661' TVDss - Zone 4 surface pressure: 2434 psi @ surface BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 3500 psi 8.5 ppg Seawater/6.8 ppg Diesel RECEIVED SEP 18 2000 Alaska 0~t & Gas Co~s, C~mmission Anchorage ' M-12A Permit to Drill Drilling Hazards/Contingencies: ***See Pad Data Sheet for details of previous wells drilled on M Pad*** HYDROGEN SULFIDE - H2S · WOA practice does not designate pads as H2S pads, but states there is a potential on any well. Standard Operating Procedures for H2S precautions should be reviewed and followed at all times. The highest levels of H2S measured recently on M pad were 120 ppm on M-04 measured 1/10/00 and 80 ppm on M-31 measured 4/15/00. Reference: Hydrogen Sulfide under Standard Operating Procedures DRILLING CLOSE APPROACH: There are two close approach wells, R-1 lA and R-24, for the proposed M-12A well path. Both wells failed a close approach scan using major risk rules. Both wells have been risk weighted and pass using risk based rules for close approaches. See directional section above for separation information. INTERMEDIATE SECTION: · The M-12A well pathwill kick off in the Kingak shale and drill -935' of Kingak shale. · Tight hole conditions and stuck pipe have been encountered in the Kingak shale interval. Increased mud weights and the addition of shale stabilizers may be required. · The kick tolerance for the 8-1/2" open hole section would be and infinite influx (annular volume) assuming an influx from the Sag River interval at -9,660' MD. This is a worst case scenario based on a 7.8 ppg pore pressure gradient, a fracture gradient of 11.5 ppg at the 9 5/8" window and 11 ppg mud in the hole. PRODUCTION SECTION: · Faults in the area of M and U Pads have a history of being conductive and have resulted in numerous lost circulation incidents. · There are three prognosed fault crossings on the planned M-12A sidetrack trajectory. The faults have a moderate risk of lost circulation. · Differential sticking will be a problem if loss circulation is occurring or if the drill string is left stationary for an extended period of time. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 13,447'. This is a worst case scenario based on a 7.8 ppg pore pressure, a minimum fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.3 ppg mud in the hole. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. RECEIVED SEP 18 ~.000 Alaska 0{~ & Gas Co,Is. C~.mmiss'~n Anchor;age M-12A Permit to Drill SUMMARY SIDETRACK PROCEDURES Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. 2. Liquid pack the 9-5/8" casing to surface. Test the integrity of the cement plug and 9-5/8" casing to 3000 psi for 30 minutes. The top of the 7" tubing is at 4,745'. 3. RU E-line. Cut the 7" tubing at _+ 8,800' in the middle of a joint. 4. Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 5. Bleed casing and annulus pressures to zero. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Rig 1. 2. 3. 4. 5. Operations: MIRU Nabors 7ES. Circulate out freeze protection and displace well to sea water. Set TWC. Nipple down tree. Nipple up and test BOPE. PU drill pipe and fishing assembly to recover the remaining 7" tubing from the Eline cut and above. MU window milling BHA and RIH picking up drill pipe as needed to drift the 9 5/8" casing down to the BP setting depth of _ 8,750'. Set BP on E-line at _+ 8,750' MD (set as needed to avoid cutting casing collar). 6. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock as desired and set on BP. Mill window in 9-5/8" casing at _+ 8,725' MD. POOH. 7. Kick-off and drill the 8-1/2" intermediate section to Top Sag at ± 9,660' MD (8,580' TVDss). 8. Run and cement a 7", 26# intermediate drilling liner, fully cemented into the 9-5/8" casing. 9. Make up and RIH with a 6 1/8" drilling assembly to the landing collar. 10. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3000 psi for 30 minutes. 11. Drill the 6 1/8" production section as per directional plan to an estimated TD of 13,447' MD (8,842' TVD). 12. Run and cement a 4 ~", L-80, 12.6#, solid production liner to TD. Spot perf pill, displace well to clean sea water above liner top. POOH. 13. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 14. PU TCP guns, RIH to perf depth, and perforate well. POOH LD DP and perf guns. 15. Run 4-1/2", 12.6# 13Cr-80 New Vam completion tying into the 4-1/2" liner top. 16. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure the well. 19. Rig down and move off. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. Install gas lift valves. Estimated Pre-rig Start Date: Estimated Spud Date: Scott Kolstad Operations Drilling Engineer 564-5347 9/15/00 10/5/00 M-12A Proposed Completion BF Elevation = 30.65' RKB = 55.2' 4-1/2" 'X' Landing Nipple with 3.813" seal bore J 2100' 13-3/8", 72 #/ft, L-80, BTC I 2671' Window Milled from x' - x' Top of Window at +/- 8,725 ' MD 4-1/2" 12.6# 13Cr-80, New Vam or NSCT Tubing 7" x 9 5/8" Baker ZXP Liner Top Packer HMC Liner Hanger SEP 1 8 2000 Aia~a 0~ & Gas Cons. Commi~sio[~ An, chomge Bridge Plug set at +/- 8,735' MD Otis Sliding Sleeve I 8,943' 9 5/8"TIW HBBP Packer I 8,969' w/PBR Top of 7" Liner I 9,145' I 9 5/8", 47 #/ft, L-80, BTC TOC 9,6O0' 7" Otis WD Packer I 9,992' I 1/2" XX- Plug 4-1/2" 'X' Landing Nipple with 3.813" seal bom 4 1/2" x 7" Baker 'S-3' Production Packer 4-1/2" 'XN' Landing Nipple with 3.813" seal bom and 3.725" No-Go ID. 4-1/2" WimLine Entry Guide spaced-out into liner top. I +1-9,510' I BAKER 4-1/2" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger Crossover to 4-1/2" BTC-Mod 9,660' I 7", 26 #iff, L-80, BTC 4-1/2" 12.6#/ft, L-80, BTC-Mod I +/' 13,447' Plug Back Depth I +1-13,367' Zone 4 Perfs Date Rev By Comments PRUDHOE BAY UNIT 8/12/00 SRK Proposed Completion WELL: M-12A APl NO: 50-029-20593-01 Shared Services Drilling PBTD I 10,506' 7", 29#/ff, L-80, BTC I 10,613' I TREE: 6' ClW WELLHEAD: FMC ACTUATOR: OTIS 13-3/8'. 72 #/ft, L-80, BTRS FOC SSSV LANDING NIPPLE (OTIS)( 3.813' ID) KB. ELEV = 55,2O' BF. ELEV = 30.65' IKOP: 3400' I l,~,,.x^,~L~: ,o I 7', 26 #/ft, L-80, IJ4S, R3 TUBING TUBING ID: 6.276' CAPACITY: 0.0382 BIJFr SCHLUMBERGER CHEMICAL CU'I-rER - HEAD LOST IN HOLE,DEPTH UNKOWN POSSIBLE IN 5 1/2" 'rBG OR CMT PLUG {~ 9600' TOP 3" = 3.5 OD. LENGTH = 14" OD = 5.75" TOP OF I9145 I 7" LINER 9-5/8'0 47#/ft, 9644 L-80, BTRS pERFORATION ,S, UMMARY REF: LOG: SiZE 3PF INTERVAL O,F EN/SQZ'D 3-3/8" 4 9858-9863 OPN 4/90 3-3/8' 4 9869-9888 ~3PN 4/90 3-3/8" 4 gg00-ggg2 OPN 4/90 3-3/8' 4 10007-10024 SQZD 3-3/8' 4 10030-10058 SQZD 3-3/8" 4 10075-10135 SQZD 3-3/8" 4 10145-10157 ~QZD 3-3/8" 4 10157-10212 ;)PN 4/90 CUT & MILLED TOP OF 7" CSG=~'° SLIDING SLEEVE (OTIS XA)(4.562' ID) I 8943 I 9-5/8~ PBR/PACKER I 8969 (TIW HBBP )( 4.000 'ID) I 5-1/2 ", 17 #/ft, TAILPIPE 5-1/2 ' 'X' NIPPLE I ( OTIS ) ( 4.562" ID) 9020 $-1/2' 'XN' N~PPLE I9°59 ( OTIS )( 4.445 · ID) "I"0(., ~1~ 5-1/2" TBG TAIL g099 ~ C~ a~l~ (4.092 ' ID) (ELMD) 9118 CEMENT PLUG LAYED BY NABORS 7ES 11-11-98 ":,' .' , , '. TOC=9600' TESTED TO 5000 PSI ~l.5bbl of DS Zone lock at 9930' Cement Cap on packer 9960'-9984' .Possible CMT Debris on Top of Packer 7" WD PACKER I (OTIS) ( 4.000' ID) I 9992 4-1/2" "x" NIPPLE ( OTIS ) ( 3.813" ID) 9999 MARKER JOINT (ELMD) 110048 4 1/2" XX-Plug Set 1 I/24/93 P~TD 110506 I-- L- O, I 10613 I -- {EV. BY COMMENTS NITIAL COMPLETION ~UT ON MAC, ADD PERFS JEWELRY LOG RUN Cement Cap ~EVISED TO PC ii PRUDHOE BAYUNIT WELL: M-12i APl NO: 50-029-20593-00 SEC 1; TN 11N; RGE 12E BP EXPLORATION (ALASKA) CWJ RKS DATE 8/5/81 7/4/90 10/27/90 8/26/96 SRW 02-23-99 RWL R CEIVED SEP 18 2000 Gas C(ms. ~.llllJ,~i(~ Anchorage Proposal Data for M-12A Wp09 ve~cal Odgin: Wall Horizontal Origin: Well Measurement Units: ft No~h Reference:Tree Neath Dogleg severity:Degrees per 100fl Vertical Section Azimuth: 104.504° Vertical Section Description:Well Vertical Seotion Origin: 0.00 N,O.00 E Measured Incl· Azlm. Verl]cel Northinga Eastinga VerticalDogleg Depth Depth 8action Rate 8725.0038.27568.977 7823.51 1719.97 N 2138.64 E1636.27 8765.0040.13275.984 7854.52 1727.54 N 2162.73 E1657.6712.000 9227.9535.422121A99 8227.37 1692.91 N 2427.01 E1922.16 9660.4535,422121A99 8579.90 156].g0N 2640.80 E2162.060.000 9660.4535.422121.499 8579.90 1561.90N 2640-g0 E2162.066.000 9670A5 35.422121.499 8588.05 1558.87 N 2645.74 E2167.~00.000 9978.1478.460123.799 8751.99 1421.92 N 2857.08 E2406.6314.000 10170.67 78.4~0123.799 8790.51 ]316.99 N 3013.83 E2594.770.000 10332.98 90.000108-000 8806.90 1247.00 N 3158.49 E2742.3912.000 10387.43 96.530108.220 8803.80 1230.11 N 3210.13 E2796.6212.000 11280.70 96.530108.220 8702.22 952.63 N 4053.11 E3682.320.000 11386.02 86.000108.000 8699.90 919.94 N 4153.05 E3787.2610.000 11463.96 78.981104.580 8710.08 898.27 N 4227.15 E3864.4410.000 11895.78 78.981104.580 8792.62 791.57 N 4637.36 E4288.300.000 12072.85 95.00097.000 8801.90 758.69 N 4810.39 E4464.0310.000 12137.07 101.347 96.007 8792.77 751.48 N 4973.52 E4526.9410.000 12639.19 101.347 96.007 8693.98 699.96 N 5363.11 E5013.720.000 12761.50 90.0~091AIO 8681.90 692.15 N 5484.35 E5133.0110.000 12913.60 74.79191.410 8701.97 688.45 N 5634.61 E5279.3610.000 13446.98 74.79191.410 8841.90 675.78 N 6149.16 E5780.500.000 Shared Services Drilling M-12A Wp 09 I DrillQuest' Single Well Target Data for M-12A WPS Measurement Units: ft Coordinate Target Point TVDrkb TVDee Northlnge EaetlngeASP Y ASP X Target Name Type Shape M-12AWp09GeoPoly EntryPoint 1747.ll N 2161.901',' 597(d}9.1.00N 6.10.145.001'.' I't)lyson Boundary Point BA 1747.ll ~-I 2161.90F. 5,.r/r,09.1.00N 1212.152~/'/3.871': 5975572.00N 631166.o01~ C 657.21N 4¢61.631': 5975046.00N 6.1296.1.OIIF. D 5#11.81 N 5444.57 E 5974991.00 N 63.1647.00 F. E 578.49 N 6399.54 I',' 5974~7.00 N 634602.00 F. F 774.66N 6390.891': 5~.r/5193.00N 6.14590.001'~ G 808.~9 N 54.16.34 E 59'/5211.00 N 6.1.16.15.00 F. ii 883.19N4665.491:. 5975272.00N 632#6.1,001:. I 1426.07 N 30.18.54 E 5975797.00N 631227.00 F, J 1846.80 N 2414.641',' 5976l~,f7.00 N Entry Point 8579.90 8523.00 1561.90 N 2640.80 F, 5975916.00 N 6.10827.00 F. Point EnlryPoin!8699.90 8643.00 919.94N4153.05E 5975300.00N 63235o.{}o1',' Point EnlryPoint8801.90 8745.00 759.68N4910.391£ 5975150.00N 63.1O10.0OF, Point EnlryPoint8681.90 8625.00 692.15N~484.35F. 5975095.00N 63.1685.001': Pein! Entry Point 8941.~O 8785.00 675.78 N 6149.16 I': 5975090.00 N 6.14.150.0o F, P,in! Ent~Point 8806.90 8750.00 1247.0ON 3158.49E 5975610.0ON 631350.0OI-'. M-I2A WP 09 TSGR M-12A Wp06'l'2 M-12A Wi~6'f3 M-12A Wp06 T4 M-12A Wp06 T5 M-12A Wl~9 TI C EIVED HorizontalWell: Coordinates: Current Well M-, Properties 2A WP$ Ref. Global Coordinates: 5974309.18 N, 628213.29 E Ref. Stmc(ure Reference: 3027.96 N, 2005.16 E Ref. Geographical Coordinates: 70' 20' 16.9705" N, 148' 57' 34,7254" W ~; -- RKB Elevation: 56.90fl above Mean Sea Level · 1~'t~~ o~"r~ '~ ~ /')i~s.~i~t 56.gOflaboveSimclureReference ~o ~ t~" Noflh Re~m~e ' Tree Nodh ~-- ~%~ ~aska 0~ & G~ Cons. ~mm~ r ...... ~= ................................ ~: :~'~ ...................................... ~ ............................................................................................ TJE- 78~6.90TYD l ......... ~. .~¢ ~ .kg o ..... ~t~ ................................. r .......... ~x ............... :":~- ' ..................................... ~,., ' ..................... ~' ................. ~% ............................ **~ .............. S ....... ~*~---*,~ ..................... ~4oo -. .................. ~% ................... ~,, ~ ............ ;so,~;,~¢*::-;.-**~$: ................. ;o¢~-L ....... ~.~ a~ - -~- ~ .............. -x ~ ...... ~ '~ : :' ~ ~ .................... ~ ~ ~ .................. ~' ~' ~z ~ ........' ~ ~ '~ ~ .........................rs~u - s6 2 ~. ~0 r~a e579.~0 WD / ~ ~ ~ ~x~ -- ~? ' .. ~,~, _ ~&~ - _.~ ~:_ ~ ~ ............................. 8579.90 T~ M-12~ ~p06 T4 1561.90 ~ 2640.80E M-12~ ~pO9 ~1 ~699.90 ~ ~6~1.90 ~D 4 112" Liner ~ M-12~ ~p06 ~ 692.15N, 54~4.~5 E M.12~ IYp06 T5 13446.98 MD 9000 -- ~ 124ZOO ~gS06'90 TFD315&49 E 919.94 ~ 415S. OS E ~01.90 ~ 8S41.90 r~ ea4a.9o ~D 758.6~ I I I I I I I I 1800 2400 3000 3600 4200 4800 ~00 6000 Scale: linch = 600ff Ve~ical Section Section ~imuth: 104.594~ (True No~h) sPerr%/-sunI ORILL. I_NG SGRVICGS I DrillQuest' Proposal Data for M.12A Wp09 VerUcal Origin:Well Holfzonta] Origin: Well Measurement Units: It i Nolth Reference:True Nodh Dogleg seve~'y: Degrees per 100fl Vett ca] Section Azimuth: 104.594° Vertical SecUon Desc~ption:Well Vertical Section Origin: 0.00 N,O.O0 E Measured Incl. AzJm. VerUcal Northlngs Eastlnge VerticalDogleg Depth Depth Section Rate g725.0038.27568.977 7823.51 1719.97N 2138.64 E1636.27 8765.0040.13275.984 7854.52 1727.54 N 2162.73 E1657.6712.000 9227.8535.422121.499 822737 1692.91 N 2427.01 £1922.166.000 9~60A5 35.422121.499 8579.90 1561.90N 2640.80 E2162.060.000 9660.4535A22 121A99 8579.90 1561.90N 2640.80 E2162.066.000 9670A5 35.422121.499 8588.05 1558.8/N 2645.74 E2167.600.000 9978.1478.460123.799 8751.99 1421.92 N 2857.08 E2406.6314.000 10170.67 78.460123.799 8790.51 1316.99 N 3013.83 E2584.770.000 10332.98 90.000108.000 8806.90 1247.00 N 3158.49 E274239 12.000 10387.43 96.530108.220 8803.80 1230.11 N 3210.13 E2796.6212.000 11280.70 96.530108.220 g'/02.22 952.63 N 4053.11 E3682.320.000 11386.02 S6.00O108.000 8699.90 919.94 N 4153.05 E3787.2610.000 11463.96 78.981104.580 8710.08 898.27 N 4227.15 E3864.4410.000 11895.78 78.981104.580 8792.62 791.57 N 463736 E 4288.300.000 12072.85 95.00097.000 8801.90 758.68 N 481039 E 4464.03I 0.000 12137.07 101.347 96.007 8792.77 751.48N 4873.52 E4526.9410.000 12639.19 10134796.007 8693.98 699.96 N 5363.11 E5013.720.000 12761.50 90.00091.410 8681.90 692.15 N 548435 E 5133.0110.000 12913.60 74.79191Al0 8701.97 688A5 N 5634.61 E5279.3610.000 13446.98 74.79191.410 8841.90 675.7g N 6149.16 E5780.500.000 180.0 ~ 1200 ,-- o z 600 O II ._ ~ 0 Scale: linch = 2400 I 600ff 3000 I 36O0 I M-IZ4 ~ 09 TSGR 8579.90 TVD ,90IV, 2640.80E 7" Casing 9660.45 MD 8579.90 TVD M-12A Wp09 TI 8806,90 TVD 1247.00 N, 3158.49 E Scale: linch = 600ft I 2400 3000 3600 Single Well Target Data for M-12A WP$- - TargetI Northlnge Eeetlnga ASP Y ASPX Shape ] ~7.,'f. ~16 i.~ ,-: 5976~;3.0o. -6~0~-5.0o, r,;,y~,,,, ~ 1747.1'" 216'.~I;J"7(~J.~N 6J0~45.~1~ ,I ]~I2.1~N ]~T).~TE~973~7~.~N ~)Illl.~E 657.21 N 4661.63 I~ 597~6.~ N 632863.~1~ 588.81 N 5~4.57 E 59~4~1.~ N 633~7.~ E 578.48 N 6399.54 E 5974~7.~ N 634f~2.~ I~ 774.66 N 6390.89 E 5975193.~ N 634590.~ I~ 808.99 N 543634 E 597~211.~ N 633635.~ I~ 8~.lg N4(~5.49 I~ ~975272.~ N 6~2863.~ E 1426.07 N 3038.54 I~ 597~787.~ N 631227.~ I~ Ig46.80 N 2414.(~ ![ 5976197.~ N 630596.1~ I~ 1561.90 N 2(~0.~ I~ 5975916.~ N (,30927.~ E Point 919.94 N 4153.05 E 59753~.~ N 632350.~ I~ Point 758.68N4810.39E5975150.~N 633010.~E Point 692.15 N 54M.35 E 597~)5.~ N 633685.~ E P,int 675.78 N 6149.16 E5975~0.~ N 634350.~ E Point 1247.~ N 3158.491~5~75610.~ N 631350.~E I',int ............. Measurement Un~ts: It Coordinate Target Point TVDrkb TVDaa Name Type M-12A Wp 09 G-eoPoly Entry Point Bouada~ POIntBA C D E F G J M-12A WP 09 TSGR Enlry Point 8579.90 &q23.00 ; M-IZA Wp06 T2'Entry Point 8699.90 8643.00 M-12A Wp06 T3 Entry Point 8801.90 8745.00 M-12A Wp06 T4 Entry Point 8681.90 8625.00 M-12A Wp06 T5 Entry Point 8841.90 8785.00 M-I 2A Wp09 TI Entry Point 8806.~0 8750.00 Eastings 4200 I 4800 5400 6000 I I I RECEIVED SEP 1 8 £V~;V ~aska ~; & Gas Cons. ~chorage M-12~ t~'pO6 T2 8699.90 I~9 4155.05E M-1211 lYp06 TS M-12,4 ~06 T4 8801.90 TI/D 868]. 90 Till} 75&68 IV, 4810.39 E 692.15 IV, $484.$5 E I 4200 Eastings 54OO 4 112" Liner 13446.98 MD 88~1.90 TVO / 8841. 90 TFD 675.78N, 6149.16£ ~ 6000 Reference is True North - 1800 - 1200 - 6OO 0 ~ Spe /,-Sun Drilling S ..vices Proposal Data - M- f 2A WPS - M- f 2A Wp09 8725.00 ..;:,~:'"':".] :,"'."~,,8'~'2~'$ ..";..'.:'68,9~ .':'78~3~5~1 :::;i"::..i'i'.:.'i'.i.:;:', ":'.'.1:?'191,g?'N .i{';{2..,113.8..~i~ i::.{'. !.,"".:;'." '"J ..... "i"."... 8765.00 40.00 40,132 75.984! 7854.52 31.01 1727.54 N 2162.73 E 12.000! 70.000 '4 ~o60.45 432.60 35.422 121.499 8579.90 352.52 1561.90 N 2640.80 E 0.000 0.000 '5 9660.45 0.00 35.422 121.499 8579.90 0.00 1561.90 N 2640.80 E 6.000 236.168 1::~6 I 9670'451 ~0.001 35.4221 1'21.4991 'S5".0sl S.~sl:~sS"-s7"l 2645'74EI 0.000 0.0001 ": 7- 9978.14 307,69- 78:460 123,799. 8751:99 163.94 1421.92 N 2857,08 E 14.000 3.301 · _. ._ :8' 10170.67 192.53 78.460 123,799 8790.51 38.52 1316.99N 3013:83E 0.000 0.000 '";9 10332.98 162131 - 90.000 ' 106.000 8806.90 16.39 1247.00 N 3158.49 E 12.000 305.261 10387.43 54.44 96.530 108,220 8803.80 -3.10 1230.11.N /3210:13 E 12.000 1.921 '11280.70 : 893.27-96.530` 108.220 8702.22 -101~58 952.63N 4053.11E 0.000 0:000 : .-_ .. . .- ..... ~ : .- .... : : . . _: -113-.8-6:02 ':~ 105,32 86.000 108.000 8699.90: : -2_.32 919.94 N 4153.05 E 10.000 :,1:81.200 :7i3 ii: .1t~3:_96 :L~i~7,94: ~---:78.981:~: ~:t:04.58-0:~87'10:08: ::: 10.18'. ~:~ 898;27.-N- 4227:15 E 10.000 ;:::: 205:57__8 :~i~:~-~14 :::: :-:11895:fS~::::431-:S2-:~!.~78.981:':~;:104;580.---879:):62: :~: i82:54 :.::: 791:~_~~ 4~7.36~E' :~: ~_~ili;-i~['120_72i85; :_:::I.7.7;~7-:; :: ~::000' : ~'Z:~o0': 8~0i :90i:~i::--~1~9~8 ':758~68-N:: 4:8'i 0:3-9 ~: -10.0oo~ :iL:~34~40~ ~:-:~6 ~:~'~:_;f 21:37_:07_-_' _--;~i-~.23--_1!i:i0i:~3~7 !~:-::.:9'6t007'i~ 8792.7.~ ;":~1;- :9~13~:-;~: .75-1';48'N::=i: ~87_ 3;5 2~E: ~__}-'~:7£~i~':1~6-~9~:~ :;! 1:~:~:1::1::-::' i'~:1:!~-~ ::~-:-:§~.---d0~' '-::i:869-3.9~::--~::-:;§~;-~9.---:: :~~:--: 53~;~-17E i~:~!i:!:-:-~-~ ~:~-:_--' :-:-~2-~.~27 ~-~ ~~= ~-:~-~-~=--~-~.~:--.~:--~,?' % ~2~-~-, :'~'~;~:-~-~ :~ ..... ~.~0-~:~:-:~ RECEIVED SEP 1 8 """" Alaska OJ{ & Gas Co~s. Commis$ior~ Anchors July, 2000 - 12:24 - 1 - DrillQuest North Slope Alaska Alaska State Plane 4 ~~%. . PBU_WOA M Pad M 12A WPS-M-12A WpQg,,,, ,, ,' ....",;,!!, :,,' ,:,,, PROPOSAL 'T ,"': ,,,,, ,, ~,,~'"r',iiii[",[i' 2;~.~¢;~/",'" Surface Coordinates: 5974309.18 E 20' 16.9705"N, 148° 57' 34.7254" W) Mean Sea Level · - D R~CEIVE Proposal Reft pro9857 RECEIVED SEP 18 2000 · Alaska 0~ A Gas Cons. ,~,mmi~ /~nchorage North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 8725.00 38.275 68.977 7766.61 8755.08 39.633 74.298 7790.00 8765.00 40.132 75.984 7797.62 8768.12 40.046 76.242 7800.00 8800.00 39.201 78.933 7824.56 8900.00 36.985 87.980 7903.32 8992.59 35.602 97.078 7978.00 9000.00 35.522 97.830 7984.03 9100.00 34.907 108.190 8065.80 9200.00 35.187 118.637 8147.74 9227.85 35.422 121.499 8170.47 9300.00 35.422 121.499 8229.27 9380.66 35.422 121.499 8295.00 9400.00 35.422 121.499 8310.76 9478.83 35.422 121.499 8375.00 9500.00 35.422 121.499 8392.25 9570.87 35.422 121.499 8450.00 9600.00 35.422 121.499 8473.74 9660.45 35.422 121.499 8523.00 9660.45 35.422 121.499 8523.00 9670.45 35.422 121.499 8531.15 9700.00 39.553 121.873 8554.59 9724.50 42.977 122.136 8573.00 9800.00 53.538 122.776 8623.20 9872.69 63.707 123.244 8661.00 Sperry-Sun Drilling Services Proposal Report for M-12A WPS - M-12A Wp09 Vertical Depth (It) 7823.51 7846.90 7854.52 7856.90 7881.46 7960.22 8034.90 8040.93 8122.70 8204.64 8227.37 8286.17 8351.90 8367.66 8431.90 8449.15 8506.90 8530.64 857~ Local Coordinates Northings (ft) 1719.97 N 1725.91 N 1727.54 N 1728.03 N 1732.40 N 1739.53 N 1737.19 N 1736.63 N 1723.73 N 1700.97 N 1692.91 N 1671.06 N 1646.63 Ni;":,;; ..... 1640.77 Eastings fit) 2138.64 E 2156.58 E 2162.73 E 2164.67 E 2184.53 E 2245.66 E 2300.28 E .67 E E E E 2561.51E 2596.53 E 2610.93 E 2640.80 E Global Coordinates........ '~"'Dogleg Northings Eas~n'gs ~.:~..~ate (it) ~ ~iooit) 5976065.47 N E , , 5976071.71,..N.';.?'?!'.'.~30340',~E 12.000 5976073.45'.N 63~46.16E 12.000 5976~96'"N::;'...630348.10 E 6.000 59~60"/'~:68 N"~0367.88 E 6.000 5~86.85-~630428.88E6.000 59~ 630483.53E 6.000 597608~96N 630487.82E 6.000 5976073.02 N 6305~.04E 6.000 5976051.16 N 630596.~E 6.000 N 630611.00 E 6.000 5976~2.10 N 630647.03 E 0.000 5975998.36 N 630687.30 E 0.000 59759~.67 N 630696.96 E 0.000 5975969.46 N 630736.32 E 0.000 5975963.23 N 630746.89 E 0.000 5975642.37 N 630782.27 E 0.000 5975933.80 N 630796.82 E 0.000 5975916.01N 630827.00 E 0.000 8579.90 1561.90 N 2640.80 E 5975916.00 N 630827.00 E 6.000 8588.05 1558.87 N 2645.74 E 5975913.06 N 630831.99 E 0.000 8611.49 1549.43 N 2661.04 E 5975903.88 N 630847.45 E 14.000 8629.90 1540.86 N 2674.74 E 5975895.55 N 630861.29 E 14.000 8680.10 1510.65 N 2722.19 E 5975866.16 N 630909.26 E 14.000 8717.90 1476.87 N 2774.16 E 5975833.27 N 630961.79 E 14.000 Vertical Section (It) 1636.26 1652.12 1657.66 1659.42 1677.54 1734.90 1788.35 1792.62 1850.08 1906.64 1922.15 1962.16 2006.89 2017.61 2061.33 2073.07 2112.37 2128.52 2162.04 2162.05 2167.59 2184.78 2200.19 2253.73 2312.53 Alaska State Plane 4 PBU_WOA M Pad Comment ST Exit (~. 12.000°/100ft 70.000° TF: 8725.00ft MD, 7823'.51ft TVD TJF Be;in Dir ~ 6.000°/100ft: 8765.00ft MD, 7854.52ft TVD TJE TJD End Dir: 9227.85ft MD, 8227.37ft TVD TJC TJB TJA Be.(;in Dir (~. 6.000°ll00ft: 9660.45ft MD, 8579.90ft TVD 7" Casing TSGR Tar;et - M-12A WP 09 TSGR, Geological Begin Dir ('~. 6.000°/100ft: 9660.45ft MD, 8579.90ft TVD 7" Casing TSGR Tar;et - M-12A WP 09 TSGR, Geological Be~in Dir ~. 14.000°/100ft: 9670.45ft ME), 8588.05ft TVD TSHU TSAD Continued... July, 2000- ~2:~1 - 2- DrillQuest 1.05.05a RECEIVED SEP 1 8 ?.000 Alaska ~ & Gas Cons. CommJ~.~ North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9900.00 67.527 123.398 8672.27 8729.17 9978.14 78.460 123.799 8695.09 8751.99 10000.00 78.460 123.799 8699.46 8756.36 10100.00 78.460 123.799 8719.47 8776.37 10170.67 78.460 123.799 8733.61 8790.51 10200.00 80.506 120.886 8738.96 8795.86 10300.00 87.627 111.168 8749.32 8806.22 10332.98 90.000 108.000 8750.00 8806.90 10387.43 96.530 108.220 8746.90 8803.80 10400.00 96.530 108.220 8745.47 8802.37 10500.00 96.530 108.220 8734.10 8791.00 10600.00 96.530 108.220 8722.73 8779.63 10700.00 96.530 108.220 8711.36 8768.26 10800.00 96.530 108.220 8699.98 8756.88 10900.00 96.530 108.220 8688.61 8745.51 11000.00 96.530 108.220 8677.24 8734.14 11100.00 96.530 108.220 8665.87 8722.77 11200.00 96.530 108.220 8654.50 87 11280.70 96.530 108.220 8645.32 8702.~ 11300.00 94.600 108.179 8643.45 8700.35 11386.02 86.000 108.000 8643.00 8699.90 11400.00 84.739 107.394 8644.13 8701.03 11463.96 78.981 104.580 8653.18 8710.08 11500.00 78.981 104.580 8660.07 8716.97 11600.00 78.981 104.580 8679.19 8736.09 Proposal Report for M- f 2A WPS - M- f 2A Wp09 Local Coordinates Global Coordinates ~"~Dogleg~ 'i . Northings Eastings Northings Eastings'"' ..~,.,~,~,Rate (ft) (ft) (ft) (~;ooft) 1463.21 N 2794.94 E 5975819.97 N ~0 E 14.000 1421.92 N 2857.08 E 5975779.74 N .'"". ;"' .'~, 163104.5.64 E 14.000 1410.01 N 2874.88 E 5975768.13'i':~i' 63'~'063'.64 E 0.000 1355.50 N 2956.30 E 5975715.03'.!'i.'~ ....... 631145.98-' E 0.000 1316.99 N 3013.83 E 59.7~.~i~50"N'!.'.ii';'.;..i~...6~.'f204.17-" E 0.000 1258.05 N 3127.43 5975~j~1~ 631318.75 E 12.000 1247.00 N 597561~'00 N 631350.00 E 12.000 1230.11 N 32: 5975594.00 N 631401.92 E 12.000 1226.20 N N 631413.85 E 0.000 1195.14 N E 5975560.85 N 631508.74 E 0.000 1164.08 ~, E 5975531.41 N 631603.62 E 0.000 1133.01 E 5975501.96 N 631698.51 E 0.000 1101.95- N"~:; E 5975472.51 N 631793.40 E 0.000 3693.85 E 5975443.07 N 631888.29 E 0.000 3788.22 E 5975413.62 N 631983.17 E 0.000 3882.59 E 5975384.18 N 632078.06 E 0.000 N 3976.96 E 5975354.73 N 632172.95 E 0.000 N 4053.11 E 5975330.97 N 632249.52 E 0.000 N 4071.36 E 5975325.28 N 632267.87 E 10.000 919.94 N 4153.05 E 5975300.00 N 632350.00 E 10.000 915.71 N 4166.32 E 5975295.99 N 632363.35 E 10.000 898.27 N 4227.15 E 5975279.59 N 632424.47 E 10.000 889.36 N 4261.39 E 5975271.27 N 632458.85 E 0.000 864.65 N 4356.39 E 5975248.19 N 632554.26 E 0.000 Vertical Section (ft) 2336.08 2406.62 2426.85 2519.37 2584.76 2612.22 2709.54 2742.38 2796.61 2809.07 2908.23 3007.38 3106.53 3205.68 3304.84 3403.99 3503.14 3602.29 3682.31 3701.48 3787.25 3801.17 3864.43 3899.81 3997.97 Alaska State Plane 4 PBU_WOA M Pad Comment End Dir' 9978.14ft MD, 8751.99ft TVD Be~in Dir (~. 12.000°1100ft: 10T70.67ft'FVlD, 8790.51ft TVD Tarqet - M-12A Wp09 T1 Geo"logical ' End Dir: 10387.43ft MD, 8803.80ft TVD Be;in Dir ~. 10.000°/10Oft: 11280.70ft'rv1D, 8702.22ft TVD Tar;et - M-12A Wp06 T2, Geological End Dir: 11463.96fl MD, 8710.08ft TVD Continued... July, 2000 - t2:11 - 3 - DrillQuest 1.05.05a RECEIVED AJaska C~;& Gas Cons. ;' · ~omm!~.~ North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth ffi) ffi) 11700.00 78.981 104.580 8698.30 8755.20 11800.00 78.981 1 04.580 8717.41 8774.31 11895.78 78.981 104.580 8735.72 8792.62 11900.00 79.362 104.394 8736.51 8793.41 12000.00 88.404 100.096 8747.16 8804.06 12072.85 95.000 97.000 8745.00 8801.90 12100.00 97.684 96.584 8742.00 8798.90 12137.07 101.347 96.007 8735.87 8792.77 12200.00 101.347 96.007 8723.49 8780.39 12300.00 101.347 96.007 8703.82 8760.72 12400.00 101.347 96.007 8684.14 8741.04 12500.00 101.347 96.007 8664.46 8721.36 12600.00 101.347 96.007 8644.79 8701.69 12639.19 101.347 96.007 8637.08 8693.98 12700.00 95.710 93.699 8628.06 8684.96 12761.50 90.000 91.410 8625.00 8681.90 12800.00 86.150 91.410 8626.29 8683.19 12900.00 76.150 91.410 8641.66 8698. 12913.60 74.791 91.410 8645.07 8701 13000.00 74.791 91.410 8667.74 8724.64 13100.00 74.791 91.410 8693.97 8750.87 13200.00 74.791 91.410 8720.21 8777.11 13300.00 74.791 91.410 8746.44 8803.34 13400.00 74.791 91.410 8772.67 8829.57 13446.98 74.791 91.410 8785.00 8841.90 Proposal Report for M. f 2A WPS - M. f 2A Wp09 Local Coordinates Global Coordinates . ~'~?~Dogleg~ Northings Eastings Northings Eas~..n. I;IS': ' ~....~,~ate ffi) (~) (~) ~- ~'1 ~ 0~) 839.94 N 4451.38 E 5975225.11 N '~ E 0.000 815.23 N 4546.38 E 5975202.03 N ...... ,,',,'-632745.07 E 0.000 791.57 N 4637.36 E 5975179.92.~i.N: ..... 632836,44 E 0.000 790.53 N 4641.38 E 5975178.95'i ,N, 63~840.47 E 10.000 769.50 N 4738.43 E 597511:.~;59'"~ :.;ili?:..i!...",,~=..:6~'~37.87 E 10.000 ,,.,, ,o.ooo 755.49 N 4837.18 59~ 633036.85 E 10.000 751.48 N 597514~?~8 N 633073.25 E 10.000 745.02 N 5975138.47 N 633134.71 E 0.000 734.76 N N 633232.37 E 0.000 724.50 N E 5975121.29 N 633330.04 E 0.000 714.24 N 40 E 5975112.70 N 633427.71 E 0.000 703.98 E 5975104.10 N 633525.38 E 0.000 699J E 5975100.74 N 633563.65 E 0.000 5423.01 E 5975096.68 N 633623.63 E 10.000 5484.35 E 5975095.00 N 633685.00 E 10.000 N 5522.80 E 5975094.71 N 633723.47 E 10.000 N 5621.46 E 5975093.97 N 633822.15 E 10.000 88.45 N 5634.61 E 5975093.87 N 633835.31 E 10.000 N 5717.97 E 5975093.24 N 633918.68 E 0.000 684.02 N 5814.43 E 5975092.52 N 634015.18 E 0.000 681.65 N 5910.90 E 5975091.79 N 634111.67 E 0.000 679.27 N 6007.37 E 5975091.07 N 634208.17 E 0.000 676.89 N 6103.84 E 5975090.34 N 634304.66 E 0.000 675.78 N 6149.16 E 5975090.00 N 634350.00 E 0.000 Vertical Section (ft) 4096.12 4194.28 4288.29 4292.44 4391.66 4464.02 4490.75 4526.93 4587.93 4684.88 4781.83 4878.77 4975.72 5013.71 5072.95 5133.00 5170.45 5266.54 5279.35 5360.53 5454.48 5548.44 5642.39 5736.35 5780.49 Alaska State Plane 4 PBU_WOA M Pad Comment Be_~in Dir ~ 10.000°/100ft: 11895.78ft'MD, 8792.62ft TVD Target - M-12A Wp06 T3, Geo"logical End Dir: 12137.07ft MD, 8792.77ft TVD Begin Dir ~. 10.000°ll00ft: 12639.19ft'MD, 8693.98ft TVD Taraet - M-12A Wp06 T4, Geo'logical End Dir: 12913.60ft MD, 8701.97ft TVD Total Depth: 13446.98ft MD, 8841.90ft TVD 4 1/2" Liner aerg, et ~ M.-12A Wp06 T5, ologlcal Continued... July, 2000. f2:ff .4 - DrillQuest f. OS.05a M-12A Ri_a Site Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Highest level of H2S recently measured on M Pad was 120 ppm on M-04. Note wind direction and Muster area for each tour. There is a risk of stuck pipe in the Kingak shale. Follow Prudhoe Bay recommended practice for safely drilling the Kingak shale to minimize this risk. 11.2 ppg mud will be used while drilling the Kingak to aid in well bore stability. Lost circulation risk is moderate while drilling the 6 1/8" section. The M-12a well bore will cross three faults. The third fault has the highest risk for severe losses. Reference the lost circulation decision tree for M-12a prior to crossing a predicted fault. Be prepared with LCM and adequate surface volume. Differential sticking will be a problem if loss circulation is occurring or if the drill string is left stationary for an extended period of time. The Sag River formation is expected to contained gas hydrocarbons. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Aurora S-101 Hazards and Contingencies Page ! of 1 ADMINISTRATION IIAP,PR .DATE. ENGINEERING COMPANY .~/~'~ INIT CLASS WELL NAME/f~" ! Z,~.' PROGRAM: exp ~.__~'~' f~.xJ/,~.J , GEOL AREA 1. Permit fee attached ........................ 2. Lease number appropriate.~:. ~¢'~--r.; ~/,~;. iL.'.'.7~-'~ //.0..".~/~/ . 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 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... 14. 15. 16. dev reddl serv v/ wellbore seg ~ UNIT# · -- ann. disposal para req ON/OFF SHORE .~ Y N~ Y N Y N GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... ' 31. Data presented on potential overpressure zones ...... ,..4 32. Seismic analysis of shallow gas zones ......... .~k)./'1 Y N APJ=.R DATE.,. 33. Seabed condition survey (if off-shore) ....... ~';.. Y N ~, ~.~3 ,.'Ct~)34. Contact name/phone for weekly progress rep.oj~exploratory only] Y N ~ AN~-ULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N 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 dive'rter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ........... 26. BOPE press rating appropriate; test to 735~,&3 Drag. 27. 28. ' ......... 29. Is presence of H2S gas probable .................. (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 GEOLOGY: ENGINEERING: U~/Annular COMMISSION: ~PPR DATE Comments/Instructions: J§ c:\msoffice\wordian~diana\checklist (rev. 02117100) ,,. 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 APPE .N. DIX~ No'special'effor~ has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Mar 12 12:11:29 2002 Reel Header Service name ............. LISTPE Date ..................... 02/03/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/03/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: M-12A 500292059301 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 12-MAR-02 MWD RUN 2 MWD RUN 4 MWD RUN 5 AK-MM-00219 AK-MM-00219 AK-MM-00219 R. KRELL R. KRELL M. HANIK T. ANGLEN T. ANGLEN J. RALL 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 6 AK-MM-00219 M. HANIK J. RALL MAD RUN 6 AK-MM-00219 M. HANIK J. RALL 1 liN 12E 2047 605 58.85 30.35 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) iST STRING 8.500 9.875 8670.0 2ND STRING 6.125 7.000 9628.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE File Header NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. MWD RUN 1 ROP DATA WERE MERGED TO THE TOP OF RUN 2 DATA. 4. MWD RUNS 2 - 6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR4). MWD RUN 6 ALSO INCLUDED STABILIZED LITHO-DENSITY (SLD) AND COMPENSATED THERMAL NEUTRON (CTN). NO DATA WERE ACQUIRED ON MWD RUN 3 DUE TO A FAILED CASING TEST. 5. MAD PASS DATA WERE ACQUIRED WHILE POOH AFTER REACHING THE FINAL TD. THE INTERVAL COVERED IS APPROXIMATELY 12800'MD - 12000'MD. 6. DIGITAL AND LOG DATA ONLY ARE SHIFTED TO THE SCHLUMBERGER CASED-HOLE WIRELINE GAMMA RAY LOG RUN ON 15 DECEMBER 2000. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. ALL 7. MWD RUNS 1-6 REPRESENT WELL M-12A WITH API$ 50-029-20593-01. THIS WELL REACHED A TOTAL DEPTH OF 13143'MD / 8834'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEX? = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED SPACING) SEMP = SMOOTHED SPACING) SEDP = SMOOTHED SPACING) SFXE = SMOOTHED RESISTIVITY TNPS = SMOOTHED MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SLIDE = NON-ROTATED INTERVALS SLDSLIDE = NON-ROTATED INTERVALS ACCOUNTING FOR SENSOR-TO-BIT DISTANCE AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125~' MUD WEIGHT: 8.4 PPG MUD SALINITY: 1200 PPM CHLORIDES FORMATION WATER SALINITY: 11,500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM PHASE SHIFT-DERIVED RESISTIVITY (DEEP FORMATION EXPOSURE TIME - DEEP THERMAL NEUTRON POROSITY (SANDSTONE Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 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 GR ROP RPX RPS FET RPD RPM NPHI NCNT FCNT PEF RHOB DRHO $ BASELINE CURVE FOR SHIFTS: START DEPTH 8662.5 8671.0 8672.0 8672.0 8672.0 8672.0 8672.0 11968 0 11968 0 11968 0 11982 0 11982 0 11982 0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8671.0 9448.5 9458.5 9480.0 9520.0 9541.5 9552 0 9558 5 9594 0 9629 0 9685 5 9688 5 9694 5 9749 0 9752 0 9756 5 9777 5 9784 5 9790 0 9798 0 9817 5 9821 0 9831 5 9834 0 9837 0 9839.5 9842.5 9860.5 9869.0 9875.5 9877.5 9879.5 9883.5 9888.5 9900.5 9908.0 9911.5 9921.5 9923.0 9933.0 GR 8669.5 9447.0 9455.0 9476.5 9516.0 9537.0 9547.0 9555.0 9593.5 9629.5 9685.0 9687.5 9695.5 9751 5 9753 5 9758 0 9779 5 9786 0 9791 5 9799 5 9817 5 9822 5 9831.5 9834.0 9837.5 9840.0 9842.5 9860.5 9869.5 9876,0 9878.0 9880.0 9884.0 9889.5 9900.5 9908.0 9911,5 9921.0 9922.5 9932.5 STOP DEPTH 13087.5 13143.0 13094.5 13094.5 13094.5 13094.5 13094,5 13050.0 13050.0 13050.5 13066.0 13066.0 13066.0 EQUIVALENT UNSHIFTED DEPTH 9948.0 9964.0 10021.5 10060.0 10112.5 10114.0 10117.5 10131.5 10139.5 10143 5 10150 5 10161 0 10202 0 10229 5 10243 0 10262 5 10279 0 10311 0 10319 0 10388 5 10407 5 10429 0 10437 5 10461 0 10478 0 10540 0 10546 0 10573 0 10580.5 10584,5 10598.5 10613.5 10642.0 10674.5 10717.5 10729.5 10737.0 10759.0 10795.5 10809.5 10818.0 10821.5 10836.0 10860.5 10889.5 10912.5 10916.0 10924.0 10976.5 10998 5 11004 5 11010 5 11060 5 11080 5 11122 5 11151 0 11163 5 11171 5 11190 5 11204 5 11214 0 11237 5 11239 5 11320 5 11323 5 11332,0 11335.0 11347.5 11376.5 11383.0 11403.0 11406.5 11416,5 11460.0 11494.0 11520.5 9947 9963 10021 10060 10111 10113 10116 10131 10138 10143 10149 10160 10200 10229 10241 10260 10278 10311 10319 10387 10405 10429 10436 10458 10475 10536 10542 10570 10580 10585 10599 10613 10641 10673 10713 10727 10733 10755 10792 10808 10815 10819 10833 10857 10884 10908 10912 10920 10972 10994 11000 11006 11057 11076 11119 11147 11159 11167 11187 11201 11212 11235 11238 11317 11320 11328 11332 11343 11373 11380 11398 11404 11413 11457 11490 11517 .0 .5 .0 .0 .5 .0 .0 5 0 0 0 0 0 5 0 5 5 0 .0 5 5 0 5 0 5 0 5 5 0 5 5 0 0 0 0 0 5 0 0 0 5 0 0 0 5 0 0 0 5 0 5 0 0 5 5 0 5 0 0 .0 .5 .5 .0 .5 .0 .5 .0 .5 .5 .5 .5 .5 .0 .5 .0 .0 11539.5 11550.5 11591.0 11671.0 11685.0 11767.5 11781.5 11802.0 11858.0 11876.5 11908.0 11933.0 11948.0 11964.5 11983.0 12008.5 12058.5 12102.5 12111.5 12136.5 12148.5 12230.0 12286.5 12320.0 12328.0 12349.5 12368.5 12386.5 12405.0 12426.5 12451.0 12537.5 12547.0 12579.5 12595.0 12632.0 12651,0 12653.0 12689.5 12695.0 12730.5 12753.0 12760.5 12765.0 12844.5 12867.5 12899.5 12921.0 12959.5 12969,5 13016.5 13030.5 13039.0 13143.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: 11536.0 11545.5 11587 0 11666 0 11682 5 11765 0 11778 5 11800 5 11854 5 11873 5 11903 0 11927 5 11944 0 11961 5 11980 5 12007 5 12055 5 12100 0 12109 0 12133 5 12145 5 12224 5 12280 0 12313 0 12323 0 12344 5 12362 5 12381 0 12400 5 12422 0 12445 0 12533 5 12542 0 12576 0 12591 5 12624 0 12644 0 12645 5 12682 0 12689 5 12724 5 12746 5 12754 0 12760 0 12838.5 12861.0 12892.0 12914.0 12953.0 12962.5 13010.0 13023.0 13033.0 13137.0 BIT RUN NO MERGE TOP MERGE BASE 2 8661.0 9628.5 4 9628.5 10733.0 5 10733.0 12817.0 6 12817.0 13137.0 MERGED MAIN PASS. $ 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 DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 8662.5 13143 ROP MWD FT/H 0.3 475.07 GR MWD API 16.09 580.6 RPX MWD OHMM 0.37 2000 RPS MWD OHMM 0.58 2000 R?M MWD OHMM 0.07 2000 RPD MWD OHMM 0.21 2000 FET MWD HOUR 0.5718 89.92 NPHI MWD PU-S 21.2 31.85 FCNT MWD CNTS 422.62 741.71 NCNT MWD CNTS 24766.3 31816.5 RHOB MWD G/CM 2.18 2.61 DRHO MWD G/CM -0.05 0.23 PEF MWD BARN 0.48 4.29 Mean 10902.8 46.5382 62.8826 30.5192 35.3861 44.243 58.6663 3.1489 26.4063 550.953 28125,3 2.30933 0.0570816 2.11035 First Reading For Entire File .......... 8662.5 Last Reading For Entire File ........... 13143 File Trailer Service name ............. STSLIB.001 Service Sub Level Name.., Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Nsam 8962 8945 8851 8846 8846 8846 8846 8846 2165 2166 2165 2169 2169 2169 First Reading 8662.5 8671 8662.5 8672 8672 8672 8672 8672 11968 11968 11968 11982 11982 11982 Last Reading 13143 13143 13087 5 13094 5 13094 5 13094 5 13094 5 13094 5 13050 13050.5 13050 13066 13066 13066 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 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 FCNT 11968.0 12756.5 NCNT 11968.0 12756.5 NPHI 11968.0 PEF 11982.0 DRHO 11982.0 RHOB 11982.0 GR 11992.5 FET 11999.0 RPD 11999.0 RPM 11999.0 RPS 11999.0 RPX 11999.0 RAT 12049.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ 12756.5 12774.0 12774 0 12774 0 12810 0 12800 5 12800 5 12800 5 12800 5 12800 5 12931 5 MAD RUN NO. MAD PASS NO. 6 1 REMARKS: MERGED MAD PASS. $ 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 DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 NPHI MAD PU-S 4 1 68 FCNT MAD CNTS 4 1 68 NCNT MAD CNTS 4 1 68 RHOB MAD G/CM 4 1 68 DRHO MAD G/CM 4 1 68 PEF MAD BARN 4 1 68 MERGE TOP 11965.0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 MERGE BASE 13137.0 Name Service Unit Min DEPT FT 11968 RAT MAD FT/H 0.43 GR MAD API 16.71 RPX MAD OHMM 14.15 RPS MAD OHMM 16.57 RPM MAD OHMM 19.49 RPD MAD OHMM 26,39 FET MAD HOUR 34.27 NPHI MAD ?U-S 21.2 FCNT MAD CNTS 427.53 NCNT MAD CNTS 24766.3 RHOB MAD G/CM 2.2 DRHO MAD G/CM -0,05 PEF MAD BARN 0.48 Max 12931.5 3069 93 141 29 37 43 41 22 53 04 63 04 76 34 31 85 741 71 31816.5 2.57 0.23 4.29 Mean 12449.8 366.623 34.2629 25. 6857 26.857 32.1867 40.6435 56,7536 26.5757 544.758 28023.9 2.30996 0.053653 2.0898 First Reading For Entire File .......... 11968 Last Reading For Entire File ........... 12931.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name.,. Nsam 1928 1765 1636 1604 1604 1604 1604 1604 1578 1578 1578 1585 1585 1585 First Reading 11968 12049.5 11992.5 11999 11999 11999 11999 11999 11968 11968 11968 11982 11982 11982 Last Reading 12931.5 12931.5 12810 12800.5 12800.5 12800.5 12800.5 12800.5 12756,5 12756.5 12756.5 12774 12774 12774 Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8661.0 9588.5 RPM 8670.5 9598.5 RPS 8670.5 9598,5 RPD 8670.5 9598.5 FET 8670.5 9598.5 RPX 8670.5 9598.5 ROP 8700.5 9628.5 $ LOG HEADER DATA DATE LOGGED: 19-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9628.0 TOP LOG INTERVAL (FT): 8700.0 BOTTOM LOG INTERVAL (FT): 9628.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 32.9 MAXIMUM ANGLE: 39.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01695HWGR6 EWR4 ELECTROMAG. RESIS. 4 PB01695HWGR6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 9628,0 BOREHOLE CONDITIONS MUD TYPE: LSND HT MUD DENSITY (LB/G): 11.20 MUD VISCOSITY (S): 41.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 3200 FLUID LOSS (C3): 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .940 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .453 161.0 MUD FILTRATE AT MT: 1.420 74.0 MUD CAKE AT MT: 1.220 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 8661 9628.5 ROP MWD020 FT/H 1 150.25 GR MWD020 API 45.48 235.09 RPX MWD020 OHMM 0.82 9.77 RPS MWD020 OHMM 0.82 8.62 RPM MWD020 OHMM 0.81 7.68 RPD MWD020 OHMM 0.87 6,59 FET MWD020 HOUR 0.7082 27.6038 First Reading For Entire File .......... 8661 Last Reading For Entire File ........... 9628.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Mean Nsam 9144.75 1936 35.2318 1857 110.561 1856 2.05689 1857 2.04072 1857 2.06062 1857 2.09139 1857 2.03665 1857 First Reading 8661 8700.5 8661 8670,5 8670.5 8670.5 8670.5 8670.5 Last Reading 9628.5 9628.5 9588.5 9598.5 9598.5 9598,5 9598.5 9598.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9589.0 10673.5 RPD 9599.0 10680.5 RPM 9599.0 10680.5 RPS 9599.0 10680.5 FET 9599.0 10680.5 RPX 9599.0 10680.5 ROP 9629.0 10733.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 25-OCT-00 Insite 65.41 Memory 10733.0 9628.0 10733.0 33.1 96.3 TOOL NUMBER PBO1706FGR4 PBO1706FGR4 6.125 QUIKDRIL-N 8.40 48.0 9.4 1500 7.3 1.950 72.0 1.007 145.8 2.200 72.0 2.100 72.0 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 ROP MWD040 GR MWD040 RPX MWD040 RPS MWD040 RPM MWD040 RPD MWD040 FET MWD040 FT FT/H API OHMM OHMM OHMM OHMM HOUR 68 68 68 68 68 68 68 68 0 4 8 12 16 20 24 28 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR Min 9589 0 98 18 26 0 37 0 58 0 07 0 21 0 86 Max 10733 410.39 554.56 1331.5 1370.48 2000 2000 89.92 First Reading For Entire File .......... 9589 Last Reading For Entire File ........... 10733 File Trailer Service name ............. STSLIB.004 Service Sub Level Name.., Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Mean 10161 42.7403 65,4276 21.1586 20.9324 39.1039 68.523 5.15279 Nsam 2289 2209 2170 2164 2164 2164 2164 2164 First Reading 9589 9629 9589 9599 9599 9599 9599 9599 Last Reading 10733 10733 10673.5 10680.5 10680.5 10680.5 10680.5 10680.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10674.0 12761,5 FET 10681.0 12768.5 RPD 10681.0 12768.5 RPM 10681.0 12768.5 RPS 10681.0 12768.5 RPX 10681.0 12768.5 ROP 10733.5 12817.0 $ LOG HEADER DATA DATE LOGGED: 29-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12817.0 TOP LOG INTERVAL (FT): 10733.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12817.0 80.1 99.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PBO1706FGR4 EWR4 ELECTROMAG. RESIS. 4 PBO1706FGR4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL-N MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 43.0 MUD PH: 8.3 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3): 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.200 MUD AT MAX CIRCULATING TERMPERATURE: .883 MUD FILTRATE AT MT: 2.600 MUD CAKE AT MT: 2.900 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 Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 65.0 172.0 65.0 65.0 Name Service Unit Min Max DEPT FT 10674 12817 ROP MWD050 FT/H 0.72 475.07 GR MWD050 API 16.09 580.6 RPX MWD050 OHMM 1.89 2000 RPS MWD050 OHMM 1.17 2000 RPM MWD050 OHMM 0.61 2000 RPD MWD050 OHMM 0,79 2000 FET MWD050 HOUR 0.6941 23.454 Mean 11745.5 48.6805 44.8248 47.5574 57.099 67.0768 80.9171 2.39072 Nsam 4287 4168 4176 4176 4176 4176 4176 4176 First Reading 10674 10733.5 10674 10681 10681 10681 10681 10681 Last Reading 12817 12817 12761.5 12768.5 12768.5 12768.5 12768.5 12768.5 First Reading For Entire File .......... 10674 Last Reading For Entire File ........... 12817 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPX RPS ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 12726.0 12726 0 12726 0 12741 0 12741 0 12741 0 12762 0 12769 0 12769 0 12769 0 12769 0 12769 0 12817 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 13044 0 13044 5 13044 0 13060 0 13060 0 13060 0 13081 5 13088 5 13088 5 13088 5 13088 5 13088 5 13137 0 30-OCT-00 Insite 65.41 Memory 13137.0 12817.0 13137.0 82.5 83.5 TOOL NUMBER PBO1692H4 PBO1692H4 PBO1692H4 PBO1692H4 6.125 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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.. Name Service Order Units DEPT FT ROP MWD060 FT/H GR MWD060 API RPX MWD060 OHMM RPS MWD060 OHMM RPM MWD060 OHMM RPD MWD060 OHMM FET MWD060 HOUR NPHI MWD060 PU-S FCNT MWD060 CNTS NCNT MWD060 CNTS RHOB MWD060 G/CM DRHOMWD060 G/CM PEF MWD060 BARN QU I KDRI L-N 8.40 44.0 10.0 1200 8.5 3.600 1.277 3.200 4.000 Size Nsam Rep Code Offset Channel 4 1 68 0 1 4 1 68 4 2 4 1 68 8 3 4 1 68 12 4 4 1 68 16 5 4 1 68 20 6 4 1 68 24 7 4 1 68 28 8 4 1 68 32 9 4 1 68 36 10 4 1 68 40 11 4 1 68 44 12 4 1 68 48 13 4 1 68 52 14 68.0 204.0 68.0 68.0 Name Service Unit Min DEPT FT 12726 ROP MWD060 FT/H 1.08 GR MWD060 API 19.77 RPX MWD060 OHMM 7.42 RPS MWD060 OHMM 8.53 RPM MWD060 OHMM 11,78 RPD MWD060 OHMM 17.91 FET MWD060 HOUR 0.5718 NPHI MWD060 PU-S 22.12 FCNT MWD060 CNTS 422.62 NCNT MWD060 CNTS 25900.8 RHOB MWD060 G/CM 2.18 DRHO MWD060 G/CM 0.02 PEF MWD060 BARN 0.74 Max Mean Nsam 13137 12931.5 823 210.78 82.502 640 104.84 33.4879 640 49.31 31.0797 640 61,73 38.6072 640 62.68 43.267 640 66.85 46,0265 640 25.9247 4.70861 640 31.52 26.0339 637 713.1 564,732 638 31049,6 28351.6 637 2.61 2.3095 639 0.18 0.0661033 639 3.79 2.1759 639 First Reading For Entire File .......... 12726 Last Reading For Entire File ........... 13137 First Reading 12726 12817.5 12762 12769 12769 12769 12769 12769 12726 12726 12726 12741 12741 12741 Last Reading 13137 13137 13081 5 13088 5 13088 5 13088 5 13088 5 13088 5 13044 13044.5 13044 13060 13060 13060 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 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 6 1 MAD RUN NUMBER: MAD PASS NUMBER: FiLE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI RHOB DRHO PEF GR RPX RPS RPM RPD FET RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 11965.0 12750.0 11965.0 12925.0 11965.0 12750.0 11979.5 12769.0 11979.5 12769.0 11979.5 12769.0 11990.5 12804.5 11997.5 12795.0 11997.5 12968.5 11997.5 12968.5 11997.5 12795.0 11997.5 12968.5 12047.0 12924.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 30-0CT-00 Insite 65.41 Memory 13137.0 13137.0 13137.0 82.5 83.5 TOOL NUMBER PBO1692H4 PBO1692H4 PBO1692H4 PBO1692H4 6.125 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 QUIKDRIL-N 8.40 44.0 10.0 1200 8.5 3.600 1.277 3.200 4.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD061 FT/H 4 1 68 4 2 GR MAD061 API 4 1 68 8 3 RPX MAD061 OHMM 4 1 68 12 4 RPS MAD061 OHMM 4 1 68 16 5 RPM MAD061 OHMM 4 1 68 20 6 RPD MAD061 OHMM 4 1 68 24 7 FET MAD061 HOUR 4 1 68, 28 8 NPHI MAD061 PU-S 4 1 68 32 9 FCNT MAD061 CNTS 4 1 68 36 10 NCNT MAD061 CNTS 4 1 68 40 11 RHOB MAD061 G/CM 4 1 68 44 12 DRHO MAD061 G/CM 4 1 68 48 13 PEF MAD061 BARN 4 1 68 52 14 68.0 204.0 68.0 68.0 Name Service Unit Min Max Mean Nsam DEPT FT 11965 12968.5 12466.8 2008 RAT MAD061 FT/H 0.43 3069.93 364.614 1756 GR MAD061 API 16.71 141.29 34.4375 1629 RPX MAD061 OHMM 14.15 37.43 25.7151 1596 RPS MAD061 OHMM 16.57 41.22 26.9923 1670 RPM MAD061 OHMM 19.49 53.04 32.3817 1670 RPD MAD061 OHMM 26.39 63.04 40.7104 1596 FET MAD061 HOUR 5.8947 76.3431 54.7186 1670 NPHI MAD061 PU-S 21.2 31.85 26.5753 1571 FCNT MAD061 CNTS 427.53 741.71 544.708 1572 NCNT MAD061 CNTS 24766.3 31881.4 28020.9 1571 RHOB MAD061 G/CM 2.2 2.57 2.3104 1580 DP. HO MAD061 G/CM -0.05 0.23 0.0535506 1580 PEF MAD061 BARN 0.48 4.29 2.09194 1580 First Reading For Entire File .......... 11965 Last Reading For Entire File ........... 12968.5 First Reading 11965 12047 11990.5 11997.5 11997.5 11997.5 11997.5 11997.5 11965 11965 11965 11979.5 11979.5 11979.5 Last Reading 12968.5 12924.5 12804.5 12795 12968.5 12968.5 12795 12968.5 12750 12925 12750 12769 12769 12769 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/03/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/03/12 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