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Home My WebLink About199-117CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Stephen Soroka To:Regg, James B (OGC) Cc:Stjohn, Kam P (OGC); Chris Casey - (C); Ryan Thompson; Alaska NS - Wells Integrity Subject:ATTENTION: Inspection Supervisor: MPJ-08 Deficiency Report, Incorect PTD# Date:Tuesday, November 25, 2025 5:17:32 PM Attachments:2025-1010_Deficiency_MPU_J-08A_ksj.pdf Mr. Regg, Kam and I discussed this at the end of October. It was immediately corrected with the correct PTD# 199-117. See attached picture and signed deficiency report. We will schedule a follow-up inspection this week. Please respond with any questions or concerns. Thank You Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey From: Stjohn, Kam P (OGC) <kam.stjohn@alaska.gov> Sent: Tuesday, November 25, 2025 4:18 PM To: Stephen Soroka <steve.soroka@hilcorp.com> Subject: [EXTERNAL] Fw: Suspended Well Inspection Follow-up - MPU J-08A Steve please see attached email 0LOQH3RLQW8QLW-$ 37' KCS Kam and I discussed this at the end of October immediately corrected Kam StJohn AOGCC Petroleum Inspector Cell 907 854-1501 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Tuesday, November 25, 2025 16:06 To: chris.casey@hilcorp.com <chris.casey@hilcorp.com> Cc: Stjohn, Kam P (OGC) <kam.stjohn@alaska.gov> Subject: Suspended Well Inspection Follow-up - MPU J-08A Inspector performed a suspended well inspection at MPU J-08A on 10/10/2025. My review indicates that the PTD # on the well sign is incorrect. Attached is the photo taken by our Inspector. PTD # should be 199-117 not 199-177. Attached is a Deficiency Report. Please sign and return when the well sign is corrected. A follow-up inspection will need to be scheduled once the sign is corrected. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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. MPU J-͏͗ϙ"ôƱèĖôĲèƅϙôŕĺŘťϙϼ"ϙ͖͐͐͐͘͘͏Ͻ Photos Courtesy of Hilcorp Alaska LLC Received 11/25/2025 ĖČĲôîϙ"ôƱèĖôĲèƅϙôŕĺŘť Corrected Well Sign From:Regg, James B (OGC) To:"chris.casey@hilcorp.com" Cc:Stjohn, Kam P (OGC) Subject:Suspended Well Inspection Follow-up - MPU J-08A Date:Tuesday, November 25, 2025 4:06:00 PM Attachments:2025-1010_MPU_J-08A_wellsign_ksj.jpg 2025-1010_Deficiency_MPU_J-08A_ksj.pdf Inspector performed a suspended well inspection at MPU J-08A on 10/10/2025. My review indicates that the PTD # on the well sign is incorrect. Attached is the photo taken by our Inspector. PTD # should be 199-117 not 199-177. Attached is a Deficiency Report. Please sign and return when the well sign is corrected. A follow-up inspection will need to be scheduled once the sign is corrected. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 038-$ 37' Location: Milne Point Unit J-08A Date: 10/10/2025 PTD: 1991170 Operator: Hilcorp Alaska LLC Type Inspection: Suspend Operator Rep: Chris Casey Inspector: Kam StJohn Position: Op. Phone: 907-242-1021 Correct by (date): 12/15/2025 Op. Email:chris.casey@hilcorp.com Follow Up Req'd: Yes Date Corrected Attachments: Operator Rep AOGCC Inspector Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Signatures: J. Regg for Kam StJohn; 11/25/2025 Photo (1) State of Alaska Oil and Gas Conservation Commission Deficiency Report *After signing, a copy of this form is to be left with the operator. Detailed Description of Deficiencies Incorrect PTD Number on Well Sign Revised 7/2019 Suspended Well Inspection – MPU J-08A (PTD 1991170) Photo by AOGCC Inspector K. StJohn 10/10/2025 Well sign has incorrect PTD # MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:28 Township:13N Range:10E Meridian:Umiat Drilling Rig:Rig Elevation:Total Depth:8,495 ft MD Lease No.:ADL0025906 Operator Rep:Suspend:X P&A: Conductor:13 3/8"O.D. Shoe@ 112 Feet Csg Cut@ na Feet Surface:9 5/8"O.D. Shoe@ 2516 Feet Csg Cut@ na Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ na Feet Production:7"O.D. Shoe@ 4,866 Feet Csg Cut@ na Feet Liner:4 1/2"O.D. Shoe@ 8,495 Feet Csg Cut@ na Feet Tubing:4 1/2 O.D. Tail@ 4,721 Feet Tbg Cut@ na Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Bridge plug 4,842 ft 4,740 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1620 1588 1570 1558 IA 1625 1591 1575 1564 OA 228 223 220 220 Continuation Initial 60 min 75 min 90 min Result Tubing 1558 1550 IA 1564 1555 OA 220 219 Remarks: Attachments: I traveled out to Milne Point Unit J-08A to witness a CMIT-TxIA pressure test and slickline (S/L) tag of a cement plug for suspension of the well. Steve Soroka was the Hilcorp rep.The wire-line string consisted of 15 feet of 1 7/8 inch roller stem, oil jars, spanges, 2 3/4 inch centralizer, and a 5-ft sample bailer. Hanging weight was 175lbs. Good solid tag of cement top @ 4,675 ft S/L (4,740 ft MD) . Sample bailer brought back mostly set-up cement chips with some softer interface up higher in the bailer. I ran the pressure test out for 60mins to confirm a PASS. October 29, 2025 Adam Earl Well Bore Plug & Abandonment MPU J-08A Hilcorp Alaska LLC PTD 1991170; Sundry 325-338 none Test Data: Casing Removal: Steve Soroka P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-1029_Plug_Verification_MPU_J-08A_ae                          Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/24/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251024 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BR 11-86 (REVISED) 50733207370000 225057 8/1/2025 HALLIBURTON RMT3D BRU 241-34T 50283201810000 220052 9/23/2025 AK E-LINE Perf END 2-36 50029220140000 190024 10/13/2025 READ Caliper Survey MPI 2-72 50029237810000 224016 10/2/2025 AK E-LINE Patch MPU I-01 50029220650000 190090 9/25/2025 AK E-LINE Punch MPU J-08A 50029224970100 199117 10/22/2025 HALLIBURTON COILFLAG MPU R-109 50029238220000 225073 9/24/2025 YELLOWJACKET SCBL NCIU A-06A 50883200260100 225071 9/25/2025 AK E-LINE CBL NCIU A-06A 50883200260100 225071 9/26/2025 AK E-LINE Perf PBU A-24B 50029207430200 225067 10/20/2025 HALLIBURTON RBT PBU GC-2E 50029227400000 197018 10/21/2025 HALLIBURTON TEMP PBU W-35A 50029217990200 225076 10/10/2025 HALLIBURTON RBT SP-03-NE2 50629236390000 219089 9/25/2025 AK E-LINE Caliper Please include current contact information if different from above. T41022 T41023 T41024 T41025 T41026 T41027 T41028 T41029 T41029 T41030 T41031 T41032 T41033 MPU J-08A 50029224970100 199117 10/22/2025 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.24 13:32:55 -08'00' Location: Milne Point Unit J-08A Date: 10/10/2025 PTD: 1991170 Operator: Hilcorp Alaska LLC Type Inspection: Suspend Operator Rep: Steve Soroka Inspector: Kam StJohn Position: Op. Phone: 907-242-1021 Correct by (date): 12/15/2025 Op. Email: steve.soroka@hilcorp.com Follow Up Req'd: Yes Date Corrected Attachments: Operator Rep AOGCC Inspector Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Signatures:J. Regg for Kam StJohn; 11/25/2025 Photo (1) State of Alaska Oil and Gas Conservation Commission Deficiency Report *After signing, a copy of this form is to be left with the operator. Detailed Description of Deficiencies Incorrect PTD Number on Well Sign Revised 7/2019 10/30/25 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 11/25/2025 InspectNo:susKPS251010131028 Well Pressures (psi): Date Inspected:10/10/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:6/24/2025 #325-338 Tubing:100 IA:300 OA:260 Operator:Hilcorp Alaska, LLC Operator Rep:Chris Casey Date AOGCC Notified:10/9/2025 Type of Inspection:Initial Well Name:MILNE PT UNIT J-08A Permit Number:1991170 Wellhead Condition Clean and no leaks, all gauges in good working order Surrounding Surface Condition Clean gravel with slight skiff of snow. Condition of Cellar Slight skif of snow dry gravel no standing water or sheen visable. There is a timber in the cellar that will need to be removed ove cellar is un covered Comments Location verified with Pad map. Supervisor Comments Photos (6) attached. Deficiency Notice sent to Hilcorp 11/25/2025 for incorrect PTD # on well sign; correct by 12/15/2025. Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, November 25, 2025           jbr; 11/25/2025 2025-1010_Suspend_MPU_J-08A_photos_ksj Page 1 of 3 Suspended Well Inspection – MPU J-08A PTD 1991170 AOGCC Inspection Rpt # susKPS251010131028 Photos by AOGCC Inspector K. StJohn 10/10/2025 Incorrect well sign – PTD # shows 199-177, should be 199-117 2025-1010_Suspend_MPU_J-08A_photos_ksj Page 2 of 3 2025-1010_Suspend_MPU_J-08A_photos_ksj Page 3 of 3 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Resevoir Abandonment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,495 NA Casing Collapse Conductor 1,130psi Surface 3,090psi Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT J-08A SCHRADER BLUFF OIL N/A 4,107 8,495 4,107 1,037 NA Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 7/1/2025 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025515, ADL0025517, ADL0025906 199-117 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22497-01-00 Hilcorp Alaska LLC C.O. 477B Length Size Proposed Pools: 112 112 12.6 / L-80 / BTC TVD Burst 4,721' MD 3,730psi 8,430psi 5,750psi 7,240psi 2,476 3,850 4,107 2,516 4,866 112 13-3/8" 9-5/8" 7" 2,516 4-1/2"3,766 4,866 Perforation Depth MD (ft): 8,495 See Schematic See Schematic 4-1/2" Baker ZXP Liner Top Packer w/ 6’ Tie Back and NA 4,714 MD / 3,810 TVD and N/A Ryan Thompson ryan.thompson@hilcorp.com 907-564-5280 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:01 am, Jun 03, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.06.02 16:16:30 - 08'00' Taylor Wellman (2143) 325-338 A.Dewhurst 20JUN25 DSR=6/3/25 * Initial well suspension for 60 months requires: 1. Slickline tag TOC ~4740' MD. 2. CMIT - TX IA to 1500 psi. * AOGCC witnessed well inspection within 12 months of initial suspension. Subsequent well inspection within 12 months before the 60 month renewal date. MGR20JUN2025 10-404 10-404 to include information required by 20 AAC 25.110 (f). *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.24 06:02:19 -08'00'06/24/25 RBDMS JSB 062425 Res P&A Well: MPU J-08A Date: 5/29/2025 Well Name: MPU J-08A API Number: 50-029-22497-01 Current Status: SI Producer Pad: J-Pad Estimated Start Date: 7/1/25 Rig: Eline/Coil Regulatory Contact: Tom Fouts Permit to Drill Number: 199-117 First Call Engineer: Ryan Thompson 907-564-5005 Second Call Engineer: Todd Sidoti 907-777-8443 AFE Number: Job Type: Res P & A Current Bottom Hole Pressure: 1,437 psi @ 4,000’ TVD (SBHP 3/2020 / 6.9 ppg EMW) MPSP: 1,037 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point J-08A well was redrilled as a Schrader Bluff development well that TD’d at 8,495’ and ran a bonzai slotted 4-1/2” liner in December 1999. The well was initially completed with an ESP in December 1999. In 2023, sundry 323-617 was approved to run a kill string and cement off the reservoir for I pad re-development. The ESP was pulled and a kill string ran on 12/16/23, the reservoir was cemented with a TOC tagged at 4,847’. The cement plug did not pass a required MIT and a LLR was established at 0.45 bbl min. Notes Regarding Wellbore Condition x Hole angle 72.9° @ 4,714’ MD at liner top. x Hole angle (horizontal) in liner starting at 5,949’ MD. x Reservoir cement plug in place, CMIT-TxIA fails with LLR of 0.45 bpm @ 1225 psi. Objective: To complete the reservoir abandonment with TOC in all annuli above ~4766’ MD per blue text in sundry 323-617. This 10-403 will finalize the reservoir abandonment began under sundry 323-617 (replace ESP, run kill string, pump reservoir cement) along with isolating the Ugnu with cement across all anulli ~100’ above the 7” casing shoe. A waiver to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area * No waiver required. Suspension approved for 5 years. - MGR Res P&A Well: MPU J-08A Date: 5/29/2025 Cementing History: 7” Production Casing The 7” production casing was ran during drilling of the MPJ-08 parent bore in 1994. The annulus was cemented with 220 sacks (45 bbls) of 15.8 ppg class G cement. The 7” casing shoe of MPJ-08 was set at 6131’ MD. With 30% washout that puts the cement top of the 7” x 8 ½” OH annulus at 4597’ MD (6131’ – 1534’). OD ID Annular Capacity Plus 30% Sacks Sacks / FT^3 Ft^3 BBLS Cement Height 8.5 7 0.022586 0.0293618 220 1.15 253 45.06 1534.69 4 ½” Liner The J-08A sidetrack liner completion ran in 1999 included 4 ½” solid liner from the liner hanger @ 4,729’ down to the cementing valve at 5775’ MD and was cemented with 14.5 bbls of cement behind pipe. Calculated volume up to the 7” shoe w/ no washout is 15.25 bbls meaning cement did not enter above the 7” casing shoe at 4866’ and into the 4 ½” x 7” annulus above the shoe. Procedure Eline 1. D&T top of cement (last tag @ 4847’ MD 2/17/25) 2. Set 4 ½” CIBP ~5’ above cement tag. 3. Perform liner punch of 4 ½” liner @ ~4750’. 4. Establish injectivity down the tubing (down open 4 ½” x 7” annulus) post punch up to 2500 psi. 5. Contingency – If injectivity is not established down the backside of the 4 ½” liner, punch 4 ½” liner 5’ above the CIBP (~4837’). Coil 1. RIH w/ GR/CCL, log liner from tag to above Liner hanger @ 4729’. 2. RIH w/ cementing nozzle. Mix 20 bbls of 15.8 ppg cement. 3. Tag CIBP @ ~4842’ 4. Lay in ~1.5 bbls of 14-15.8 ppg cement up to tubing punch @ 4750’. 5. Pull up to liner hanger @ 4729’. 6. Pump 6 bbls of 14-15.8 cement (>200% displacement of 4 ½” x 7” annulus to the 7” window) 7. Continue to pump cement attempting to obtain 1500 psi squeeze pressure on the annulus/open hole cement. 8. Once squeeze pressure is obtained clean out to 10’ above the liner punch holes at 4740’. 9. Contingency – If a second set of liner punches is performed by eline (~4837’) due to lack of injectivity into the 4 ½” x 7” shoe, lay in balanced plug from top of CIBP to 10’ above top liner punch at 4750’, allowing fluids to swap. Volume of 15.8 ppg cement is ~4.5 bbls. Leaving cement top in the liner at 4740’. Slickline/Fullbore 1. After 3 days, D&T TOC @ 4740’ – AOGCC Witness 2. After 3 days, CMIT-TxI to 1500 psi – AOGCC Witness Res P&A Well: MPU J-08A Date: 5/29/2025 Attachments: 1. Liner Tally 2. As-built Schematic 3. Proposed Schematic Res P&A Well: MPU J-08A Date: 5/29/2025 _____________________________________________________________________________________ Revised By: TDF 5/29/2025 SCHEMATIC Milne Point Unit Well: MPU J-08A Last Completed: 12/16/2023 PTD: 199-117 TD =8,495’ (MD) / TD =4,107’(TVD) 13-3/8” Orig. KB Elev.: 65.2’/ GL Elev.: 35.7’(N22E) 7”3 9-5/8” 4 5 6 PBTD =8,495’ (MD) / PBTD =4,107’(TVD) 4-1/2” Horiz. Slotted Liner Milled 6-1/8” Window @ 4,866’ to 4,880’ (14’) 1 2 Top of Cement @ 4,847 SLM Top of Cement @ 4,597’ Calculated CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / L-80 / N/A 12.615 0 112’ 9-5/8" Surface 40 / L-80 / Btrc. 8.835 0 2,516’ 7" Intermediate 26 / L-80 / Btrc 6.276 0 4,866’ 4-1/2” Liner 12.6 / L-80 / IBT 3.958 4,729’ 8,495’ 4-1/2” Slotted Liner 6.2 / L-80 / SLT 3.958 5,901’ 8,451’ TUBING DETAIL 4-1/2” Tubing 12.6/ L-80 / BTC 3.958 Surf 4,721’’ JEWELRY DETAIL No Depth Item 1 4,688’’ Wireline Entry Guide (Btm at 4,721’) (3.958” ID) 2 4,729’ Baker 5” x 7” HMC Liner Hanger (4.375” ID) 3 5,776’ Baker HMCV Cement Valve 4 5,794’ Baker CTC 20’ PZP ECP 5 8,451’ 4.5” Baker Drillable Pack-off Bushing 6 8,495’ 4.5” Baker Drillable Guide Shoe OPEN HOLE / CEMENT DETAIL 13-3/8”" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 504sx PF “E”, 250 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 220 sx Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 84 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,500’ Max Hole Angle = Horizontal TREE & WELLHEAD Tree 4-1/8” 5M Wellhead WKM 11” x 11” 5M, WKM w/ 11” x 4-1/2” tubing hanger/ 8RD threads top and bottom and 4” Back Pressure Valve Profile GENERAL WELL INFO API: 50-029-22497-01-00 Sidetracked & Completed by Nabors 22E - 12/29/1999 Recompletion –1/28/2000 Schrader Bluff Recompletion by Nabors 4ES –4/19/1997 ESP Replacement by Nabors 3S –2/11/2007 ESP Change-out by Nordic #3 –7/5/2015 ESP Change-out by ASR #1 –10/3/2015 Install Kill String by ASR –12/16/2023 _____________________________________________________________________________________ Revised By: TDF 5/29/2025 PROPOSED Milne Point Unit Well: MPU J-08A Last Completed: 12/16/2023 PTD: 199-117 TD =8,495’ (MD) / TD =4,107’(TVD) 13-3/8” Orig. KB Elev.: 65.2’/ GL Elev.: 35.7’(N22E) 7”4 9-5/8” 5 6 7 CIBP @ ±4,842’ PBTD =8,495’ (MD) / PBTD =4,107’(TVD) 4-1/2” Milled 6-1/8” Window @ 4,866’ to 4,880’ (14’) 1 2 Top of Cement @ 4,847 SLM Top of Cement @ 4,597’ Calculated Tubing Punch Top ±4,750’ 3 TOC @ 4,740’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / L-80 / N/A 12.615 0 112’ 9-5/8" Surface 40 / L-80 / Btrc. 8.835 0 2,516’ 7" Intermediate 26 / L-80 / Btrc 6.276 0 4,866’ 4-1/2” Liner 12.6 / L-80 / IBT 3.958 4,729’ 8,495’ 4-1/2” Slotted Liner 6.2 / L-80 / SLT 3.958 5,901’ 8,451’ TUBING DETAIL 4-1/2” Tubing 12.6/ L-80 / BTC 3.958 Surf 4,721’’ JEWELRY DETAIL No Depth Item 1 4,688’’ Wireline Entry Guide (Btm at 4,721’) (3.958” ID) 2 4,729’ Baker 5” x 7” HMC Liner Hanger (4.375” ID) 3 ±4,842’ CIBP 4 5,776’ Baker HMCV Cement Valve 5 5,794’ Baker CTC 20’ PZP ECP 6 8,451’ 4.5” Baker Drillable Pack-off Bushing 7 8,495’ 4.5” Baker Drillable Guide Shoe OPEN HOLE / CEMENT DETAIL 13-3/8”" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 504sx PF “E”, 250 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 220 sx Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 84 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,500’ Max Hole Angle = Horizontal TREE & WELLHEAD Tree 4-1/8” 5M Wellhead WKM 11” x 11” 5M, WKM w/ 11” x 4-1/2” tubing hanger/ 8RD threads top and bottom and 4” Back Pressure Valve Profile GENERAL WELL INFO API: 50-029-22497-01-00 Sidetracked & Completed by Nabors 22E - 12/29/1999 Recompletion –1/28/2000 Schrader Bluff Recompletion by Nabors 4ES –4/19/1997 ESP Replacement by Nabors 3S –2/11/2007 ESP Change-out by Nordic #3 –7/5/2015 ESP Change-out by ASR #1 –10/3/2015 Install Kill String by ASR –12/16/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for:MILNE PT UNIT J-08A MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Remarks:2 7/8" and 4.5" test joints used for testing. Test #2 on a low was slowly bleeding off. Bled off and purged air out of the system. Started test again and cmv #10 was found to be leaking by. Started test again using cmv #7 in place of cmv#10 for a pass. CMV#10 was serviced and tested in test #3. CMV #11 failed. Service valve and retest for a pass on test #3. Test #10 a test fitting started leaking on the high. Tightened fitting and went back to the high for a pass. Test Results TEST DATA Rig Rep:C. Pace/J. WerlingerOperator:Hilcorp Alaska, LLC Operator Rep:S. Heim/R. Gallen Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1991170 DATE:12/14/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC231212225903 Inspector Guy Cook Inspector Insp Source Related Insp No:BOPOP000011095 INSIDE REEL VALVES Quantity P/F (Valid for Coil Rigs Only) Test Time:6 MASP: 1037 Sundry No: 323-617 Control System Response Time (sec): P/FTime Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11" 5000 P #1 Rams 1 2 7/8" x 5"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 500 P HCR Valves 1 2 1/16" 500 P Kill Line Valves 3 2 1/16" 500 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1700 200 PSI Attained P15 Full Pressure Attained P62 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2312 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P13 #1 Rams P7 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0 JBR; 4-4-2024       REVISED Well Name revised from J-08 to J-08A Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/6/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240306 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-19RD 50133205790100 219188 12/9/2023 AK E-LINE CBL BRU 232-09 50283200750000 184136 10/30/2023 AK E-Line PT/CALIPER MPU B-19A 50029214510100 223123 2/26/2024 HALLIBURTON Jewelry Log MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag PBU N-11D 50029213750300 223083 2/13/2024 HALLIBURTON RBT Please include current contact information if different from above. T38597 T38598 T38599 T38600 T38601 T38602 MPU J-08A 50029224970100 199117 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.06 12:00:22 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp KBU 42-6 50133205460000 204209 2/23/2024 HALLIBURTON PPROF KU 31-07X 50133204950000 200148 2/2/2024 HALLIBURTON PressTemp MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Please include current contact information if different from above. T38535 T38536 T38537 T38538 T38539 T38540 T38541 T38542 T38543 2/29/2024 MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 09:17:32 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/8/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-08 50133203040000 177029 10/11/2023 AK E-LINE TUBING CUT KBU 14-6Y 50133205720000 207149 10/24/2023 AK E-Line PLUG/PERF MPU B-28 50029235660000 216027 1/10/2024 HALLIBURTON MFC40 MPU F-65 50029227520000 197049 1/19/2024 HALLIBURTON MFC40 MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag Please include current contact information if different from above. T38488 T38489 T38490 T38491 T38492 T38493 2/8/2024 MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.08 10:05:37 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Resevoir Abandonment 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,495 NA Casing Collapse Conductor 1,130psi Surface 3,090psi Intermediate Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker ZXP Liner Top Packer w/ 6’ Tie Back and NA 4,714 MD / 3,810 TVD and N/A NA 4,8664,866 4-1/2" See Schematic 907-564-5277 brian.glasheen@hilcorp.com Wells Manager November 30, 2023 8,4953,766 2-7/8" 4,107 Perforation Depth MD (ft): See Schematic 3,8507" 9-5/8"2,516 3,730psi 5,750psi2,4762,516 SCHRADER BLUFF OIL Same 112 112 6.5# / L-80 TVD Burst 4,602 7,240psi MD 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22497-01-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 4,107 8,495 4,107 1,037 Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025515, ADL0025517, ADL0025906 199-117 C.O. 477.05 MILNE PT UNIT J-08A Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,430psi Tubing Grade: 112 13-3/8" Brian Glasheen Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.11.15 07:51:21 - 09'00' Taylor Wellman (2143) 323-617 1,037 MGR07DEC23 * BOPE test to 2500 psi. * AOGCC witness tag and pressure test of cement plug to 1500 psi. * 10-407 required within 30 days of suspension. * AOGCC witnessed inspection within 12 months of the approved suspension. 10 day notice to AOGCC. * Provide 10 day notice for opportunity to witness second well site inspection 12 months prior to 31-DEC-25 * 10-404 for both inspection reports. * Waiver approved for incomplete reservoir abandonment. Future well work will either re-enter reservoir from existing reservoir penetration or additional cement will be required to isolate reservoir at the SB confining zones. DSR-11/15/23 December 31, 2025 10-407 SFD 12/1/2023 By Grace Christianson at 10:16 am, Dec 07, 2023 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.12.08 08:12:57 -09'00'12/08/23 RBDMS JSB 120823 Res P&A Well: MPU J-08A Date: 10/17/2023 Well Name:MPU J-08A API Number:50-029-22497-01 Current Status:SI Oil Well [ESP]Pad:J-Pad Estimated Start Date:11/30/2023 Rig:ASR #1 Coil Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:199-117 First Call Engineer:Brian Glasheen 907-545-1144 Second Call Engineer: AFE Number:Job Type:Res P & A Current Bottom Hole Pressure: 1,437 psi @ 4,000’ TVD (SBHP 3/2020 / 6.9 ppg EMW) Maximum Expected BHP: 1,437 psi @ 4,000’ TVD (No new perfs being added) MPSP: 1,037 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point J-08A well was redrilled as a Schrader Bluff development well that TD’d at 8,495’ and ran a slotted 4-1/2” liner in December 1999. The well was initially completed with an ESP in December 1999. ESP is currently dead and J-08 is cross cutting acreage that is being redeveloped at I pad in 2024. Notes Regarding Wellbore Condition x Hole angle 72.9° @ 4,714’ MD at liner top. x Hole angle (horizontal) in liner starting at 5,949’ MD. x 2017 SL pulled St1 GLV left open, DMY St2 GLV Objective: Is to pull ESP, install kill sting and perform a Res P&A with coil to support 2024 I pad drilling. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area Slickline - 1. SBHP Well Support- 2. Clear and level pad area in front of well. Spot rig mats and containment. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.4 ppg produced water or source water down tubing, taking returns up casing to 500 bbl returns tank. Heat fluids to help with thick crude prior to circulating. a. If returns are not seen, after attempting circulation down the tubing, bullhead and load the tubing, IA. 6. RD Little Red Services and reverse out skid. 7. RU crane. Set CTS BPV. ND Tree. NU BOPE. RD Crane. 8. NU BOPE house. Spot mud boat. - Waiver to 20 AAC 25.110 (c) (2) as the reservoir is only partially secured for future drilling. A 2 year suspension will be approved to allow Hilcorp to either fully abandon the SB reservoir in compliance to AOGCC regulation or re-enter the SB in a way that injector/producer conformance is not compromised. - mgr Hydrocarbons incompletely isolated. mgr waiver HC will evaluate a recomplete on J-08 to a vertical injector and or producer in the future. A future RWO would be submitted to recomplete as a vertical well. Well is also a candidate for possible CTD in the future. per Brian Glasheen email 11-15-23 Res P&A Well: MPU J-08A Date: 10/17/2023 Brief RWO Procedure Sundry work: 9. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines. 10. Check for pressure. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.4 produced water/ Source water prior to setting CTS Plug. Set CTS Plug. 11. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8’’ test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 12. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 13. Bleed any pressure off tubing and casing to the returns tank. Pull CTS, lubricate if pressure expected. Kill well as needed. 14. MU landing joint or spear and BOLDS. 15. Well is a live well and hole fill needs to be managed the entire job. If well will hold a column of fluid establish hole fill rate to see fluid at surface at all times, If well will not surface fluid due to low bottom hole pressure maintain a hole fill and double pipe displacement when POOH. 16. Attempt to pull tubing. a. PU weight 2015 RWO was 43k SO was 41K b. Do not exceed 80 percent of 2-7/8” tubing. c. Heat trace down to 2992’ MD 17. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 18. POOH and lay down the 2-7/8’’ tubing. Rig up spooler for TEC cable and heat trace. a. Inspect the Tubing and place good joints into inventory. 19. PU new 4-1/2’’ kill string with WLEG and RIH to ~4700’ MD. Res P&A Well: MPU J-08A Date: 10/17/2023 20. Pump 74 bbls of diesel down the tubing, rig up jumper hose to IA and allow FP to swap 21. Set CTS. 22. RDMO ASR. Post-Rig Procedure: 23. RD mud boat. RD BOPE house. Move to next well location. 24. RU crane. ND BOPE. 25. NU tree and tubing head adapter. 26. Test both tree and tubing hanger void to 500psi low/5,000psi high. 27. Pull CTS. 28. RD crane. Move 500 bbl returns tank and rig mats to next well location. Coil Cement P&A Procedure: Objective The objective of this procedure is to cement the entire liner including the annular space between the 4- 1/2” liner and openhole. Notes x There is 2550’ of openhole behind the 4-1/2” slotted liner. This equates to approximately 43.0 bbls of liner annulus and 39 bbls of internal liner volume. x Job is designed as a pump till you bump operation. The high level plan will be to lay in cement from TD to 5500’ MD with the choke closed. When the nozzle gets to 5500’, the cement will continue to be down squeezed until all the cement is pumped or a 1000 psi squeeze is achieved. x Plan to have ~130 bbls of powervis contaminate on location given the large volume of cement that may need to be contaminated. Cement Design BHST – 75 deg F. SBHP – 1437 psi. BHCT – 75 deg F Cement: Class G Mix on the fly. Density: 8.6 ppg Thickening time: 10-12 hrs. API Fluid Loss: 160-240. (80-120 cc/30 min) Free Water: 0 Compressive Strength: Minimum of 2000 psi Filter Cake: 0.75”-1.0” Requested Volume: 120 bbls Cement Ramp 1 hr to mix 2 hr pump time 0.5 hr to get to safety and prepare for squeeze. 1 hr pressure up to squeeze 75F 1 hr to hold squeeze. 75F See altnate proposed cement design included at the end of this sundry. Approved to pump a 12.5 ppg cement slurry, NOT an 8.6 ppg slurry. -mgr * Schrader Bluff reservoir isolation incomplete. Future sidetrack or future re-entry will require re-entry of reservoir below SB confining zones or additional cement isolation across the SB confining zones to secure the reservoir. -mgr Res P&A Well: MPU J-08A Date: 10/17/2023 2 hrs to finish contamination pass. 75F 2 hr for contingency. Planned Procedure 1. MU and RIH with GR/CCL in a carrier with a 3.0” OD nozzle. 2. RIH and tag TD. Log from TD to 4700’ MD. Flag pipe. 3. POOH Cement Squeeze 4. Load tubing with 104 bbls of 1% KCl followed by 61 bbls of diesel for underbalance(Assuming 1.75’’ coil we will be very close with res pressure at 1437 psi) 5. RIH with Nozzle ( WSL and OE discretion) and dry tag TD. 6. PUH 5’ and flag pipe. 7. Note the WHP with CT parked and no pumping. This is the static baseline WHP. 8. With choke closed begin pumping 8.6 ppg cement. Note the WHP before cement reaches the nozzle, this is the baseline injecting WHP. 9. When cement reaches nozzle, allow 1 bbl to get around nozzle (choke can remain closed) and begin PUH, laying in cement with choke closed from TD to 5500’ MD. PUH at 100%. ie 1.0 bpm and ~66 fpm. Adjust rate and speed accordingly 1. It is recognized that the nozzle may outrun the cement depending on the cement exit point in the well, regardless, it is still preferable to lay in as much cement as possible rather than downsqueezing the entire volume. 10. With nozzle at 5500’ MD, park CT and continue to pump cement with the choke closed until either 1) 20 bbls of cement remains in the CT or 2) a 1000 psi squeeze (over baseline injecting WHP) has been achieved. Once CT is parked, try and maintain as high a pump rate as possible when downsqueezeing. The hope is that the higher the rate, the better the cement coverage. If 1000 psi squeeze is achieved 11. Cut cement at surface, open choke, and lay in remaining cement in the tubing 1:1. 12. With nozzle at safety, continue displacing cement into well until cement top is at ~5000’ MD or until 2000 psi squeeze (over baseline static WHP) has been achieved. 13. Hold final squeeze pressure for 60 mins. 14. Drop ball and clean out cement back down to 5000’ with powervis. Plan to have at least 130 bbls of powervis contaminate on location. 1. Keep choke pressure at ~50-75 psi above baseline WHP. 15. With nozzle at 5000’ MD, slick 1% KCl should be at the nozzle. Proceed with chasing cement OOH at 80%. 16. FP well to 2500’ MD. Leave 300 psi on tbg. If 1000 psi squeeze is not achieved. 17. If after pumping all cement on location, 1000 psi bump is not achieved, open choke and lay in remaining 20 bbls of cement in the liner, 1:1, and PUH to safety. 18. With nozzle at safety, perform a hesitation squeeze over the course of 60 minutes until cement has been down squeezed to ~5000’ MD. 19. Hold final squeeze pressure for 60 mins (if time allows). Res P&A Well: MPU J-08A Date: 10/17/2023 20. POOH and leave 300 psi on tbg. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Coil BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 11/8/2017 SCHEMATIC Milne Point Unit Well: MPU J-08A Last Completed: 10/3/2015 PTD: 199-117 TD =8,495’ (MD) / TD =4,107’(TVD) 13-3/8” Orig. KB Elev.: 65.2’/ GL Elev.: 35.7’ (N22E) 7” 3 5 6 7 9 10 11 12 13 9-5/8” 1 2 14 15 16 PBTD =8,495’(MD) / PBTD =4,107’(TVD) 4 Heat Trace @ 2,992’ 4-1/2” Horiz. Slotted Liner Milled 6-1/8” Window @ 4,866’ to 4,880’ (14’) 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / L-80 / N/A 12.615 0 112’ 9-5/8" Surface 40 / L-80 / Btrc. 8.835 0 2,516’ 7" Intermediate 26 / L-80 / Btrc 6.276 0 4,866’ 4-1/2” Liner 12.6 / L-80 / IBT 3.958 4,729’ 8,495’ 4-1/2” Slotted Liner 6.2 / L-80 / SLT 3.958 5,901’ 8,451’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 0 4,602’ JEWELRY DETAIL No Depth Item 1 174’ GLM – 1” DGLV BK LATCH 9/22/17 2 4,395’ GLM ***PULLED 1” GLV AND LEFT EMPTY – 10/30/17*** 3 4,537’ 2-7/8” XN Nipple – 2.313 ID: 2.205 no-go 4 4,548.7’ Discharge Head 5 4,549’ Pump 6 4,573’ Gas Separator 7 4,578’ Upper Tandem Seal Section 8 4,585’ Lower Tandem Seal Section 9 4,592’ Motor 10 4,600’ Centralizer/Downhole Gauge:Bottom @ 4,602’ 11 4,714’ Baker ZXP Liner Top Packer w/ 6’ Tie Back (5.25” ID) 12 4,729’ Baker 5” x 7” HMC Liner Hanger (4.375” ID) 13 5,776’ Baker HMCV Cement Valve 14 5,794’ Baker CTC 20’ PZP ECP 15 8,451’ 4.5” Baker Drillable Pack-off Bushing 16 8,495’ 4.5” Baker Drillable Guide Shoe OPEN HOLE / CEMENT DETAIL 13-3/8”" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 504sx PF “E”, 250 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 220 sx Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 84 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,500’ Max Hole Angle = Horizontal TREE & WELLHEAD Tree 3-1/8” CIW 5M Wellhead WKM 11” x 11” 5M, WKM w/ 11” x 3.5” tubing hanger/ NSCT threads top and bottom and 3” CIW H PBV Profile GENERAL WELL INFO API: 50-029-22497-01-00 Sidetracked & Completed by Nabors 22E - 12/29/1999 Recompletion – 1/28/2000 Schrader Bluff Recompletion by Nabors 4ES – 4/19/1997 ESP Replacement by Nabors 3S – 2/11/2007 ESP Change-out by Nordic #3 – 7/5/2015 ESP Change-out by ASR #1 – 10/3/2015 _____________________________________________________________________________________ Revised By: DH 11/10/2023 PROPOSED Milne Point Unit Well: MPU J-08A Last Completed: 10/3/2015 PTD: 199-117 TD =8,495’ (MD) / TD =4,107’(TVD) 13-3/8” Orig. KB Elev.: 65.2’/ GL Elev.: 35.7’ (N22E) 7”3 9-5/8” 4 5 6 PBTD =8,495’(MD) / PBTD =4,107’(TVD) 4-1/2” Horiz. Slotted Liner Milled 6-1/8” Window @ 4,866’ to 4,880’ (14’) 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 54.5 / L-80 / N/A 12.615 0 112’ 9-5/8" Surface 40 / L-80 / Btrc. 8.835 0 2,516’ 7" Intermediate 26 / L-80 / Btrc 6.276 0 4,866’ 4-1/2” Liner 12.6 / L-80 / IBT 3.958 4,729’ 8,495’ 4-1/2” Slotted Liner 6.2 / L-80 / SLT 3.958 5,901’ 8,451’ TUBING DETAIL 4-1/2” Tubing 12.6/ L-80 / EUE 2.867 Surf 3000’ JEWELRY DETAIL No Depth Item 1 4,722’ Wireline Entry Guide (Btm at 4,723’) (2.875” ID); Buried 9’ inside liner top 2 4,729’ Baker 5” x 7” HMC Liner Hanger (4.375” ID) 3 5,776’ Baker HMCV Cement Valve 4 5,794’ Baker CTC 20’ PZP ECP 5 8,451’ 4.5” Baker Drillable Pack-off Bushing 6 8,495’ 4.5” Baker Drillable Guide Shoe OPEN HOLE / CEMENT DETAIL 13-3/8”" Cmt w/ 250 sx of Arcticset I in 24” Hole 9-5/8" Cmt w/ 504sx PF “E”, 250 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 220 sx Class “G” in 8-1/2” Hole 4-1/2” Cmt w/ 84 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,500’ Max Hole Angle = Horizontal TREE & WELLHEAD Tree Cameron 3-1/8” 5M Wellhead WKM 11” x 11” 5M, WKM w/ 11” x 3-1/2” tubing hanger/ 8RD threads top and bottom and 3” CIW H PBV Profile GENERAL WELL INFO API: 50-029-22497-01-00 Sidetracked & Completed by Nabors 22E - 12/29/1999 Recompletion – 1/28/2000 Schrader Bluff Recompletion by Nabors 4ES – 4/19/1997 ESP Replacement by Nabors 3S – 2/11/2007 ESP Change-out by Nordic #3 – 7/5/2015 ESP Change-out by ASR #1 – 10/3/2015 100’ of continuous cement across all annuli 100’ above/into the 7” casing shoe for future final reservoir abandon with TOC ~4766' MD post suspension status. This suspension does not isolate the hydrocarbon bearing Ugnu with cement across all annuli -mgr Milne Point ASR Rig 1 BOPE 2018 Updated 5/14/2018 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head SLB Stack Drawing Not Drawn To Scale--- For Reference Only BOP rams dressed for 1.75" Coiled Tubing. Blind/Shear ram blades: Texas Oil Tools NOV – 4.06" Shear seal Rams w/ Viton Seals, H2S -50F Flanged Plug Valve (Manual) Flanged Plug Valve (Manual) Kill Port Manual ram locking wheel CT BOP’s controlled by Coiled Tubing Unit with ~100 gal accumulator system Well Floor HR 580 Injector Head with 72" Gooseneck 4.06" 10K Top Door Stripper – 1.75" Swab Valve 4.06" 10K Quad BOP C/W 2.06" 10K Flanged Plug Valves x 2" 1502 SSV 5K x 10K C062/CB44 Crossover Master Valve 7.06" 5K /4.06"10K Lubricator Section (Manual)(Manual) Slip & Pipe Ram dressed with 1.75" Inserts IA and OA Gate Valves Blind & Shear Ram Slip Ram Kill Port Blind & Shear Ram Pipe Ram Pump In Sub with 2 Flanged Gate Valves 2' 10K to 5K Crossover Provided by client Lab report was generated and approved by Bryce Hinsch (H262692) 06/Dec/2023 20:29. This report is the property of Halliburton Energy Services and neither it nor any part thereof, nor a copy thereof, is to be published or disclosed without first securing the expressed written approval of Halliburton. It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton. This report is for information purposes only and the content is limited to the sample described. Halliburton makes no warranties, expressed or implied, as to the accuracy of the contents or results. Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause, including any act or omission of Halliburton, resulting from the use hereof. Global Customer Report Page 1 of 2 Lab Results-TailWest Coast, Prudhoe Bay Job Information Request/Slurry 2757293/2 Rig Name Date 10/AUG/2022 Submitted By Bryce Hinsch Job Type Bulk Plant Prudhoe Bay, AK USA Customer Halliburton Location Well Well Information Casing/Liner Size Depth MD 1052 m / 3450 ft BHST 18°C / 65°F Hole Size Depth TVD BHCT 16°C / 60°F Pressure 138 bar / 2000 psi Cement Information - Tail Design Cement Properties Slurry Density 12.5 lbm/gal Slurry Yield 1.75 ft3/sack Water Requirement 7.46 gal/sack Pilot Test Results Request ID 2757293/2 Mixability (0 - 5) - 0 is not mixable, Request Test ID:39159076 12/AUG/2022 Mixability rating (0 - 5)Avg rpm mixing under load (~12,000) 5 12000 API Rheology, Request Test ID:39159080 12/AUG/2022 Temp (degF) 300 200 100 60 30 6 3 Cond Time (min) Cond Temp (degF) Foam Quality (%) 60 (up)179 147 113 99 89 63.6 43.2 40 60 0 60 (down)179 149 116 104 94 88 86.2 40 60 0 60 (avg.)179 148 115 102 92 76 65 40 60 0 PV (cP) & YP (lbs/100ft2): 107.39 79.72 (Least-squares method) PV (cP) & YP (lbs/100ft2): 96.75 82.25 (Traditional method (300 & 100 rpm based)) Generalized Herschel-Bulkley 4: YP(lbf/100ft2)=67.18 MuInf(cP)=47.03 m=0.59 n=0.59 API Rheology, Request Test ID:39159081 12/AUG/2022 Temp (degF)300 200 100 60 30 6 3 Foam Quality (%) 70 (up)102 77 49 46 44 40.2 33.5 0 70 (down)102 94 73 65 58 57.2 57.8 0 70 (avg.)102 86 61 56 51 49 46 0 PV (cP) & YP (lbs/100ft2): 56.88 48.14 (Least-squares method) PV (cP) & YP (lbs/100ft2): 61.5 40.5 (Traditional method (300 & 100 rpm based)) Generalized Herschel-Bulkley 4: YP(lbf/100ft2)=48.13 MuInf(cP)=56.89 m=1 n=1 Free Fluid API 10B-2, Request Test ID:39159078 12/AUG/2022 Con. Temp (degF)Con. Pr. (psi)Cond. Time (min)Static T. (F)Static time (min)Incl. (deg)% Fluid 60 14.7 40 60 120 45 0 API Fluid Loss, Request Test ID:39159079 03/NOV/2022 Test Temp (degF)Test Pressure (psi)Test Time (min)API FL (cc/30 min)Meas. Vol.Conditioning time (min) Conditioning Temp (degF) 60 1000 30 30 15 40 60 Lab report was generated and approved by Bryce Hinsch (H262692) 06/Dec/2023 20:29. This report is the property of Halliburton Energy Services and neither it nor any part thereof, nor a copy thereof, is to be published or disclosed without first securing the expressed written approval of Halliburton. It may however be used in the course of regular business operations by any person or concern receiving such report from Halliburton. This report is for information purposes only and the content is limited to the sample described. Halliburton makes no warranties, expressed or implied, as to the accuracy of the contents or results. Any user of this report agrees Halliburton shall not be liable for any loss or damage regardless of cause, including any act or omission of Halliburton, resulting from the use hereof. Global Customer Report Page 2 of 2 Thickening Time - ON-OFF-ON, Request Test ID:39439085 19/DEC/2022 Test Temp (degF) Pressure (psi) Reached in (min) 30 Bc (hh:min) 50 Bc (hh:min) 70 Bc (hh:min) 100 Bc (hh:min) Start Bc Stirring before stop (mins) Static Period (min) Peak reading (BC) Terminati on time (hh:min) Terminati on Bc 60 2000 60 7:12 7:12 7:37 8:36 66 75 15 6 10:52 117 UCA Comp. Strength, Request Test ID:39434664 21/DEC/2022 End Temp (degF) Pressure (psi) 50 psi (hh:mm) 100 psi (hh:mm) 500 psi (hh:mm) 1000 psi(hh:mm ) 12 hr CS (psi) 16 hr CS (psi) 24 hr CS (psi) 48 hr CS (psi) End CS (psi) End Time (hrs) 65 3000 10:16 11:07 16:11 25:20 166 487 933 1858 2258 67.27 JͲ08A lateralconformanceproblem STATE OF ALASKA • ' AlOKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations ❑ Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ESP Change-out 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 199-117 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22497-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025515 MILNE PT UNIT SB J-08A , �: I' 0 9.Logs(List fogs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): )c 7 202015 N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: q, Total Depth measured 8,495 feet Plugs measured N/A feet true vertical 4,107 feet Junk measured N/A feet Effective Depth measured 8,495 feet Packer measured 4,714 feet true vertical 4,107 feet true vertical 3,810 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' 3,730psi 1,130psi Surface 2,516' 9-5/8" 2,516' 2,476' 5,750psi 3,090psi Production 4,866' 7" 4,866' 3,850' 7,240psi 5,410psi Liner 3,766' 4-1/2" 8,495' 4,107' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,602' 3,776' Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A 4,714'MD/3,810'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 350 224 Subsequent to operation: 58 0 523 230 225 14.Attachments(required per 20 AAC 25.070..25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑� Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-527 Contact Stan Porhola Email sporholaahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature �, Oti Phone 777-8412 Date 10/19/2015 c-/ iv �z—is' �'iCT 2 12015 Form 10-404 Revised 5/2015 RBDMS • 1 Submit Original Only H . ! Milne Point Unit . in Well: MPU J-08A SCHEMATIC Last Completed: 10/3/2015 Hilcorp Alaska,LLC PTD: 199-117 CASING DETAIL Orig.KB Elev.:65.7/GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top Btm iii 1;01e 13-3/8" Conductor 54.5/L-80/N/A 12.615 0 112' k' 4� i ,' 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,516' 13-3/8" o. 7" Intermediate 26/L-80/Btrc 6.276 0 4,866' 71, i 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' 1 `4" 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 5,901' 8,451' } TUBING DETAIL V. i' 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 4,602' lit I t� 1 JEWELRY DETAIL rh ). No Depth Item 9-5/8"'Is 1 174' GLM 2 4,395' GLM Haat Trace @ 3 4,537' 2-7/8"XN Nipple-2.313 ID:2.205 no-go 2,9' 4 4,548.7' Discharge Head 5 4,549' Pump 6 4,573' Gas Separator 7 4,578' Upper Tandem Seal Section 8 4,585' Lower Tandem Seal Section 9 4,592' Motor 10 4,600' Centralizer/Downhole Gauge:Bottom @ 4,602' 11 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 4,729' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 5,776' Baker HMCV Cement Valve 14 5,794' Baker CTC 20'PZP ECP F k 15 8,451' 4.5"Baker Drillable Pack-off Bushing to 1' 16 8,495' 4.5"Baker Drillable Guide Shoe p2 WELL INCLINATION DETAIL `"r KOP @ 1,500' MaxHole Angle=Horizontal ,,, I 13 :, 1 k 4 OPEN HOLE/CEMENT DETAIL 5 13-3/r" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole 6 7" Cmt w/220 sx Class"G"in 8-1/2"Hole }* 7 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole eg �; 8 TREE&WELLHEAD 9 Tree 3-1/8"CIW 5M . 1- Wellhead WKM 11"x 11"5M,WKM w/11"x 3.5"tubing hanger/NSCT > 10 :' threads top and bottom and 3"CIW H PBV Profile R GENERAL WELL INFO 1 " 11 API:50-029-22497-01-00 Horiz Slott- x Sidetracked&Completed by Nabors 22E -12/29/1999 Dnp 101„ ,12 Recompletion -1/28/2000 iii$' . Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 7' ' ' 13 ESP Replacement by Nabors 35-2/11/2007 A p; 14 ESP Change-out by Nordic#3-7/5/2015 Killed 61/8 VNndow@ .I, ESP Change-out by ASR#1-10/3/2015 4,866'to 4,880'(14') (IIIIIIp 1111111 111111 111111!' 41/2" 1111111'i 1;6 TD=8,495'(MD)/TD=4,107'(TVD) PBTD=8,495'(MD)/PBTD=4,1071TVD) Revised By:TDF 10/20/2015 • • Hilcorp Alaska, LLC i,,.,,rpAlaska.IAA: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP J-08A 50-029-22497-00-00 199-117 I 9/16/2015 10/3/2015 Daily Operations: 9/16/15-Wednesday Held PJSM. Finish RU, PU/MU Injector Head and Lubricator and BOP's.Circulated 60/40 thru coil and lines. Performed Body Test 250-3,500psi.Test ok.Test BOPE as follows:Valves 250-3,500psi, Rams 250-3,500psi, Blinds 250-3,500psi. Function and drawdown. No failures recorded. MU 1-11/16"washout BHA and RIH. Kicked pump in 1.5bpm at 500'. Conitinued in hole to 3,300'with min returns.40bbls in 2bbls out.With no returns, Discuss plan with Anchorage, continued RIH pumping.4bpm and tagged the Discharged Head at 4,651. Increased rate to lbpm pumped away 10 bbls back flushing thru ESP. 140 bbls pumped,8bbls returned. POOH pumping 20 bbls 60/40 freeze protestion. Blow lubricator and lines dry. L/D Injectorhead, Lubricator and BOP's.Secured well and SDFN. 9/17/15-Thursday No operations to report. 9/18/15-Friday No operations to report. 9/19/15-Saturday No operations to report. 9/20/15-Sunday No operations to report. 9/21/15-Monday Demob and disconnect. Psi test surface lines 1,000 psi,SITP 100 psi,SICP 250 psi, Blow down well, Reverse circulate 190 bbl 8.5#hot sea water. Pump 30 bbl hot sea water down tbg 68 bbl heavy oil and water return,84 bbl lost. 9/22/15-Tuesday Pending Report. • S Hilcorp Alaska, LLC likeurpAlaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP J-08A 50-029-22497-00-00 199-117 9/16/2015 10/3/2015 Daily Operations: 9/23/15-Wednesday PJSM,Continue RU prepare for BOP test. BOPE test waived by John Crisp 0530 AM by E-mail. PJSM,Test all lines 3,500psi, Test gas detectors Test BOPE, 250/3,000psi,Annular 250/2,500psi.Accumulator draw down test,offload 225 8.5#150° sea water. PJSM, Pump 42 bbl down csg, 150°F sea water, pump 11 bbl down tbg caught psi, hang sheaves, Pick up landing jt, BO lock downs& pull hanger SW 43K. PJSM, BO landing jt&hanger, POOH,w/ESP, heat trace, and cap. Continue POOH through end of heat trace, continue POOH to 450'. 9/24/15-Thursday PJSM. Continue POOH 11 jts BO/LD ESP motor and pump assy.Close Blind rams LD Baker equipment.Organize floor for standard tubing operations rack 109 jts 2-3/8" PH-6 5.7#P-110, 1 mule shoe 30.24,x-over to 2-7/8" eue 1.45'. Pu MU 2- 3/8" PH6 Mule shoe RIH w 65jts 2-3/8" PH-6 5.7#P-110, 1 mules shoe and 109 jts 3,395.10'"'. Change out floor hardware to 2-7/8". PJSM Continue RIH w 2-7/8"to TOL of 4,716'TMD. RIH to 6,567' PU SO change+/-5K. Repeat 4 times check drag.Cannot interpret load cell weiktindicator. RU pump lines to reverse circ. Pump 9 bbl catch fluid 48 bbl get returns oil, pump 42 bbls cleaned up after 20 bbls total pumped 100 bbls. 28 recovered losses at 70%. Blow down/drain up PU single make connection cannot go any further. LD single rig up to circulate non rotating connection. PJSM RU to reverse circ. previous circ was conventional.Catch pressure at 21 bbls attempt to work down tag is solid@ 6,567'. Pump total 33 bbls 3 BPM at 600 psi. No returns obstruction not washing off. LD 2 singles depth of muleshoe is ("''° 6,535'. RU Halliburton N2 to pump down annulus, returns plumbed to pigging tank,JSA P/T all lines to 3,500 psi. Mix 2 drums Baraklean w/seawater 8.5 ppg temp 100°F. Initial pump rate .5 bpm/500 scf work to 1.25bpm/1500 scf @ "'1,300psi pump 1.75 hrs, heavy sand returns, develop leak in downstream connections,SD/SI ops, 107.6 bbls/113 mscf away, repair down 27 minutes SITP"'1,150psi. Resume ops 1.25bpm/1000scf @"'1,200psi. Off loading seawater, pump total 200 mcsf 207 bbls seawater chase w 50 bbls seawater.Total 4.5" clean_is 1800'total sitted_liner clean_is_634'�. 9/25/15-Friday PJSM. Blow down N2 pressure. 227 bbls recovered.Tubing light blow annulus at 300psi.Open annulus bleed down. Line up to pump 50 bbls down annulus,after 4 bbls casing pressure climbed to 1,100 psi.Shut down pump begin to bleed off pressure. Pressure bleeding off slow. Discuss w/pusher and proceed to evaluate.0915 Operator met co man enroute to pits preceeded by pusher. Disoriented operator explained he had gotten dizzy and fell down stairs and that 2 other men on the pits were down but he had gotten 1 man out. Notified security an dispatched rescue and ambulance a 0915. Mud tt1"� hopper door was opened from the outside and the pusher was rescued by superintendent and other crew mewbers. Rescue and ambulance medical team arrived and administered air/firstaid as needed and all 3 individuals were taken to MPU medical center. Operator had shut in the well with the manual valves.Well is secured with annular, manual valves, &TIW.Operations suspended until further notice.Three personnel from incident have been released to work.SICP is 173 psi. 9/26/15-Saturday Operations on standby. • S 9/27/15-Sunday Well is SI and rig is secured awaiting AOGCC permission to freeze protect well. Investigation continues-safety and Investigation team on location 0800. Break down unnecessary lines and organize location monitor well.AOGCC permission to Freeze protect well. Rig up lines to blow down well, bypassing all lines still in place from N2 operation. Bleed off trapped pressure in choke manifold"'100 psi. SITP 0 psi SICP 640 psi. Bleed off annulus pressure to light blow no fluid in returns. PJSM RU LRS PT lines Pump 65 bbls Freeze protect down 7"annulus.Annulus on vac.Close and lock pipe rams,open annular. Pump 20 bbls freeze protect down tubing tbg on vac.Secure TIW valve.3 rig crew members working. break down all cellar lines, kill lines choke lines and drain up same to prevent freezing.drain up all lines to return tank. Perform housekeeping and RD halliburton pumping HP hose and hardline. Investigation continues Investigation team returns to site. Night crew resumes schedule. NO WELL WORK.Work on maintenaince and storage facilities. 9/28/15-Monday Operations on standby. 9/29/15-Tuesday Operations on standby. 'A • S Hilcorp Alaska, LLC Bikini)Alaska,LLC Weekly eekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP J-08A 50-029-22497-00-00 199-117 9/16/2015 10/3/2015 Daily Operations: 9/30/15-Wednesday Approval from the AOGCC to resume operation. Held PJSM, MIRU LRS and tested to 3,000psi-test ok. Pumped 15bbls of 60/40 methanol down tbg broke circulation up the csg to the external 500bbls kill tank.With tbg under balanced with methanol bullheaded 20 bbls of seawater down tbg and monitored tbg on a vac. Resend BOPE test notice with estimated test time. Held PJSM with night crew. Notified by the state that no waiver will be given for Rig avitivties until BOPE test is completed. BO/LD TIW valve, MU/PU Landing it,Tbg Hanged with TWC installed and landed,secured hanged with LDS. Prep for BOPE Testing, Performed Shell Test, Function tested BOP's and gas detection system. Notified Inspector that we are ready to begin testing at 06:00. 10/1/15-Thursday Held PJSM, Waited on State Inspector to arrive. Prep for BOP Test. Performed BOPE Testing with AOGCC Inspector Chuck Scheve as follows;Valves 250-3,000psi, Rams 250-3,000psi,Annular 250-2,500psi,Gas Detection and Accumulator drawdown test. 1 FP was recorded on C-12. PJSM, Pulled TWC MU landing jt and pulled hanger to rig floor BO/LD same. TOH/LD 149 jts of 2-7/8"8rd 105 jts of 2-3/8" PH6 and mule shoe using charge pump to keep hole full. PU/MU and serviced new ESP assembly.String cable over sheave, made motor and cap connection.TIH w/new ESP on 2-7/8"8rd Tbg with xn-nipple and lower GLM (dummy), continued RIH. 10/2/15-Friday Held PJSM and walk through with change-out crew.Continued TIH with ESP completion. PU Heat Trace at 2,992'. PU top GLM continued TIH w/ESP completion from Hanger depth,Top of Tool Depths as following: Hanger, Pup,4 jts 2-7/8" L-80 6.5#tbg, pup, GLM @ 174',jts tbg, pup GLM @ 4,395',4 jts tbg,XN Nipple @ 4,537', Head @ 4,548', Pump @ 4,549',Gas Separator @ 4,572',Tandem Seals @ 4,577', Motor @ 4,591', Pumpmate @ 4,598',Centralizer @ 4,600', EOC @ 4,602'. Heat Trace Spool was 40'short of 3,000'. Made splice 2'jts down from hanger. Continued splice at report time. 10/3/15-Saturday Held PJSM and walk thru with crew.Completed Heat Trace splice, Continued TIH w/ESP Completion. PU landing joint. Install hanger and penetrators.Test cable, Cut and splice cable connector install same. Meg check connector. Land string SW 43K up 41k down. Run in lock down screws.Set BPV. RDMO ASR 1 and associated equipment and stacked on A Pad. ND BOP's and NU Production Tree and tested-ok.Well transferred over to production. 10/4/15-Sunday No operations to report. 10/5/15-Monday No operations to report. 10/6/15-Tuesday No operations to report. IIIIIMMIMMIIIIIIIIIMMMMMMMMMMMMMMMMMNMMMMMMMM ti OF TJt� • ��w\ s� THE STATE Alaska Oil and Gas Conservation Commission of�T AC KA ' - _ __ 333 West Seventh Avenue J GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ‘11,41-Z, Main: 907.279.1433 OFALAS*P' Fax' 907.276 7542 www.aogcc alaska.gov 5C0/611 19q ... 07 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-08A Sundry Number: 315-527 Dear Mr. Porhola: 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 Si— DATED this 'J1 day of August, 2015 Encl. RBDM SEP 2 2015 RECEWED • STATE OF ALASKA AUG 2 7/ 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION /71-5 6131 l I S APPLICATION FOR SUNDRY APPROVALS AOGCG 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Change Approved Plan ❑✓ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Fill Clean-out 2 Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ESP Change-out❑, 2.Operator Name: 4.Current Well Class: 5.Permit to Dril Number. Hilcorp Alaska,LLC . Exploratary ❑ Development 0- 199-117 . 3.Address: Stratigraphic ❑ Service 1=16.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-71497-01-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 " Will planned perforations require a spacing exception? Yes ❑ No El ✓ MILNE PT UNIT SB J-08A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025515 - MILNE POINT!SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8,495 - 4,107 . 8,495 - 4,107 ' N/A N/A Casing Length Size MD TVD Burst Collapse I Structural Conductor 112' 13-3/8" 112' 112' 3,730psi 1,130psi Surface 2,516' 9-5/8" 2,516' 2,476' 5,750psi 3,090psi Production 4,866' 7" 4,866' 3,850' 7,240psi 5,410psi Liner 3,766' 4-1/2" 8,495' 4,107' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,687 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer and N/A ' 4,714 MD/3,810 TVD and N/A 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development 2- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/15/2015 Commencing Operations: OIL ❑✓ . WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ).,JL- /9 --- Phone 777-8412 Date 8/26/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2 1g._ r �� Plug Integrity ❑ BOP Test [1" Mechanical Integrity Test ❑ Location Clearance LI 7 7 Other: Spacing Exception Required? Yes ,�/ 0 9 p g p q ❑ No ld Subsequent Form Required: APPROVED BY Approved by: / %0,(.4.,14ti COMMISSIONER THE COMMISSION Date: 9- 3/-/-S t.10417 0 RpirGdwA L . 2-/X,-- Submit Form and Form 70-403 Rews 5not5 for 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: MPU J-08A Hilcorp Alaska,l.L, Date:8/26/2015 Well Name: MPU J-08A API Number: 50-029-22497-01 Current Status: SI Oil Well [ESP] Pad: J-Pad Estimated Start Date: September 15th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-117 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,717 psi @ 4,000' TVD (Last BHP measured 11/11/2913) Maximum Expected BHP: 1,717 psi @ 4,000' ND (No new perfs being added) ✓ Max.Allowable Surf Pressure: 177 psi (Based on SBHP taken 11/11/2013 and water ,} c- cut of 50% (0.385psi/ft)with an added safety Sa factor of 1,000'ND of oil cap) Brief Well Summary: r The Milne Point J-08A well was redrilled as a Schrader Bluff development well that TD'd at 8,495' and ran a slotted 4-1/2" liner in December 1999. The well was initially completed with an ESP in December 1999. This ESP failed and was replaced in 2007. The recent pump failed June 15, 2015 during a restart, following recent TAPS proration. The most recent casing pressure test performed prior to sidetracking the well was in 1999. A casing pressure test to 1,500 psi was completed in July 2015 during a recent ESP change-out with Nordic#3. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition • Casing last tested to 1,500 psi for 30 min down to 4,700' MD on 7/04/2015. Objective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. Brief Procedure: WO Rig Procedure: 1. Circulate well with 8.5 ppg seawater down tubing and fill casing. 2. RU crane.Set BPV. ND Tree. NU 11" BOPE. 3. MIRU Hilcorp ASR#1 WO Rig. 4. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8"test joint. 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure Well Prognosis Well: MPU J-08A Ililcorp Alaska,LL Date:8/26/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 7. Bleed any pressure off tubing and casing. Pull BPV. 8. MU landing joint (2-7/8" EUE 8RD hanger thread)and pull over string weight (previous rig string weight 30k UWT with Nordic#3 does not include block weight of 23K)on tubing hanger to confirm free. 6 .S , , t 9. POOH. Lay 2-7/8" tubing on the pipe rack (utilize as workstring). a. Drift ID of 2-7/8" tubing is 2.347". 10. MU 6-1/8" bit and junk baskets. 11. RIH w/2-7/8" tubing to liner top packer+/-4,714' MD. 12. POOH. Lay down bit and junk baskets. Lay down 2-7/8" tubing. 13. MU 3-3/4" mill and junk baskets. 14. RIH w/2-3/8" workstring to liner top packer+/-4,714' MD. 15. Cleanout fill inside screens down to PBTD+/-8,450' MD. a. Min ID is 3.844" at Indicator Subs at+/- 5,768' and 5,787' MD. b. Drift ID of liner is 3.833". 16. Circulate bottoms up x 2 with 8.5 ppg seawater. 17. POOH. Lay down mill and junk baskets. Lay down 2-3/8" workstring. 18. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. 19. Set base of ESP at+/-4,700' MD (Pump intake around +/-4,660' MD). Land tubing hanger. a. Re-run 3/8" control line w/clamps down to pump gauge centralizer. b. Re-run heat trace to +/-3,000' MD. 20. Lay down landing joint. Set BPV. ND BOPE. NU existing 3-1/8" 5,000#tree. Pull BPV. 21. Set TWC. Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 22. RD Hilcorp ASR#1 WO Rig. 23. Replace IA x OA pressure gauge if removed (7" x 9-5/8"). 24. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Milne Point Unit • Well: MPU J-08A SCHEMATIC Last Completed: 7/5/2015 ua�•oru Alaska.LLC PTD: 199-117 CASING DETAIL Orig.KB Elev.:65.27 GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top Btm J L 13-3/8" Conductor 9-5/8" Surface 54.5/L-80/N/A 12.615 0 112' 40/L-80/Btrc. 8.835 0 2,516' 13-3/8" 7" Intermediate 26/L-80/Btrc 6.276 0 4,866' 1 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 5,901' 8,451' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 4,687' . JEWELRY DETAIL No Depth Item 9-5/8" a 6 1 178' GLM 2 4,491' GLM Heat Trace@ 3 4,634' 2-7/8"XN Nipple-2.313 ID:2.205 no-go 3,000 4 4,645' Discharge Head 5 _ 4,646' Pump 6 4,656' Gas Separator 7 4,661' Upper Tandem Seal Section 8 4,668' Lower Tandem Seal Section 9 4,680' Motor 10 4,689' 3/8"External Capillary String 11 4,689' Pumpmate&Centralizer/Downhole Gauge:Bottom @ 4,687' 12 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 13 4,729' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 14 5,776' Baker HMCV Cement Valve 15 5,794' Baker CTC 20'PZP ECP 16 8,451' 4.5"Baker Drillable Pack-off Bushing 2 17 8,495' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL 3 KOP@1,500' y 4 MaxHole Angle=Horizontal 5 OPEN HOLE/CEMENT DETAIL 6 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" . Cmt w/220 sx Class"G"in 8-1/2"Hole M 8 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole 9 TREE&WELLHEAD Tree 3-1/8"CIW 5M 11 it, WKM 11"x 11"5M,WKM w/11"x 3.5"tubing hanger/NSCT Wellhead threads top and bottom and 3"CIW H PBV Profile 12 GENERAL WELL INFO Horiz.Slotted tii u ner N API:50-029-22497-01-00 - .13 Sidetracked&Completed by Nabors 22E -12/29/1999 7„. Recompletion -1/28/2000 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 0 15 ESP Replacement by Nabors 3S-2/11/2007 Mlled6-1/8"Wndcw@ IIIII�IIIIII 4,866'to 4,880'(14') 111111111111 111111111111 111111111111 4-1/2" 11111111 167 TD=8,495'(MD)/TD=4,107'(TVD) PBTD=8,495'(MD)/PBTD=4,107'(TVD) Revised By:STP 8/19/2015 Milne Point Unit Well: MPU J-08A • 14PROPOSED Last Completed: 7/5/2015 Hilcorp Alaska,LLC PTD: 199-117 CASING DETAIL Orig.KB Elev.:65.7/GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top Btm 11 4; 13-3/8" Conductor 54.5/L-80/N/A 12.615 0 112' F 9 5/8" Surface 40/L-80/Btrc. 8.835 0 2,516' 13-3/8" 7" Intermediate 26/L-80/Btrc 6.276 0 4,866' 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' 4-1/2" Slotted Liner 6.2/L-80/SLT 336...992557886 .958 5,901' 8,451' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 ±4,687' JEWELRY DETAIL No Depth Item 9-5/8" 1 ±178' GLM 2 ±4,491' GLM Heat Trace@ 3 ±4,634' 2-7/8"XN Nipple-2.313 ID:2.205 no-go ±3,000' 4 ±4,645' Discharge Head 5 ±4,646' Pump 6 ±4,656' Gas Separator 7 ±4,661' Upper Tandem Seal Section 8 ±4,668' Lower Tandem Seal Section 9 ±4,680' Motor 10 ±4,689' 3/8"External Capillary String 11 ±4,689' Pumpmate&Centralizer/Downhole Gauge:Bottom @±4,687' 12 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 13 4,729' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 14 5,776' Baker HMCV Cement Valve 15 5,794' Baker CTC 20'PZP ECP 16 8,451' 4.5"Baker Drillable Pack-off Bushing 2 17 8,495' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL 3 KOP @ 1,500' MaxHole Angle=Horizontal , 4 s OPEN HOLE/CEMENT DETAIL 6 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole 7 7" Cmt w/220 sx Class"G"in 8-1/2"Hole • 8 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole 9 TREE&WELLHEAD ""'10 Tree 3-1/8"CIW 5M 11 Wellhead WKM 11"x 11"5M,WKM w/11"x 3.5"tubing hanger/NSCT threads top and bottom and 3"CIW H PBV Profile " 112 GENERAL WELL INFO Holt.Slat±-; Una API:50-029-22497-01-00 13 Sidetracked&Completed by Nabors 22E -12/29/1999 7 Recompletion -1/28/2000 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 • 15 ESP Replacement by Nabors 3S-2/11/2007 4W,866ned 6o4B8W30 n(14') III IIIR 11111111 1111111 11111111 4-1/2" !11111 1617 TD=8,495'(MD)/TD=4,107(TVD) PBTD=8,495'(MD)/PBTD=4,107(TVD) Revised By:STP 8/19/2015 Milne Point . . 2015 ASR Rig 1 11 ' `� Knight Oil Tools BOP 11.or. 11" BOPE Stripping Head IN 3.98' 1` ° , Shaffe 4 i 11" - 5000 II iii iiiiil Milli lig SPEW 1 II 111 III Ill 1111 ice. Mal4 ll C 16 iiiiinl! 4.54' °� —= 2 7/8-5 variables WW110.111"-5000 �� _�g�) —= Blind 0 ,ice fnl frfl(fnI it 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves ! i :IWill 2.00 � . � � � �I!iSlI[i I1ti .., ii " 'i ort Manual Manual Manual HCR Updated 8/19/15 Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, August 31, 2015 10:23 AM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: RE:J-08A ESP swap .. updated sundry(PTD 199-117) Guy, Please withdraw the original sundry 315-507 for MPU J-08A. SCANNED SEP 1 6 2015 Stan From: Schwartz, Guy L (DOA) [ It0guy.schwartz@alaska.gov] Sent: Monday, August 31, 2015 10:02 AM To: Stan Porhola Subject: J-08A ESP swap .. updated sundry (PTD 199-117) Stan, Looks like same thing with 1-08A. We received an new sundry for MPU J-08A with updates... the changes look like mainly to have a rolling test contingency for the BOPE pressure test. It would be cleaner to request a withdraw of the original sundry 315-507 and go completely off the new sundry for the wellwork (use 315-527) . Please send an email requesting a withdraw for the original sundry 315-507. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). RBDMSIY.__j_ SEP 0 8 2015 1 hw 11/1/4 c, THE STATE Alaska Oil and Gas ofAJ AsKA Conservation Commission st '.��•�.;t= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALA`'*2' Fax. 907.276.7542 www.aogcc.alaska gov Stan Porhola SCANNED .4 Operations Engineer Hilcorp Alaska, LLC fl 3800 Centerpoint Drive, Suite 1400 �( Anchorage, AK 99503 Re: Mile Point Unit, Schrader Bluff Oil, SB J-08A Sundry Number: 315-507 Dear Mr. Porhola: 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 20 day of August, 2015 Encl. ECE VE 9 Ula STATE OF ALASKA AUGa`S 9120 i 13 ALASKA OIL AND GAS CONSERVATION COMMISSION dko'CU APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑., . Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ FNI Clean-out 2 Plug for Redrill❑ Perforate New Pool ❑ Repair Well 2- Re-enter Susp Well ❑ Other. ESP Change-out 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Nunber. Hilcorp Alaska,LLC ., Exploratory 0 Development Q- 199-117 ' 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22497-01-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05• Will planned perforations require a spacing exception? Yes 0 No ❑/ MILNE PT UNIT SB J-08A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025515 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8,495 - 4,107 _ 8,495 - 4,107 • N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' 3,730psi 1,130psi Surface 2,516' 9-5/8" 2,516' 2,476' 5,750psi 3,090psi Production 4,866' 7" 4,866' 3,850' 7,240psi 5,410psi Liner 3,766' 4-1/2" 8,495' 4,107' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic- See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,687 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): ZXP Liner Top Packer and N/A • 4,714 MD/3,810 ND and N/A 12.Attachments: Description Summary of Proposal E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development 2- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/11/2015 Commencing Operations: OIL ❑✓ ' WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: N/A GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email soorholaAhilcorD.com Printed Name S an Porhola Title Operations Engineer Signature e2 ;r(`_ Phone 777-8412 Date 8/19/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l5 - so—t Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,, 3DGO los es a0° lssf( IV%. -5P= 177e5.) Spacing Exception Required? Yes ❑ No 12 Subsequent Form Required: J 0 --y0,"1 / APPROVED BY Approved by: Pcl..c.t.1)Z....1 ( COMMISSIONER THE COMMISSION Date: g.� - iS_$•1J) y � 'l�lis . -97zq OpRietiliillAtfor Suborn Form and Form 10-403 Rewsed 5/2075711 12 months from the date of approval. A achments in Duphc1t RBDMS AUG 1 1U15 Well Prognosis Well: MPU J-08A Hilcorp Alaska,LL Date:8/19/2015 Well Name: MPU 1-08A API Number: 50-029-22497-01 Current Status: SI Oil Well [ESP] Pad: J-Pad Estimated Start Date: September 11th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-117 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907)331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,717 psi @ 4,000' TVD (Last BHP measured 11/11/2013) Maximum Expected BHP: 1,717 psi @ 4,000' TVD (No new perfs being added) Max. Allowable Surf Pressure: 177 psi (Based on SBHP taken 11/11/2013 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000'TVD of oil cap) Brief Well Summary: The Milne Point J-08A well was redrilled as a Schrader Bluff development well that TD'd at 8,495' and ran a slotted 4-1/2" liner in December 1999. The well was initially completed with an ESP in December 1999. This ESP failed and was replaced in 2007. The recent pump failed June 15, 2015 during a restart, following recent TAPS proration. The most recent casing pressure test performed prior to sidetracking the well was in 1999. A casing pressure test to 1,500 psi was completed in July 2015 during a recent ESP change-out with Nordic#3. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition • Casing last tested to 1,500 psi for 30 min down to 4,700' MD on 7/04/2015. / Q �- Objective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. / d- F11‘) Brief Procedure: WO Rig Procedure: 1. Circulate well with 8.5 ppg seawater down tubing and fill casing. 2. RU crane. Set BPV. ND Tree. NU 11" BOPE. 3. MIRU Hilcorp ASR#1 WO Rig. 4. Test to 250 psi Low/3,T2pahlizh, annular to 250 psi Low/2,500 psi High (hold each valve and • test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8"test joint. 5. Bleed any pressure off tubing and casing. Pull BPV. r" h se_�l 6. MU landing joint(2-7/8" EUE 8RD hanger thread)and pull over string weight(30k UWT Nordic#3 di"'�s does not include block weight of 23K)on tubing hanger to confirm free. G• srcj `/2SA 7. POOH. Lay 2-7/8"tubing on the pipe rack(utilize as workstring). = 3/, zea lbs a. Drift ID of 2-7/8"tubing is 2.347". CA•�) 8. MU 6-1/8" bit and junk baskets. Well Prognosis Well: MPU J-08A Hilcorp Alaska,LI) Date:8/19/2015 9. RIH w/2-7/8"tubing to liner top packer+/-4,714' MD. 10. POOH. Lay down bit and junk baskets. Lay down 2-7/8"tubing. 11. MU 3-3/4" mill and junk baskets. 12. RIH w/2-3/8"workstring to liner top packer+/-4,714' MD. 13. Cleanout fill inside screens down to PBTD+/-8,450' MD. a. Min ID is 3.844" at Indicator Subs at+/-5,768'and 5,787' MD. b. Drift ID of liner is 3.833". 14. Circulate bottoms up x 2 with 8.5 ppg seawater. 15. POOH. Lay down mill and junk baskets. Lay down 2-3/8" workstring. 16. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. 17. Set base of ESP at+/-4,700' MD(Pump intake around+/-4,660' MD). Land tubing hanger. a. Re-run 3/8"control line w/clamps down to pump gauge centralizer. b. Re-run heat trace to+/-3,000' MD. 18. Lay down landing joint. Set BPV. ND BOPE. NU existing 3-1/8" 5,000#tree. Pull BPV. 19. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 20. RD Hilcorp ASR#1 WO Rig. 21. Replace IA x OA pressure gauge if removed (7"x 9-5/8"). 22. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic • Milne Point Unit Well: MPU 1-08A SCHEMATIC Last Completed: 7/5/2015 Hilcorp Alaska,LLC PTD: 199-117 CASING DETAIL Clog.KB Elev.:65.7/GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top Btm Jj 13 3/8" Conductor 54.5/L-80/N/A 12.615 0 112' P �i 9-5/8" _ Surface 40/L-80/Btrc. 8.835 0 2,516' 13-3/8" $' y 7" _ Intermediate 26/L-80/Btrc 6.276 0 4,866' 1 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' 4 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 5,901' 8,451' w .: TUBING DETAIL ►q 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 4,687' A. JEWELRY DETAIL cr t No Depth Item 35/8''4 ic 1 178' GLM 2 4,491' GLM Heat Trace @ 3 4,634' 2-7/8"XN Nipple—2.313 ID:2.205 no-go 3,OOD' 4 4,645' Discharge Head 5 4,646' Pump 6 4,656' Gas Separator 7 4,661' Upper Tandem Seal Section 8 4,668' Lower Tandem Seal Section 9 4,680' Motor 10 4,689' 3/8"External Capillary String 11 4,689' Pumpmate&Centralizer/Downhole Gauge:Bottom @ 4,687' 12 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 13 4,729' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 14 5,776' Baker HMCV Cement Valve ,, 15 5,794' Baker CTC 20'PZP ECP '+ 16 8,451' 4.5"Baker Drillable Pack-off Bushing 217 8 ,495' 4.5"Baker Drillable Guide Shoe s .. WELL INCLINATION DETAIL . • � 3 KOP @ 1,500' MaxHole Angle=Horizontal OPEN HOLE/CEMENT DETAIL if• )6 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole '+ 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole 7 7" Cmt w/220 sx Class"G"in 8-1/2"Hole .", 0 8 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole 9 •10 TREE&WELLHEAD sa, ,,, Tree 3-1/8"CIW 5M >' 11 WKM 11"x 11"5M WKM w/11"x 3.5"tubing hanger/er NSCT 4 Wellhead threads top and bottom and 3"CIW H PBV Profile Hain Slott= _ " 12 GENERAL WELL INFO Ung lig API:50-029-22497-01-00 13 Sidetracked&Completed by Nabors 22E -12/29/1999 7'r ,. iiii Recompletion —1/28/2000 "' :??14 Schrader Bluff Recompletion by Nabors 4ES—4/19/1997 • 0 15 killed 6-1/8"VUndoN® ESP Replacement by Nabors 35-2/11/2007 4,866 to 4,880(14) 4112„ `�';' 1617 TD=8,495'(MD)/TD=4,107(TVD) PBTD=8,495'(MD)/PBTD=4,107(TVD) Revised By:STP 8/19/2015 Milne Point Unit Well: MPU J-08A 14 PROPOSED Last Completed: 7/5/2015 Ifilcorp Alaska,LLC PTD: 199-117 CASING DETAIL Orig.KB Elev.:65.2'/GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top BMA L 13-3/8" Conductor 54.5/L-80/N/A 12.615 0 112' 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,516' 13-3/8" 7" Intermediate 26/L-80/Btrc 6.276 0 4,866' 1 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 5,901' 8,451' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 ±4,687' . JEWELRY DETAIL No Depth Item 9-5/8" a 1 1 ±178' GLM , � 2 ±4,491' GLM Heat Trace @/ 3 ±4,634' 2-7/8"XN Nipple-2.313 ID:2.205 no-go ±3,000 4 ±4,645' Discharge Head 5 ±4,646' Pump 6 ±4,656' Gas Separator 7 ±4,661' Upper Tandem Seal Section 8 ±4,668' Lower Tandem Seal Section 9 ±4,680' Motor 10 ±4,689' 3/8"External Capillary String 11 ±4,689' Pumpmate&Centralizer/Downhole Gauge:Bottom @±4,687' 12 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 13 4,729' _ Baker 5"x 7"HMC Liner Hanger(4.375"ID) 14 5,776' Baker HMCV Cement Valve 15 5,794' Baker CTC 20'PZP ECP 2 16 8,451' . 4.5"Baker Drillable Pack-off Bushing 17 8,495' 4.5"Baker Drillable Guide Shoe WELL INCLINATION DETAIL 3 KOP @ 1,500' MaxHole Angle=Horizontal r'__ i I 4 ' 5 OPEN HOLE/CEMENT DETAIL 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole , ,4 L j 6 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole 1• 8 7" Cmt w/220 sx Class"G"in 8-1/2"Hole 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole ' l' s TREE&WELLHEAD of" 10 . Tree 3-1/8"CIW 5M 11 WKM 11"x 11"5M,WKM w/11"x 3.5"tubing hanger/NSCT Wellhead threads top and bottom and 3"CIW H PBV Profile How slots %.112 GENERAL WELL INFO Liner `.' API:50-029-22497-01-00 :13 Sidetracked&Completed by Nabors 22E -12/29/1999 Recompletion -1/28/2000 7 14 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 ' 15 ESP Replacement by Nabors 35-2/11/2007 Nilled6-1/8 VUndov@ IIIIIIIIIIII 4,866'to 4,880'(14') IIIIIIIIIIII IIIIIIIIIIII 01111111111 4-1/2" IIIIIIIIIII 1617 1D=8,495'(MD)/TD=4,107(TVD) PBTD=8,495'(MD)/PBTD=4,107'(1VD) Revised Ry:STP R/19/2015 ., .. Milne Point 14 2015 ASR Rig 1 Miro" �:..e..t.tc Knight Oil Tools BOP 11" BOPE Stripping Head 3.98' IP WEI Gr Shaffer 111P 11" - 5000 11l III III Iii iii I di I 1411111 1_ H Cie H 2 7/8-5 variables 4.54 ai in " H 11 -5000 n H Blind a r‘ N . . * /_____..: I MI 111 111 11 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves ell I I I!I 1!I IF III" 2.00 N1 Al1 c.lH : '� I �� i 4. I 1r: - lil Iii III I11 I11'! Manual Manual Manual HCR Updated 8/19/15 STATE OF ALASKA AL_ _„KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑✓ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: ESP Change-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska,LLC Development Q Exploratory ❑ 199-117 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22497-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL0025515 MILNE PT UNIT SB J-08A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JUL 7 2015 N/A MILNE POINT/SCHRADER BLUFF OIL 11. Present Well Condition Summary: AOGGC Total Depth measured 8,495 feet Plugs measured N/A feet true vertical 4,107 feet Junk measured N/A feet Effective Depth measured 8,495 feet Packer measured 4,714 feet true vertical 4,107 feet true vertical 3,810 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8” 112' 112' 3,730psi 1,130psi Surface 2,516' 9-5/8" 2,516' 2,476' 5,750psi 3,090psi Production 4,866' 7" 4,866' 3,850' 7,240psi 5,410psi Liner 3,766' 4-1/2" 8,495' 4,107' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic feet SEWED AUG 1 02015 True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,687'MD 3,802'TVD Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A 4,714'MD/3,810'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 68 28 362 260 227 Subsequent to operation: 65 26 540 260 223 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-375 Contact Chris Kanyer Email ckanyer@hilco p.com Printed Name Chris Kanyer Title Operations Engineer or SignatureXPhone 777-8377 Date 7/17/2015 76.✓ 7-..?7-is" RBDMJUL 2 3 2015 Form 10-404 Revised 5/2015 ,' 7 ,1//-3---- Submit Original Only Milne Point Unit Well: MPU J-08A . 14 SCHEMATIC Last Completed: 7/5/2015 Hilcarp Alaska,LLC PTD: 199-117 CASING DETAIL Orig.KB Elev.:65.2'/GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top Btm j , t.:, li . A 13-3/8" Conductor 54.5/L-80/N/A 12.615 0 112' 9-5/8" Surface 40/1-80/Btrc. 8.835 0 2,516' 13-3/8 7" Intermediate 26/L-80/Btrc 6.276 0 4,866' 1 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 5,901' 8,451' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 4,687' i• JEWELRY DETAIL No Depth Item 9-5/8"o 1 1 172' GLM 2 4,485' GLM Heat Trace @-''''''''......41r- 3 4,628' 2-7/8"XN Nipple-2.313 ID 3,000' 4 4,639.7' Discharge Head 5 4,640' Pump 6 4,656' Gas Separator 7 4,661' Upper Tandem Seal Section 8 4,668' Lower Tandem Seal Section 9 4,675' Motor 10 4,683' Pumpmate&Centralizer/Downhole Gauge:Bottom @ 4,687' 11 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 12 4,729' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 13 5,776' Baker HMCV Cement Valve 14 5,794' Baker CTC 20'PZP ECP 15 8,451' 4.5"Baker Drillable Pack-off Bushing 16 8,495' 4.5"Baker Drillable Guide Shoe 2 • WELL INCLINATION DETAIL 'i6r KOP @ 1,500' e1 w i 3 <3, MaxHole Angle=Horizontal r ;' - 4 t' OPEN HOLE/CEMENT DETAIL / tr+ al �/ 1t' 6A, 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole ri 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole 6 ,4 7" Cmt w/220 sx Class"G"in 8-1/2"Hole ! 1: 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole w 8 «x 9 TREE&WELLHEAD , Tree 3-1/8"CIW 5M ",n i _10 4..', WKM 11"x 11"5M,WKM w/11"x 3.5"tubing hanger/NSCT (.; Wellhead threads top and bottom and 3"CIW H PBV Profile e. GENERAL WELL INFO '. , 11 API:50-029-22497-01-00 Horiz Slott Linerr $ .4 Sidetracked&Completed by Nabors 22E -12/29/1999 ;: :12 Recompletion -1/28/2000 •$ F. Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 7"' �M 3 13 ESP Replacement by Nabors 35-2/11/2007 14 Nilled 6-1/8"Wndow @ 4,866 to 4,880'(14) 4-1/2" ; 15 16 TD=8,495'(MD)/TD=4,107'(1VD) PBTD=8,495'(MD)/PBTD=4,107'(TVD) Revised By:TDF 7/17/2015 Hilcorp Alaska, LLC 11;Icorp Alaska,L;I,C Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP J-08A 50-029-22497-01-00 199-117 7/2/2015 7/5/2015 Daily Operations: 7/1/15-Wednesday No operations to report. 7/2/15-Thursday Accepted Rig, MIRU Nordic 3 and associated equipment,spot tanks, berm cellar&MU hardline to kill tanks. Pull BPV.Off loaded 2 peak vac trucks with 140 deg seawater(480bbls).Tested hardline 250psi low/3,000psi high.SITP 240psi SICP 350psi, bled both to Opsi,started pumping reversed circulating @ 5bpm, broke cir 125bbls,with returns clean,SD pump well on vac- Pumped 298 bbls, Returned 113 bbls, Lost 185 bbls. Blow lines dry and disconnect from well,Set BPV, ND /n� production tree packed off tbg hanger and NU BOP's. Pulled BPV and set TWC,filled BOPE and performed the shell test. I) AOGCC witness waived by John Crisp. Performed BOPE test as follows:Annular 250psi/2,500psi,Valves 250psi/3,000psi, ,\r¢47 Rams 250psi/3,000psi, held and charted 5 mpt,gas detection and kommey drawdown=noTa'ilums re u e TWC, MU Landing jt, backed out lock down pins, pulled 80k to unseated tbg hanger and pulled to rig floor, meg. ESP cable- good,decompleted hanger BO/LD same. Pull stand and thread cable to spooler. 7/3/15-Friday Held PJSM. POOH w/completion string and spooling cable and heat trace.Tallied stands OOH, L/D GSM's,xn nipple, loaded 80jts of 2-7/8"8rd yellow band in pipe shed, BO/LD ESP assembly. Note:from xn-nipple to top of the seals was covered with broken up pieces of scale. From seals to top of motor had areas of piting.The pump and motor turned free. Sent pic to Anchorage._Cleaned and re-r floor,PU7"csg scraper and TIH to 4,700' reversed circulated 2 bottoms up returns scale.TOH standing back first 60 jts, L/D bottom 81 jts (61-141) identifed bad on PDS caliper log and casing scraper. PU 7"test packer and TIH to 4,700'. 7/4/15-Saturday Held PJSM.Set packer,filled and pressured up casing to 1,500psi charted for 30mins-test ok. Released test packer and TOH w/packer and L/D same. PU MU and service new ESP assembly,sting new cable and cap string over sheave. Make motor and cap connection.Test all cap string check break @ 3,400 psi. RIH w/new ESP on 2-7/8" 8rd L-80 tbg with XN- nipple and lower GLM,continue RIH check cable and cap every 2,000'. PU Heat trace at 3,000'. PU top GLM continued TIH w/ESP completion from hanger depth,depths as following: Hanger, Pup,4 jts 2-7/8" L-80 6.5#tbg, pup,GLM @ 178', jts tbg, pup GLM @ 4,491',4 jts tbg,XN Nipple@ 4,634', pup. head @ 4,645'gas separator @ 4,662',tandem seals @ 4,667', motor @ 4,680', EOT Centralizer @4,693'. 7/5/15-Sunday, Held JSA.Continued TIH w/completion. PU landing joint. Install hanger and penetrators.Test cable and cap string. Cut and splice cable connector and cap string, install same. Meg check connector. Land string. Run in lock down screws. ND BOPE. NU tree.Test all breaks and void 250/5,000 psi. 7/6/15-Monday No operations to report. 7/7/15-Tuesday No operations to report. V OF Tit,\ s?, THE STATE Alaska Oil and Gas mw of/�11T , /f�, IK /� Conservation Commission 1 � �1� Witt ._ = 333 West Seventh Avenue • 5GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \Tj�: Main. 907,279.1433 O"ALASY`P s7 2Q15 S�NFax• 907.276 7542 Ea \..L www.aogcc.alaska.gov Chris Kanyer } Lri Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-08A Sundry Number: 315-375 Dear Mr. Kanyer: 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, / Daniel T. Seamount, Jr. Commissioner DATED this/7 day of June, 2015 Encl. RECEIVED STATE OF ALASKA JUN 17 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION I.:V ,6 APPLICATION FOR SUNDRY APPROVALS AOGCC • r 20 AAC 25.280 1.Type of Request Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 . Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well Q - Re-enter Susp Well ❑ Other: ESP Change-out Q 2.Operator Name 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory ❑ Development ❑✓ • 199-117 ' 3.AddressStratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22497-01-00 7 If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑., MILNE PT UNIT SB J-08A • 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL0025515 " MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft). Effective Depth TVD(ft)• Plugs(measured): Junk(measured): 8,495 4,107 8,495 4,107 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' 3,730psi 1,130psi Surface 2,516' 9-5/8" 2,516' 2,476' 5,750psi 3,090psi Production 4,866' 7" 4,866' 3,850' 7,240psi 5,410psi Liner 3,766' 4-1/2" 8,495' 4,107' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): See Attached Schematic f See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,679 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer and N/A 4,714 MD/3,810 TVD and N/A 12 Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development ❑, - Service ❑ 14.Estimated Date for 15.Well Status after proposed work. 6/30/2015 Commencing Operations. OIL Q v WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A I GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyerahilcorp.com Printed Name Chris Kanyer Title Operations Engineer 9 Signatures. Phone 777-8377 Date 6/16/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31s- 31 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: „IL 512:90 Qs. 3)y c s (' (/VU4S/ = /3J ps— ) —71 ceis; . .tet- red rt- ' ( 1S c tesz, ) Spacing Exception Required? Yes ❑ No a Subsequent Form Required: /0 1-1(,41 APPROVED BY Approved by: .� COMMISSIONER THE COMMISSION Date: / 1 / /...9 to (7(.s f�l4 417115- 4 m Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months r the date o p , ` 4..0, IAachrl'feni� uph:ate RBDM76 JUN L A Well Prognosis Well: MPJ-08A Hilcorp Alaska,LL Date:6/16/2015 Well Name: MPJ-08A API Number: 50-029-22497-01-00 Current Status: SI Producer Pad: J Pad Estimated Start Date: June 30, 2015 Rig: Nordic 3 Reg.Approval Req'd? June 30, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 199-117 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907)250-0374 (M) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) AFE Number: 1551649 Current Bottom Hole Pressure: — 1,717 psi @ 4,000'ND (Last BHP measured 11/11/2013) Maximum Expected BHP: — 1,717 psi @ 4,000' ND (No new perfs being added) Max.Allowable Surface Pressure: 133 psi (Based on actual reservoir conditions and water cut of 80% (0.418psi/ft)with an added safety factor of 1000'ND of oil cap) r AO- CAL Brief Well Summary: µ,4-5,a The Milne Point J-08A well was redrilled as a Schrader Bluff development well that TD'd at 8,495' and ran a slotted 4-1/2" liner in December 1999. The well was initially completed with an ESP in December 1999. This ESP failed and was replaced in 2007. The recent pump failed June 15, 2015 during a restart, following recent TAPS proration.The most recent casing pressure test performed prior to sidetracking the well in 1999. A casing pressure test will be completed during this workover. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. RWO Objective: Pull ESP with heat trace, pressure test casing, & run 2-7/8" ESP completion with heat trace. Brief Procedure: 1. MIRU Nordic#3 Rig. " 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Well Prognosis Well: MP1-08A • Hilcorp Alaska,Ll/ Date:6/16/2015 d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESP completion with heat trace (3,360') from 4,677' to surface and lay down same. Contingency: (Pending condition of pulled completion—sand/scale in pump) 6. RIH with cleanout BHA to +/-4,700'. POOH with same. 7. RIH and set test packer at+/-4,700' (Note: above liner top packer, to test of 7" casing only). 8. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 9. MU and RIH with ESP with ^'3,000' heat trace on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+1-4,677'. Land tubing hanger. 10. ND BOP, NU and tree. 11. RDMO workover rig and equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU J-08A SCHEMATIC Last Completed: 2/11/2007 . II iiii��,r Alaska,LLC PTD: 199-117 CASING DETAIL Orig.KB Elev.:65.2'/GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top Btm ,� f4' 13-3/8" Conductor 54.5/L-80/N/A 12.615 0 112' 1kR ' 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,516' 13-3/8" ' 7" Intermediate 26/L-80/Btrc 6.276 0 4,866' It*,*, 1 d* 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' t .1 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 5,901' 8,451' ;* I TUBING DETAIL r:; . r 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 4,679' 1 JEWELRY DETAIL s ;' k No Depth Item 9-5/8"`i te 1 174' GLM:2-7/8"x 1"KBMM—ID=2.347" , 2 4,473' GLM:2-7/8"x 1"KBMG^'72°angle 1. 3 4,615' 2-7/8"HES XN Nipple(2.205"ID) 4 4,630' XT-1 PSI&Discharge Head (- 5 4,633' Centrilift Pump MSSD-1-5 146 Stage,400P6 6 4,648' Gas Seperator:GRSFTXARH6 _ 7 4,653' Tandem Seal Section Heat Trace@ i 8 4,667' Motor:76hp/1,360V/34A,Model-KMH 3,360 9 4,675' PumpMate Sensor and 6 fin Centralizer:Bottom @ 4,679' 10 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 11 4,729' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 12 5,776' Baker HMCV Cement Valve 13 5,794' Baker CTC 20'PZP ECP 14 8,451' Baker Drillable Pack-off Bushing 4 's 15 8,459' Baker Drillable Guide Shoe 2 WELL INCLINATION DETAIL i KOP @'1440 CS MaxHole Angle=Horizontal i I 1 3 eOPEN HOLE/CEMENT DETAIL sr yj 4 140 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole ;i i 5 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole ; 6 ih 7" Cmt w/220 sx Class"G"in 8-1/2"Hole 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole 4" 7• TREE&WELLHEAD '. Ain r. Tree 3-1/8"CIW 5M '0 41:44 8 PWKM 11"x 11"5M,WKM w/11"x 3.5"tubing hanger/NSCT a 1 9 Wellhead threads top and bottom and 3"CIW H PBV Profile IA i' 0 GENERAL WELL INFO wv Mi, API:50-029-22497-01-00 > ' - 10 Sidetracked&Completed by Nabors 22E -12/29/1999 , Recompletion —1/28/2000 A k }'i 11 Schrader Bluff Recompletion by Nabors 4ES—4/19/1997 ` : �•, � ,- ESP Replacement by Nabors 3S—2/11/2007 7"L4 0 12 • 13 Nflled 6.1/8"Wrxio✓v @ 4,866'to 4,880(14') i al ■I_� 4-1/2" 14 15 TD=8,495'(MD)/TD=4,107'(TVD) PBTD=8,495'(MD)/PBTD=4,107'(TVD) Revised By:TDF 6/16/2015 Milne Point Unit Well: MPU J-08A PROPOSED Last Completed: 2/11/2007 , 14 ililcoru Alaska,LLC PTD: 199-117 CASING DETAIL Orig.KB Elev.:65.2'/GL Elev.:35.7'(N22E) Size Type Wt/Grade/Conn ID Top Btm 4 4 ..':ii: 13-3/8" Conductor 54.5/L-80/N/A 12.615 0 112' to 9-5/8" Surface 40/L-80/Btrc. 8.835 0 2,516' ir 13-3/8" 7" Intermediate 26/L-80/Btrc 6.276 0 4,866' 1 �a i� 4-1/2" Liner 12.6/L-80/IBT 3.958 4,729' 5,901' '^ 4-1/2" Slotted Liner 6.2/L-80/SLT 3.958 5,901' 8,451' TUBING DETAIL ;' 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 ±4,677' 1 JEWELRY DETAIL i, No Depth Item :la9-5/8" � 1 ±174' GLM 2 ±4,473' GLM Haat Trace @ 3 ±4,615' 2-7/8"XN Nipple ±3,C067 i4 ±4,630' Discharge Head 5 ±4,633' Pump 6 ±4,648' Gas Separator 7 ±4,653' Tandem Seal Section: 8 ±4,667' Motor 9 ±4,675' Centralizer/Downhole Gauge:Bottom @±4,677' 10 4,714' Baker ZXP Liner Top Packer w/6'Tie Back(5.25"ID) 11 4,729' Baker 5"x 7"HMC Liner Hanger(4.375"ID) 12 5,776' Baker HMCV Cement Valve 13 5,794' Baker CTC 20'PZP ECP 14 8,451' 4.5"Baker Drillable Pack-off Bushing i. a 15 8,495' 4.5"Baker Drillable Guide Shoe e 2 WELL INCLINATION DETAIL KOP @ 1,500' MaxHole Angle=Horizontal I l 3 OPEN HOLE/CEMENT DETAIL k. 4 tt 13-3/8"" Cmt w/250 sx of Arcticset I in 24"Hole ! 5 k 9-5/8" Cmt w/504sx PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/220 sx Class"G"in 8-1/2"Hole 6,, 4-1/2" Cmt w/84 sks Class"G"in 6-1/8"Hole 7 TREE&WELLHEAD 8 IN Tree 3-1/8"CIW 5M Wellhead WKM 11"x 11"5M,WKM w/11"x 3.5"tubing hanger/NSCT 9'? threads top and bottom and 3"CIW H PBV Profile 11 '' iz GENERAL WELL INFO �' API:50-029-22497-01-00 c I: 10 Sidetracked&Completed by Nabors 22E -12/29/1999 lio'Liner 4 Recompletion -1/28/2000 ;', r`'11 Schrader Bluff Recompletion by Nabors 4ES-4/19/1997 � ESP Replacement by Nabors 3S-2/11/2007 7'f A ' p 8,2 13 MIIed 6-1/8"Wrxiow @ 4,866'to 4,880'(14') 3 , 5 ( 4-1/2" 14 15 TD=8,495'(MD)/TD=4,107'(ND) PBTD=8,495'(MD)/PBTD=4,107'(ND) Revised By:TDF 6/16/2015 11" BOP Stack 1 v v as i so Hydril 11" 5M ,iiiii - Shaffer 2 3/8" Rams 11" 5M 2 7/8-5.5 _ variables "Im'llia.* 1 _ Hydril - 4 11" 5M I!fr Blinds low* Optional valve port —) C :,,,,,, i„. , „Ot1EI9iII!*l1I , t. ,, .,,,,-,,, ,,,,, „„,., , 1.( 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program STATE OF ALASKA J-Jr'-V¡ I '~"'_I ... -- ALÀ~ OIL AND GAS CONSERVATION COM~SION ~l') MAR 0 6 Z007 REPORT OF SUNDRY WELL OPERATIONS '0" & G C C ., Alaska i as ons. ommlSston Anth\)fogo ~ Repair Well 0 Plug Perforations 0 Stimulate ~ Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Time Extension o Re-Enter Suspended Well ~ Other Change-Out ESP 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Well Class Before Work: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 199-117 ;" 6. API Number: 50-029-22497 -01-00 ¡/ 66.00 9. Well Name and Number: MPJ-08A/ 8. Property Designation: 10. Field / Pool(s): ADL 025515 11. Present well condition summary Total depth: measured Milne Point Unit / Schrader Bluff./ Effective depth: true vertical measured true vertical Length 8495 I 4107 / 8495 4107 feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 13-3/8" 112' 112' 2730 1130 9-5/8" 2516' 2476' 5750 3090 7" 4866' 3850' 7240 5410 4-1/2" 4729' - 8495' 3814' - 4107' 8430 7500 Casing Structural Conductor Surface Intermediate Production Liner 80' 2483' 4837' 3766' SCANNED MAR 0 8 2007 Perforation Depth MD (ft): Perforation Depth TVD (ft): Slotted Liner 5901' - 8451' Slotted Liner 4118' - 4105' Tubing Size (size, grade, and measured depth): 2-7/8",6.5# L-80 4679' Packers and SSSV (type and measured depth): Baker ZXP Liner Top Packer with 6' tie back 4714' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure o 0 0 0 o 0 0 0 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16, Well Status after proposed work: 181 Well Schematic Diagram 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 13. Oil-Bbl Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations Title Technical Assistant Phone > Prepared By Name/Number: 564-4750 Date I)~S-01ondra Stewman, 564-4750 , / RBDMS BFl MAR 0 8 2007 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-08 MPJ-08 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/7/2007 Rig Release: 2/13/2007 Rig Number: N3S Spud Date: 8/10/1994 End: 2/13/2007 From 2/7/2007 00:00 - 10:00 10.00 MOB P PRE Move Rig Camp and Mud Pits to J-pad along with several loads of equipment. Move Rig Sub and Pipe Shed to location. 10:00 - 14:00 4.00 RIGU P PRE Move rig into position to spot rig over well and find that there is not enough room to set BOP cradle. Call Pad Operator and Well Ops Coordinator and dig pipe support out from under pipeline covered by snow drift to make room for cradle. Place cradle with BOP into position. 14:00 - 18:00 4.00 RIGU P PRE Move Rig Sub to spot over well and find that the cellar diameter is greater then the inside footprint of the Derrick leg supports. Get Pad Operator to sign Hot Work Permit and use sniffer to check for gas. Hold PJSM to assist welder in cutting off the top 8-inches of the cellar wall. 18:00 - 00:00 6.00 RIGU P PRE Hold Pre-tour meeting to discuss Plan Forward and review some of the learnings from the rig move to MPJ-08A. Hold PJSM to spot rig over well. Spot rig, center same over well. Excessive rig levelling required due to unlevel well pad. Spot and level pipe shed and fluid pits. 2/8/2007 00:00 - 03:00 3.00 RIGU P PRE Move in Tiger Tank. Prep to raise Derrick. Hold PJSM. Raise Derrick @ 0300 hrs. 03:00 - 06:00 3.00 RIGU N PRE RU Derrick equipment. Prep to telescope Derrick. Hold PJSM. While telescoping the Derrick, an oil mist was observed coming from the off-Driller-side scoping ram. Stopped scoping the Derrick and sent the Derrickman up to look for the source of the mist. Several 1-2" diameter drops of hydraulic oil were discovered in the snow near the rig and immediately cleaned up. Security, Enviro, Pad Operator, MPU Well Ops Supv, and Well Ops Coord were contacted. Inspect and repair Derrick scoping ram on the off-Driller-side. 06:00 - 09:00 3.00 RIGU N PRE Repair scoping ram leak. Scope up Derrick. Install lines to circulate well-kill fluid. Accept rig at 0900-hrs. 09:00 - 20:00 11.00 RIGU N PRE Wait on trucking and forklift to bring berming frames and hardlines to J-pad. Install berm frame for Herculite around Tiger Tank. 20:00 - 22:00 2.00 RIGU P PRE Assemble Tiger Tank hardlines. Notify MPU Security and Pad + Operator of potential gas venting. 22:00 - 23:30 1.50 RIGU P PRE Hold PJSM on pressure testing, killing well, and circulating well fluids to surface. Test Tiger Tank hardlines to 1000 psi. Blow down tank lines with steam and air. Test rig lines to 3500 psi. 23:30 - 00:00 0.50 KILL P DECOMP Open well. ITP = 300 psi. ICP = 340 psi. Rev circ 120 deg seawater @ 1 BPM; csg press falls to 0 psi. Incr rate to 2 BPM, minimal gas in returns. 2/9/2007 00:00 - 00:30 0.50 KILL P DECOMP Fin rev circ total of 20 bbls 120 deg seawater. Recover approx 20 bbls freeze protect fluid and water. Realign valves to circ long way. 00:30 - 01 :00 0.50 KILL P DECOMP Reopen well. ICP = 340 psi, ITP = 60 psi. Circ long way @ 2 BPM, initially gas returns. Liquid returns to surface after 21 bbls pumped. Pressures steady 0 psi. Circ total of 30 bbls. Recovered total of 5 bbls liquid. 01 :00 - 01 :30 0.50 KILL P DECOMP Close annular BOPE. Pump 65 bbls 120 deg seawater down tubing into formation. Pump press 20 psi. Final csg press 140 psi. SITP 20 psi. SICP fell from 120 psi to 20 psi in 10 minutes. 01 :30 - 02:30 1.00 KILL P DECOMP Realign valves to circ long way. Pump in 27 bbls @ 2 BPM, Printed: 2/19/2007 1:06:40 PM ~ ",-,,/ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-08 MPJ-08 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/7/2007 Rig Release: 2/13/2007 Rig Number: N3S Spud Date: 8/10/1994 End: 2/13/2007 From 2/9/2007 01 :30 - 02:30 1.00 KILL P DECOMP had 6 bbls returns. Fill rig pits with seawater. 02:30 - 06:00 3.50 KILL P DECOMP Rev bullhead 1.5 well bore vols (243 bbls) seawater down annulus. Annulus press = 290 psi, OA press = 260 psi. Shut in and monitor well for 30 minutes. Annulus and tubing on vacuum. 06:00 - 09:00 3.00 WHSUR P DECOMP Set TWC and test to 3500 psi from above. Hold PJSM. Nipple down tree. 09:00 - 21 :00 12.00 BOPSUF P DECOMP PJSM. M/U New HCR Valve to Kill Line. Break off 2-ea, 3-1/8" 5M valves from Mud Cross and M/U 2-ea, 2-1/16" 5M valves to Mud Cross. Install Adaptor Spool and N/U BOP Stack. 21 :00 - 00:00 3.00 BOPSUF P DECOMP Attempt to test BOPE to 250 psi low 1 3500 psi high. Could not ./ obtain 3500 psi test. Test attempt witness by C. Scheve and R. Noble, AOGCC. 2/10/2007 00:00 - 02:00 2.00 BOPSUP P DECOMP Continue to attempt BOPE test. Could not obtain 3500 psi test on successive components. 02:00 - 05:00 3.00 WHSUR P DECOMP RU Lubricator and re-seat TWC. Floorhand caught and reported a seawater spill in the Cellar that occurred during the Drawdown test for the Koomey. Seawater came from the Kill line that had been removed, but not blocked. Spill confined to secondary containment in Rig Cellar. Reported spill to MPU Security and Enviro. MPU Enviro (Shane) advised that spill is not reportable. Dipped all the seawater into 3-ea 5-gallon buckets and disposed of it in the Pits. 05:00 - 09:00 4.00 BOPSUR P DECOMP Attempted t~ test new TWC to 3500 psi. Pressure test failed.,.-- Conferred with C. Sheve, R, Noble, AOGCC, BP ADW Engineer, Nabors Tool Pusher, and reviewed the BP ADW Policy for BOP testing. Agreed to use 2000-psi as the maximum pressure for all tests performed against the TWC and Hanger. See further info in "Remarks" tab. 09:00 - 11 :00 2.00 BOPSUP P DECOMP PJSM to P/U lubricator and pull TWC. P/U lubricator and have Well Support personnel pull TWC. The casing and tubing are on a vacuum. During the course of BOPE testing, the well was given a drink by gravity flow from the Pits every 30-minutes, and It took 11-12 Bbls each time to fill the annulus, which puts the fluid level at -370' (MD and TVD) from surface after a 30-min shut-in time. 11 :00 - 15:00 4.00 PULL P DECOMP RIU Schlumberger Spooler on Rig Floor to spool the I-Wire. Ready the Centrilift spooler unit to handle both the Heat Trace and ESP-Cables. Breakoff and UD Hanger. Assess training of the Floorhand and Roustabout assigned to operate the Spooler. SLB/Camco Spooler to be operated by Schlumberger. 15:00 - 18:00 3.00 PULL P DECOMP Tie off ESP cable and Heat Trace cable and pull over Centrilift double sheave. Use steam wand to thaw frozen cementing manifold. Decide to wait until night tour crew has their changeout so that we can hold a PJSM to complete the RIU of the ESP pulling equipment. 18:00 - 21 :00 3.00 PULL P DECOMP PJSM with rig crew, Tour Pusher, Centrilift Technician, Schlumberger Cameo Spoooler operator, and both WSLs to discuss all the operation. Decide to re-tie the ESP cable and Heat Trace cable to ensure equal tension of the lines over the double sheave. Also need to reposition the Schlumberger spooler to line up all three cables for pulling them through the air slips. Printed: 2/19/2007 1 :06:40 PM '-' ",-,/ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-08 MPJ-08 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/7/2007 Rig Release: 2/13/2007 Rig Number: N3S Spud Date: 8/10/1994 End: 2/13/2007 From 2/10/2007 21 :00 - 00:00 3.00 PULL P DECOMP POH with ESP ass'y. 20 stnds OOH @ 0000 hrs. Recovered 205 x 6' heat trace channels, 10 x 4' heat trace channels, 5 x 3' heat trace channels, and 738 heat trace and ESP cable bands. 2/11/2007 00:00 - 08:30 8.50 PULL P DECOMP Cont POH with ESP ass'y. 71 stnds OOH @ 0600 hrs. Recovered total of 380 x 6' heat trace channels, 17 x 4' heat trace channels, 9 x 3' heat trace channels, total of 1260 heat trace and ESP cable bands, and 39 La Salle clamps. At 0130-hrs discovered approx. 1 oz. lube grease and approx. 2 oz. windshield washer fluid under Veco water truck. Reported leaks to MPU Security and MPU J-Pad Op. MPU Enviro (Shane) declined to respond. Both leaks were scraped up and disposed on rig. Double displace tubing + 5-Bbls every 30-min while POH to bottom of heat trace. Double displace tubing thereafter. Well taking -11-Bph. Break out XN-Nipple immediately above the ESP assembly @ 0830-hrs. 08:30 - 14:00 5.50 PULL P DECOMP Break out and UD ESP assembly. 14:00 - 15:00 1.00 PULL P DECOMP Clear and clean Rig Floor to prepare to RIH with new ESP assembly. P/U, M/U, and service ESP components. 15:00 - 00:00 9.00 RUNCOMP RUNCMP P/U new ESP assembly and RIH on 2-7/8", L-BO, EUE 8-Rd tubing from Derrick. Start installing Heat Trace on Joint #40. Check conductivity every 2,000'. Use Best-O-Life pipe dope and torque all connections to 2,300 Ib-ft. At Heat Trace attachment point on stand #20 at 1730-hrs. At OOOO-hrs: 33 stands in hole, with 475 heat trace and ESP cable bands, 130 x 6' heat trace channels, 6 x 4' heat trace channels, 7 x 3' heat trace channels, and 26 La Salle clamps. Well taking about 9 bblslhr seawater. 2/12/2007 00:00 - 20:30 20.50 RUNCOMP RUNCMP Cont RIH with new ESP assembly on 2-7/8", L-80, EUE 8-Rd ~ tubing from Derrick. Check ESP cable conductivity every 2,000'. Use Best-O-Life pipe dope and torque all connections to 2,300Ib-ft. At 0400-hrs: 40 stands in hole. Well taking about 10-Bph seawater. Stand #59 at 11 OO-hrs. Stand #70 at 1600-hrs. At 1815-hrs a floorhand cut his right forearm on a sharp piece of cable band. See remarks section for further information. MU Tubing Hanger, XO and Landing Joint. Torque LJ to XO with 10,000 Ib-ft. 20:30 - 00:00 3.50 RUNCOMP RUNCMP Install Heat Trace and ESP cable penetrators in tubing hanger. Splice heat trace and ESP cables. Well continuing to take about 10-Bph seawater. 2/13/2007 00:00 - 04:00 4.00 RUNCOMP RUNCMP Cont to splice heat trace and ESP cables. Heat trace impedance 4.4 ohm phase to phase and 250 gigaohm phase to ground. ESP cable impedance 2.2 ohm phase to phase and 2.0 gigaohm phase to ground. Final tally: 527 x 6' heat trace channels, 16 x 4' heat trace channels, 6 x 3' heat trace channels, and 1831 heat trace and ESP cable bands. Well continuing to take about 10-Bph seawater. 04:00 - 06:30 2.50 RUNCOMP RUNCMP Filled tubing with seawater and flushed with additionaI10-Bbls.· Landed tubing hanger. PU 41,000-lb, SO 36,000-lb. RILDS. 06:30 - 08:00 1.50 BOPSUF P RUNCMP Cameron Tech installed the TWC. Nipple down BOPE and UD BOP stack on transport cradle. 08:00 - 13:00 5.00 WHSUR P RUNCMP N/U Adaptor Flange and Tree and test to 5,000-psi. Test pressure kept bleeding off. Pull TWC and re-seat. Test pressure bled off at a slower falloff rate. Bumped the test pump Printed: 2/19/2007 1:06:40 PM ~ ."-" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-08 MPJ-08 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/7/2007 Rig Release: 2/13/2007 Rig Number: N3S Spud Date: 8/10/1994 End: 2/13/2007 2/1312007 08:00 - 13:00 5.00 WHSUR P RUNCMP pressure up 4-times and pressure held solid at 5,OOO-psi. Pull TWC and install BPV. Release rig at 1300-hrs. RUNCMP Rig down rig components. Check MPJ-04 location preparation. 13:00 - 16:00 3.00 WHSUR P Printed: 2/19/2007 1:06:40 PM DATA SUBMITTAL COMPLIANCE REPORT Permit to Drill No. 1991170 Well Name/No. MILNE PT UNIT SB J-08A 2/5/2002 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22497-01-00 MD 8494 TVD 4107 Completion Date 12/29/1999 Completion Status 1-OIL Current Status I-OIL UIC N REQUIRED INFORMATION Mud Log N.~_o Samples N_9_o Directional Survey No -- ~2 ......................... __-_'~-~.--~?~2--__2_-_~2 7"~ ~ 2C. '._-. ~ _~22~___ ~.· '_-_' 2.~5~_~ ~~---~_~__-i~2__'-~ ~2_ ~_' ......................... 2___~ ~_~-_2_-_~.~.~ _-~_ ~_i~ ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Log Log Run Interval OH / Dataset Type Media Format N/ame Scale Media No Start Stop CH Received Number Comments i~ ................................. ~-[- s'RQY-RbT 88 8495 OH 2/16~2000 SPERRY 4816.. · / DGR/EWR-MD 25 FINAL 4868 8495 OH 3/9/2000 ~2~' DGR/EWR-TVD 25 FINAL 3850 4107 OH 3/9/2000 T O 3/7/2000~,,9~'~i09 4760-8440 Well Cores/Samples Information: ......................................................................... (data taken from Logs Portion of Master Well Data Maint) Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~'~ Daily History Received? ?~N Formation Tops Receuived? '("~ Comments: Compliance Reviewed By: Date' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. !. Supe~isor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: April 22, 2001 Safety Valve Tests Milne Point Unit J &l Pads Sunday April 22, 2001.: I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work ~th. I also inspected the well houses on these pads during the SVS testing. All the wellhouses were very clean and the equipment appeared to be in excellent condition. Summary: I witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 11~wells 22 components 0 failures MPU I Pad 6 wells '12 components 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Safety Valve System Test Report Submitted By: ~Chuck Scheve Date: Field/UniffPad: Milne Point / MPU / I Pad Separator psi: LPS 140 HPS 4/22/01 . i i i . · i i I i i i i i _i i i i i ;~::i:i~ ~?:;'::7-.) i. !"SSV- SSSV · Retest Well Type WeB Pemit Separ Set L~ T~t Test Test Date ~!, WAG, G~J, Number Number PSI PSI Trip Code Code Code Pass~ GAS or CYCLE i oi o9oo .................. [02' 1900910 .... 140 100 95 ' "~" P ..... OIL~ i203 1900920 " i~O 1~0 95 P P OIL I-~ 190~30 ' '140 100 95 P P ' ' OIL 1-06 1971950 ' 140 100 "95~ P P .... OIL 1-07 19515i0 140 "iO0 9~" 'e ' 'P ........ OIL ~-08 1971920 140 100 95 "P' 'P ..... ~I'~ . , , . . ., , , .. ~ . .., ,, ., · . , .. , , , . Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% [] 9o Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Huime AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Milne Point / MPU / J Pad Separator psi: LPS 140 HPS 4/22/01 i i i ii . ii i i i i i i i · i i i i ?'--? ~ ?S?. sssv Retest Well Type .' i [ i Well Permit Separ Set L/P Test Test Test Date oa, WAa, Gm J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE J-01A '" 1991110 ' 140 100 95 "P ..... P ...... OIL J-03 1900970 140 100 ' 95 P 'P ...... OiL -- - , . , . , , ,, ,, J-04 1900980 140 100 95 P P OIL J-05 1910950 140 100 95 ' P" P ..... Oi~L J-06 1940950 140 100 125 e P OIL J-07 ' i'9ii)¢70 ' 140 ' 100 ' 95 ' ' P' ..... P OiL J-08A 1991170 140 100 95 e' P .... oIL J-09A 1991140 140 100 110 P P OIL J-10 1941100 ' '140 100 " 95 "e" P ' OIL J-11 1941'140 .............. J-12 1941180 J- 18 1972200 J-19A 1951700 J-20 19'72150' ' J-21 1972000 140 1 oo 95 p e OIL '~I-22 "1~J8i240" 140 f00 9~ P ' 'e .... OIL J-23 "2001200 ' ' ' Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU J Pad 4-22-01 CS WELL ! ,oc. ~T~A~NS~NilTT&L To: State of Alaska Alaska Oil and Cra_s Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchome, Alaska 99501 \C-~ C~- MWD Formation Evaluation Logs - MPJ-08& AK-MM-90211 March 09, 2000 2" x 5" TVD Resistivi~ and Gamma Ray Logs: 50-029-22497-01 ! Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia P~._~.a~SE AC!CNOWLE..DGE B~CE_.!PT BY S!GNLNG A~ .NI) RETURNLNG THE ATTACHED COPIES OF THE TRANSMKFrAL LETrER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIV£D 0 9 2000 G~s Cons. C0mmis~bn Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Sis ~ '~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company WELL LOG TRANSM]TrAL To: State of Alaska March 7, 2000 Alaska Oil and Gas Conservation Cornrn. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPJ-08A, AK-MM-90211 1 LDWG formatted Disc with verification listing. API#: 50-029-22497-01 PLEASE A~OWLE. DGE RECEH'T BY SIGNLNG .4~ND RETURNING THE ATTACHED COPIES OF Tr~. TU~&NS~MATTAL LETTER TO ~ ATTENTION OF: Sperry-Sun Drilling Services Attn: Jan Galvin 5631 Silverado Way, Suite G. Anchor~e, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date:,~,t,kR ._q,. 7. ~.O000 Alaska 0it 8, Gas Cons. Commission Anchorage Si._maed: 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended I~ Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 199-117 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22497-01 4. Location of well at surface ; ~':-i ,.'ii~?~.:~ '!~'.~ ' ~ 9. Unit or Lease Name 2576' NSL, 1938' EWL, Sec. 28, T13N, R10E, UM ~,,~'. - !!~~.~, Milne Point Unit At top of productive interval ~ 10. Well Number At total depth ~'~.'~~ .... ... 11. Field and Pool 111' NSL, 2503' WEL, Sec. 20, T13N, R10E, UM Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 66' AMSL~ ADL 025515 ......... 12. Date Spudded12/18/99 113' Date T'D' Reached I 14' Date C°mp" Susp" °r AbanO'115' Water depth' if °"sh°re 116' N°' °f C°mpleti°nsl 2/22/99 12/29/99 N/A MSL One 17. Total Depth (MD+~D) ~18. Plug Back Depth (MD+~D) 19. Directional Su~ey ~0. Depth where SSSV set 21. Thickness of Permafrost 8495 4107 FT] 8495 4107 FT ~Yes ~No~ N/A MD 1800' (Approx.) ~}. Type Electric or Other Logs Run ~,!~IHAI MWD, GR, RES, PWD . 23. CASING~ LINER AND CEMENTING RECORD ~ ...... CASING S~ING DEPTH HOLE SIZE WT. PER FT. G~DE TOP BO~OM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5~ K-55 32' 112' 24" 250 sx Arctic Set (Approx.) 9-5/8" 40~ L-80 33' 2516' 12-1/4" 504 sx PF 'E', 250 sx Class 'G' 7" 26~ L-80 29' 4866' 8-1/2" 220 sx Class 'G' 4-1/2" 12.6~ L-80 4729' 8495' 6-1/8" 84 sx Class 'G' 24. Perorations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and inte~al, size and number) S~ZE DEPTH S~ (MD) PACKER S~ (MD) 4-1/2" SIo~ed Liner 2-7/8", 6.5ff, L-80 4665' MD TVD MD TVD 5901' - 8451' 4118' - 4105' 26. ACID, FRACTURE, CEMENT SQUEAL, ~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 70 Bbls of Dead Crude Freeze Protect with 22 Bbls of Diesel 27. PRODUCTION TEST Date First Production l Method of Operation (Flowing, gas lift, etc.) Janua~ 30, 2000 J Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I FI0w Tubing Casing Pressure CALCU~TE OIL-BBL GAS-MCF WATER-BBL O~L CRAWl-APl (CORR) Press. 9 24-HOUR 28. RATE CORE DATA ........... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. SBF2 - NA 5057' 3893' SBF1 - NB 5100' 3904' SBE4 - NC 5182' 3928' SBE2- NE 5253' 3951' SBE1 - NF 5405' 4004' TSBD - CA 5503' 4040' TSBC 4014 5597' 4073' TSBB - OB 5783' 4110' 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 ¢'~'J~_~ Title Technical Assistant Ill Date M PJ-08A 199-117 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. RECEIVED ITEM 28: If no cores taken, indicate 'none'. . 'i 6 2009. Form 10-407 Rev. 07-01-80 Facility Date/Time 16 Dec 99 17 Dec 99 M Pt J Pad Progress Report Well MPJ-08A Page 1 Rig Nordic3 Date 06 January 00 12:01-15:30 12:01-14:00 14:00 14:00-15:30 15:30 15:30-17:00 15:30-16:00 16:00 16:00-16:30 16:30 16:30-17:00 17:00 17:00-18:30 17:00-18:30 18:30 18:30-20:30 18:30-20:00 20:00 20:00-20:30 20:30 20:30-23:00 20:30-23:00 23:00 23:00-00:00 23:00-00:00 00:00 00:00-06:00 00:00-01:00 01:00 01:00-03:30 03:30 03:30-04:00 04:00 04:00-05:00 05:00 05:00-06:00 06:00-13:00 Duration 3-1/4 hr 1-3/4 hr 1-1/2 hr 1-1/2 hr 1/2 hr 112 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr lhr lhr 6hr lhr 2-1/2 hr 1/2 hr lhr lhr 7hr Activity Move rig Rig moved 100.00 % Move onto MP J-08A. Rig accepted @ 1400 hrs on 12/16/99. At well location - Cellar Installed Drillfloor / Derrick Berm up pit liner. Set tanks & buildings. Thaw cellar ro access annulus valves. Equipment work completed Wellhead work Removed Hanger plug Pull BPV. Equipment work completed Installed Hanger plug Set TWC. Eqpt. work completed, running tool retrieved Removed Xmas tree ND tree & adapter. Equipment work completed Nipple up BOP stack Rigged up BOP stack NU & function test rams. Work completed - BOP stack in position Wellhead work Removed Tubing hanger PU landing jt. Screw into hanger. Check for pressure. BOLDS. Pull hanger & LD. Equipment work completed Installed BOP test plug assembly Set test plug. Prep to test stack. Eqpt. work completed, running tool retrieved Test well control equipment Tested BOP stack Test BOPE to 250 / 2000 psi-OK. Witnessing waived by John Crisp-AOGCC Field Inspector. Pressure test completed successfully - 2000.000 psi Wellhead work Installed Wear bushing Pull test plug. Set wear ring. Eqpt. work completed, running tool retrieved BHA run no. 1 Rigged up Drillstring handling equipment Work completed - Drillstring handling equipment in position Made up BHA no. 1 MU mill assembly f/dummy run. PU 12-4.75" DC & 36-3.5" HWDP. BHA no. 1 made up R.I.H. to 2200.0 ft Stopped: To circulate Circulated at 2200.0 ft Circ out freeze protect diesel w/120 deg seawater. Hole displaced with Seawater - 150.00 % displaced R.I.H. to 3900.0 ft BHA run no. 1 (cont...) RECEIVED' aOi[&C. sC s. Ce Facility Date/Time M Pt J Pad Progress Report Well MPJ-08A Page Rig Nordic3 Date 2 06 January 00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-07:15 07:15 07:15-08:15 08:15 08:15-08:30 08:30 08:30-08:45 08:45 08:45-09:30 09:30 09:30-11:00 11:00 11:00-13:00 13:00 13:00-06:00 13:00-14:00 14:00 14:00-14:30 14:30 14:30-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-20:30 20:30 20:30-23:30 23:30 23:30-00:00 Duration 1/2 hr 1/2 hr 1/4 hr lhr 1/4 hr 1/4 hr 3/4 hr 1-1/2 hr 2hr 17hr lhr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 3hr 1/2 hr Activity Serviced Top drive Service rig & top drive. Equipment work completed R.I.H. to 4783.0 ft Observed loss of 4000.00 klb string weight Circulated at 4783.0 ft Start circ to wash through tight spot. Had seawater spill outside. Stop circ & all personnel respond outside. Stopped · Flowline plugged Held safety meeting Respond to spill. Thaw cuttings chute. Attempt to clean-uo spill. Everything frozen. Held safety meeting to discuss incident. LCIR/f10587. Completed operations Reamed to 4785.0 ft Wash & ream past tight spot several times-OK. No further resistance R.I.H. to 4887.0 ft Washed 2' to top of retainer. On bottom Circulated at 4887.0 ft Circ sweep. Pump dry job. Blow down. Hole swept with slug - 120.00 % hole volume Pulled out of hole to 1520.0 ft At BHA Pulled BHA LD bumper sub & jars. BHA Stood back BHA run no. 2 Made up BHA no. 2 MU BHA. Orient. Stopped · To hold safety meeting Held safety meeting Held pre-spud meeting with all personnel. Completed operations Made up BHA no. 2 MU whipstock. Run DC's. Test MWD. Blow down. BHA no. 2 made up Serviced Top drive pipe handler Serv pipe handler. Change elevators. Equipment work completed Held safety meeting PJSM on RIH w/whipstock. Completed operations R.I.H. to 4885.0 ft On bottom Functioned downhole tools at 4885.0 ft Break circ. Orient whipstock. Set anchor-OK. Attempt to shear off several times. Did not see bolt shear. Question as to whether whipstock is oriented. Consult with service personnel & w/Anch drilling. Equipment work completed Circulated at 4867.0 ft Displace well to --:":-- '~'-:~ 111111111~ 1 Il IIILI, RECEIVED Facility M Pt J Pad Progress Report Well MPJ-08A Page 3 Rig Nordic3 Date 06 January 00 Date/Time 18 Dec 99 00:00 00:00-04:30 04:30 04:30-06:00 06:00 06:00-10:00 06:00-06:30 06:30 06:30-08:30 08:30 08:30-10:00 10:00 10:00-06:00 10:00-13:00 13:00 13:00-16:00 16:00 16:00-17:00 17:00 17:00-17:30 17:30 17:30-06:00 19 Dec 99 06:00-06:00 06:00-07:30 07:30 07:30-11:00 11:00 11:00-12:00 12:00 12:00-12:30 12:30 12:30-14:00 14:00 14:00-19:30 Duration 4-1/2 hr 1-1/2 hr 4hr 1/2hr 2hr 1-1/2 hr 20 hr 3hr 3hr lhr 1/2 hr 12-1/2 hr 24 hr 1-1/2 hr 3-1/2 hr lhr 1/2 hr 1-1/2 hr 5-1/2 hr Activity X~ Hole displaced with Water based mud - 100.00 % displaced Milled Casing at 4892.0 ft Milled window f/4866'-80', as per procedure. Completed operations Circulated at 4892.0 ft Circ sweeps while working mills through window. Cleaned up good. Window appears smooth. Obtained clean returns - 200.00 % hole volume BHA run no. 2 (cont...) Circulated at 4892.0 ft Pump dry job. Blow down. Heavy slug spotted downhole Pulled out of hole to 1548.0 ft At BHA Pulled BHA guage [ ~;''~ ~ ~ ~}000 LD milling assembly. All mills in . BHA Laid out jt,~itOij & ~lS Coils. Coil BHA run no. 3 ~0f~ Made up BHA no. 3 MU drlg BHA. Orient. Load MWD. PU NMDC's. Test motor & MWD. BHA no. 3 made up R.I.H. to 4850.0 ft Stopped: To service drilling equipment Serviced Top drive Change out saver sub. Service top drive, swivel & blocks. Equipment work completed Circulated at 4892.0 ft Break circ. Orient 10-L. Slide through window. Tag bottom. Broke circulation Drilled to 5415.0 ft Extrapolating surveys back, it appears that the whipstock was most likely set at the correct orientation ( 30L of Hi ). BHA run no. 3 (cont...) Circulated at 5415.0 ft Circ sweeps. Rotate & reciprocate 30'off bottom. Abandon rig drill; OS-1:15 min. Hole swept with slug - 150.00 % hole volume Drilled to 5609.0 ft Stopped: To take survey Took MWD survey at 5609.0 ft Do IFR calculations. Acceptable survey obtained at 5545.0 ft Drilled to 5675.0 ft Began precautionary measures Circulated at 5675.0 ft Circ HiVis / HiFiber weighted sweeps. Rotate & reciprocate 20' off bottom. Hole swept with slug - 150.00 % hole volume Drilled to 5996.0 ft RECEIVED Facility Date/Time 20 Dec 99 21 Dec 99 22 Dec 99 M Pt J Pad Progress Report Well MPJ-08A Page 4 Rig Nordic3 Date 06 January 00 19:30 19:30-20:30 20:30 20:30-22:00 22:00 22:00-23:00 23:00 23:00-23:30 23:30 23:30-01:00 O1:00 O1:00-02:00 02:00 02:00-05:00 05:00 05:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-06:00 08:00-09:00 09:00 09:00-12:30 12:30 12:30-15:00 15:00 15:00-06:00 06:00-06:00 06:00-05:00 05:00 05:00-06:00 06:00-06:00 06:00-07:00 Duration lhr 1-1/2 hr lhr 1-1/2 hr lhr 3hr lhr 2hr 2hr 22 hr lhr 3-1/2 hr 2-1/2 hr 15hr 24 hr 23 hr lhr 24 hr lhr Activity Stopped: To circulate Circulated at 5996.0 ft Circ HiVis / HiFiber, followed by HiVis sweep. Rotate & reciprocate 30' off bottom. Hole swept with slug - 120.00 % hole volume Pulled out of hole to 4930.0 ft Stopped: To take survey Logged hole with LWD: FE/DD from 4930.0 ft to 4815.0 ft Logged up for tie-in to original well. Log up over interval from 4930.0 ft to 4815.0 ft Dropped EMSS survey barrel Drop ESS. Pump down @ 15 spm. Blow down top drive. Survey barrel on bottom at 4780.0 ft R.I.H. to 5996.0 ft RIH. Stop every 30' for ESS. Hole in good shape. On bottom Circulated at 5996.0 ft Circ & cond. Rotate & reciprocate 30'. Obtained clean returns - 150.00 % hole volume Pulled out of hole to 433.0 ft D 1 Drill; OS-40 sec. At BHA Pulled BHA Recover ESS. BHA Stood back BHA run no. 3 (cont...) Downloaded MWD tool Interpret MWD & ESS Data. Service top drive & rig. H2S Drill; OS-1:15 min. Completed operations BHA run no. 4 Made up BHA no. 4 Load MWD. Test MWD. Blow down. BHA no. 4 made up R.I.H. to 5996.0 ft Hole in good shape. On bottom Circulated at 5996.0 ft Rotate & reciprocate. Pump Lo-Hi sweeps. Displace hole to 9.1 ppg Baradril-n. Hole displaced with Water based mud - 100.00 % displaced Drilled to 7043.0 ft Pumped sweeps as necessary (-300'). BHA run no. 4 (cont...) Drilled to 8495.0 ft Continue Horizontal drlg 6-1/8" hole F/7043' to 8495'. Dilute mud system w/300 bbl's new mud at 7500'. Pump sweeps as needed.. Reached planned end of run - Section / well T.D. Circulated at 8495.0 ft Circulate and condition hole at 8495' TD BHA run no. 4 (cont...) Circulated at 8495.0 ft Continue to circulate, Reciporicate and condition ~'^'- @ TD 8495' llUl~, RECEIVED 't 2 6 000 NaskaOil&GasCoas. Facility M Pt J Pad Progress Report Well MPJ-08A Page Rig Nordic3 Date 5 06 January 00 Date/Time 07:00 07:00-08:00 08:00 08:00-09:00 09:00 09:00-10:30 10:30 10:30-12:00 12:00 12:00-13:00 13:00 13:00-13:15 13:15 13:15-15:30 15:30 15:30-16:00 16:00 16:00-16:30 16:30 16:30-18:30 18:30 18:30-23:00 23:00 23:00-01:30 23 Dec 99 01:30 01:30-02:30 02:30 02:30-04:00 04:00 Duration lhr lhr 1-1/2 hr 1-1/2 hr lhr 1/4 hr 2-1/4 hr 1/2 hr 1/2 hr 2hr 4-1/2 hr 2-1/2 hr lhr 1-1/2 hr Activity Obtained clean returns - 200.00 % hole volume Pulled out of hole to 7060.0 ft Started short trip to 7" casing shoe after pulling 15 stands. Hole not taking fluid. Stopped: Incorrect trip volume R.I.H. to 8045.0 ft RIH to 8045' tight spot. Kelly up circulate bottoms up. circ, recip and rotate. Observed loss of 20.00 klb string weight Circulated at 8045.0 ft Recip,Circulate bottoms up gas & oil cut mud. ECD 11.2 ppg. Pumped @ 120 spin 1950 psi. Obtained clean returns - 200.00 % hole volume R.I.H. to 8495.0 ft Wash and rotate back to bottom @ 8495'. On bottom Pulled out of hole to 8045.0 ft Pull 5 stands. Gained 3.2 bbl's Stopped: Incorrect trip volume R.I.H. to 8495.0 ft RIH to 8495' Gained 2 bbl's On bottom Circulated at 8495.0 ft Circ out gas & oil cut mud. Rotate and recip while Raiseing mud weight f/9.3 to 9.6 ppg Obtained req. fluid properties - 200.00 %, hole vol. Pulled out of hole to 8045.0 ft Pulled 5 std's Gained 1.2 bbls Stopped: Incorrect trip volume R.I.H. to 8495.0 ft RIH to 8495' Gaiined .8 bbl On bottom Circulated at 8495.0 ft Circ out gas & oil cut mud. Cut YP 100 spin @ 1750 psi. After well bore clean ECD 11.1 ppg Obtained clean returns - 250.00 % hole volume Pumped out of hole to 4688.0 ft Pump out of hole. Hole taking the right fluid displacement, At Kick off depth: 4688.0 ft Serviced Block line Slip and cut drilling line. Service top drive. Shut well in and monitor. No pressure increase. Check for flow well dead. Line slipped and cut Circulated at 4875.0 ft RIH to 4875' Do torque and drag and circulate bottoms up. No gas or oil cut mud casing clean. Obtained clean returns - 200.00 % hole volume R.I.H. to 8495.0 ft RIH to 8420' M/U top drive washed to bottom @ 8495'. Fluid displacement correct no fluid loss. On bottom RECEIVED i 6 000 Na aOil&GasCons. Facility M Pt J Pad Progress Report Well MPJ-08A Page 6 Rig Nordic3 Date 06 January 00 Date/Time 04:00-06:00 06:00-16:30 06:00-07:00 07:00 07:00-11:30 11:30 11:30-12:30 12:30 12:30-14:00 14:00 14:00-16:30 16:30 16:30-06:00 16:30-18:00 18:00 18:00-18:30 18:30 18:30-01:00 24 Dec 99 01:00 01:00-02:00 02:00 02:00-06:00 06:00-06:00 06:00-09:30 09:30 09:30-10:00 10:00 10:00-11:00 11:00 11:00-12:30 Duration 2hr 10-1/2 hr lhr 4-1/2 hr lhr 1-1/2 hr 2-1/2 hr 13-1/2 hr 1-1/2 hr 1/2 hr 6-1/2 hr lhr 4hr 24 hr 3-1/2 hr lhr 1-1/2 hr Activity Circulated at 8495.0 ft Circulate @ 120 spm 1950 psi bottoms up. Cuttings from angle build section, Dark mud from horizonal section cut from 9.6 to 9.5+ ppg. Back to clean mud at bottom up. BHA run no. 4 (cont...) Circulated at 8495.0 ft Continue pumping sweep while rotating & percipercate till well clean Obtained clean returns - 250.00 % hole volume Pumped out of hole to 4860.0 ft Pump out of hole to controal swabing. Hole taking the right amount of fluid. At 7in casing shoe Flow check Pump dry job, Monitor well and drop pipe drifts. Observed well static Pulled out of hole to 400.0 ft At BHA Downloaded MWD tool Down load MWD, L/D motor, Jars & bit Completed operations Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment Work completed - Handling equipment in position Held safety meeting Completed operations Ran Liner to 3760.0 ft (4-1/2in OD) PFLI 4.5' Bonzai slotted liner. Run 62 jt's slotted, 28 28 solid jt's W/Baker ECP packer Stopped: To pick up/lay out tubulars Held safety meeting R/U to run 2.875" inside work string. Hold safety meeting partaing to well control while running. Completed operations Ran Liner to 3745.0 ft (2-7/8in OD) PFLI Baker Bonzai 2.875" enter working string Run Liner, 4-1/2in O.D. (cont...) Ran Tubing to 3740.0 ft (2-7/8in OD) Continue running Baker inter work string 2.875" W/ Bonzai cup tool. Spaced out and made up 2.875" to liner hanger tool. M/U 7" X 4-1/2" liner hanger to 4.5" liner. At Top of liner: 3791.0 ft Circulated at 3791.0 ft Circulate liner volume. Total liner w/2.875" inter work string. Up weihgt 83k, Dn weight 80k Slow circulation rates completed Ran Liner on landing string to 4840.0 ft RIH on 3.5" HWDP to 4840' At 7in casing shoe Ran Drill collar on landing string to 5704.0 fl Run total of 36 joints 3.5" HWDP P/U 16 4.75"X 2.25" DC's ran 4 stands 4.75" dc's out of derrick, to RECEIVED Facility M Pt J Pad Progress Report Well MPJ-08A Page 7 Rig Nordic3 Date 06 January 00 Date/Time 12:30 12:30-14:30 14:30 14:30-19:00 19:00 19:00-19:30 19:30 19:30-00:00 25 Dec 99 00:00 00:00-02:00 02:00 02:00-03:00 03:00 03:00-06:00 06:00-06:00 06:00-08:00 08:00 08:00-09:00 09:00 09:00-11:30 11:30 11:30-12:00 12:00 12:00-12:30 12:30 12:30-14:30 Duration 2hr 4-1/2 hr 1/2 hr 4-1/2 hr 2hr lhr 3hr 24 hr 2hr lhr 2-1/2 hr 1/2 hr 1/2 hr 2hr Activity Stopped · To pick up/lay out tubulars Ran Drillpipe in stands to 8495.0 ft Continue to run 4.5" Bonzai slotted liner to TD @ 8495. Made up cement rotating head to string. On bottom Circulated at 8495.0 ft Break circulation @ 1 bpm 540 psi. Increase rate to 2.5 bpm @ 850 psi. Light oil cut mud at bottoms up. Obtained clean returns - 250.00 % hole volume Held safety meeting Safety meeting w/dowell & crew on setting & cementing 4.5" Bonzai liner. Completed operations Ran Liner to 8495.0 ft (4-1/2in OD) Drop ball and release f/hanger @ 4714'. Pull inter string up to ECP packer. Inflate packer. Open HMCV, Cement w/15 bbl's 15.8 ppg disp. to with in 1/2 bbl 14.5 bbl behind pipe. Close HMCV. CIP 2400 hrs Stopped · To flowcheck well HMCV closed O.K., Circulated at 4790.0 ft Shear out inflation tool dump valve. Reverse 2 bbl's to dowell. Pump long way with rig pumps saw 2 bbls cement contaminated mud back. Pump sweeps to cean up 7"casing. Hole swept with slug - 200.00 % hole volume Ran Liner to 8495.0 ft (4-1/2in OD) Set Baker 7" X 4.5" liner top packer @ 4714' Packer set at 4714.0 ft Pulled Drillpipe in stands to 7000.0 ft Pull 15 std's monitor well not taking fluid right. Well static at surface. Run Liner, 4~1/2in O.D. (cont...) Pulled Drillpipe in stands to 5775.0 ft Continue POOH stand back DP to 5775. Hole continue's not to take the right amount fluid for displacement. Well static No Flow. Stopped · To pick up/lay out tubulars Laid down 864.0 ft of Drill collar L/D 28 it's 4.75" DC'S Stopped ' To pick up/lay out tubulars Laid down 1109.0 ft of HWDP L/D 36jt's of 3.5" HWDP Stopped · To pick up/lay out tubulars Pulled Tubing in stands to 5700.0 ft Pull and stand back 2.875" tbg. Stopped · To pick up/lay out tubulars Laid down 120.0 ft of Tubing L/D Inter string Cup tools. P/u 3 jt's 2.875" tbg. 3 joints laid out Ran Tubing in stands to 8450.0 ft RECEIVED '-- 'i 6 20O · .. ~ AlaskaOii&Gas Cons. Facility M Pt J Pad Progress Report Well MPJ-08A Page 8 Rig Nordic3 Date 06 January 00 Date/Time 14:30 14:30-18:00 18:00 18:00-20:30 20:30 20:30-22:30 22:30 22:30-01:15 26 Dec 99 01'15 01'15-02:00 02:00 02:00-03:00 03:00 03:00-04:30 04:30 04:30-06:00 06:00 06:00-19:30 06:00-07:00 07:00 07:00-15:30 15:30 15:30-19:30 19:30 19:30-02:00 19:30-00:00 27 Dec 99 00:00 00:00-02:00 02:00 Duration 3-1/2 hr 2-1/2 hr 2hr 2-3/4 hr 3/4 hr lhr 1-1/2 hr 1-1/2 hr 13-1/2 hr lhr 8-1/2 hr 4hr 6-1/2 hr 4-1/2 hr 2hr Activity On bottom Circulated at 8450.0 ft Break circ @ 1 bpm 370 psi. Increase rate slowly to 72 spm 790 psi. Gas & oil @ surface 2400 stks. Circ thru choke and gas buster. After bottoms up open well circ @ 100 spm 1310 psi Obtained bottoms up (100% annulus volume) Circulated at 8450.0 ft Pump sweep reciprocate and followed w/9.6 ppg salt water110 spm @ 1410 psi. Followed by hi-vas sweep. Stopped · To flowcheck well Flow check Check for flow. Well flowing slightly 3/4 bbl in 45 min. Shut in and put on gauges after 30 min 10 psi on annulus. Observed 0.750 bbl gain in annulus in 0.75 hr Circulated at 8450.0 ft Circ and raise weight frm 9.6 to 9.8 ppg Stopped · To flowcheck well Flow check Monitor flow with salt water weigth @ 9.8 ppg. Observed well static Circulated at 8495.0 ft Spot 80 bbl's Dowell enzyme weighted to 9.8 ppg across horizontal section. F/8495 to 5500' Water spotted downhole Racked back Drillpipe POOH 28 std's 3.5" DP to 5700' Stopped · To circulate Flow check Flow check well @ 5700', While loading filtered 9.6 ppg in rig tanks, Raise weight from 9.6 to 9.8 Observed well static Run Liner, 4-1/2in O.D. (cont...) Circulated at 5700.0 ft Displace well with 9.8 ppg Filtered salt water 400 bbl's 140 spm @ 2000 psi. Reciporcate pipe while circ. up wt. 55k, Dn wt. 53k RECEIVED Obtained clean returns - 200.00 % hole volume Laid down 7300.0 ft of 3-1/2in OD drill pipe L/D 234 joints of 3.5" DP. 234 joints laid out Laid down 3700.0 ft of Tubing R/U & L/D 119 joints of 2.875" Fox tubiO~ltli[l$&G$S O0iI$.,~ At Surface' 0.0 ft Run Other completion type completion, 3-1/2in O.D. Ran Tubing to 4350.0 ft (3-1/2in OD) P/U & RIH w/3.5" 9.3# L-80 Eue 8rd tbg 141 joints. Stopped · To pick up/lay out tubulars Pulled Tubing in stands to 4300.0 ft POOH Stand back in derrick. For ECP completion. Completed operations Facility M Pt J Pad Progress Report Well MPJ-08A Page 9 Rig Nordic3 Date 06 January 00 Date/Time 02:00-06:00 02:00-05:00 05:00 05:00-05:30 05:30 05:30-06:00 06:00-06:00 06:00-08:00 08:00 08:00-10:00 10:00 10:00-11:00 11:00 11:00-15:30 15:30 15:30-16:30 16:30 16:30-01:30 28 Dec 99 01:30 01:30-02:30 02:30 02:30-06:00 02:30-06:00 06:00-11:00 06:00-09:30 09:30 09:30-11:00 11:00 Duration 4hr 3hr 1/2 hr 1/2 hr 24 hr 2hr 2hr lhr 4-1/2 hr lhr 9hr lhr 3-1/2 hr 3-1/2 hr 5hr 3-1/2 hr 1-1/2 hr Activity Run Other completion type completion, 3-1/2in O.D. Rigged up Tubing handling equipment R/U to run 3.5" ESP completion. Stopped: To hold safety meeting Held safety meeting Safety meeting on running ESP completion and w/New Spooling unit on rig floor. Completed operations Ran Tubing in stands to 50.0 ft P/U & M/U Centralift ESP pump & motor Run Other completion type completion, 3-1/2in O.D. (cont...) Rigged up sub-surface equipment - ESP P/U ESP motor and attach ESP cable. Equipment work completed Conducted slickline operations on Slickline equipment - Tool run R/U slickline and install pump. Test same to 2500 psi for 15 minutes. Pull test plug and R/D slickline Completed run with ESP to 27.0 ft Installed Downhole pressure gauge cable Install BOT 1-wire. Equipment work completed Ran Tubing in stands to 2351.0 ft PHD failed. BOT I-wire tested OK. Began precautionary measures Stopped to install Raychem heat trace cable. Installed Control lines Install Raychem heat trace cable 14 ft down from box end of joint # 73 (2256'). Equipment work completed Heat trace continuity test failed. Bad connector will need to be spliced before attaching to penetrator. Ran Tubing in stands to 4633.0 ft Continue to RIH w/3-1/2" tbg, heat trace, ESP, and 1-wires, making periodic continuity checks. On bottom Installed Tubing hanger Space out and m/u tubing hanger. Install ESP cable penetrator. Stopped: To splice cable Serviced Control lines Splice heat trace cable. Serviced Control lines Continue to splice heat trace cable. Install 1-wire and test same. Run Other completion type completion, 3-1/2in O.D. (cont...) Serviced Control lines (cont...) Continue to splice heat trace cable. Install I-wire and test same. Equipment work completed Installed Tubing hanger Land tubing hanger, RILDS. Eqpt. work completed, running tool retrieved RECEIVED 200 Facility M Pt J Pad Progress Report Well MPJ-08A Page 10 Rig Nordic3 Date 06 January 00 Date/Time 29 Dec 99 11:00-12:30 11:00-12:30 12:30 12:30-16:30 12:30-13:00 13:00 13:00-14:30 14:30 14:30-16:00 16:00 16:00-16:30 16:30 16:30-17:00 16:30-17:00 17:00 17:00-18:00 17:00-18:00 18:00 18:00-00:00 18:00-23:00 23:00 23:00-23:30 23:30 23:30-00:00 00:00 00:00-01:30 00:00-01:00 01:00 01:00-01:30 01:30 01:30-06:00 01:30-04:00 04:00 Duration 1-1/2 hr 1-1/2 hr 4hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 6hr 5hr 1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 4-1/2 hr 2-1/2 hr Activity Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Tubing head spool M/U tubing spool and tree. Heat trace wire did not test. Aborted equipment work Installed BOP stack Equipment work completed Removed Tubing hanger M/U landing joint, BOLDS, pull hanger to floor. Check heat trace cable. Test good. Check penetrator. Test good. Equipment work completed Installed Tubing hanger Land hanger. RILDS. Equipment work completed, seal energised Nipple down BOP stack [' '"-"' ~ 6 ~}000 Removed BOP stack Equipment work completed Wellhead work Tested Tubing hanger Tested heat trace cable. Cable good on 2 legs. Discuss options with Anch SSD and Asset. Agreed to complete as is. Function test completed satisfactorily Wellhead work Installed Xmas tree Install adapter flange & tree. Equipment work completed Tested Xmas tree Tested tree & adapter flange. Pressure test completed successfully - 5000.000 psi Installed Hanger plug Pull TWC & set BPV. Eqpt. work completed, running tool retrieved Fluid system Freeze protect well - 70.000 bbl of Oil Bullhead annulus w/70 bbls of dead crude. Completed operations Freeze protect well - 22.000 bbl of Diesel Bullhead tubing w/22 bbls diesel. Completed operations Move rig Rigged down Drillfloor / Derrick Finish offloading & cleaning pits, cuttings tank, and trip tank. RD berms. Secure wellhead & tree. Equipment work completed Rig released @ 0400 hrs on 10/29/99. RECEIVED Facility Date/Time 24 Jan 00 25 Jan O0 M Pt J Pad Progress Report Well MPJ-08A Page 1 Rig Nabors 4ES Date 31 January 00 06:00-11:00 06:00-11:00 11:00 11:00-13:00 11:00-13:00 13:00 13:00-14:00 13:00-14:00 14:00 14:00-15:30 14:00-15:30 15:30 15:30-17:00 15:30-17:00 17:00 17:00-19:30 17:00-18:00 18:00 18:00-19:30 19:30 19:30-22:00 19:30-22:00 22:00 22:00-00:30 22:00-00:30 00:30 00:30-03:00 00:30-01:30 01:30 01:30-03:00 03:00 03:00-06:00 03:00-06:00 06:00 06:00-12:00 06:00-12:00 12:00 12:00-14:30 12:00-14:30 14:30 14:30-00:00 14:30-17:00 17:00 17:00-21:00 Duration 5hr 5hr 2 hr 2 hr lhr 1 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr lhr 1-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 3hr 3hr 6hr 6 hr 2-1/2 hr 2-1/2 hr 9-1/2 hr 2-1/2 hr 4hr Activity Move rig Rig moved 100.00 % move rig & set in & safe out eqipment. At well location - Slot Derrick management Rigged up High pressure lines rig tiger tank & rig hard lines to tree & take on 9.8 ppg. fluid. Equipment work completed Wellhead work Removed Hanger plug Equipment work completed Wellhead work Tested High pressure lines install hcr valve & test all lines to 2500 psi. Pressure test completed successfully - 2500.000 psi Well control Circulated closed in well at 4520.0 ft circ. well bore influx out with 9.8 ppg. brine Hole displaced with Brine - 100.00 % displaced Wellhead work Installed Hanger plug Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 2000.000 psi Wellhead work Removed Tubing hanger rig lub & pull twc & pull hanger to floor Equipment work completed Serviced Accessories inspect hanger penetrator etc for problem Equipment work completed Pull Single completion, 3-1/2in O.D. Pulled Tubing in stands to 3650.0 ft Stopped: To hold safety meeting Pull Single completion, 3-1/2in O.D. (cont...) Pulled Tubing in stands to 0.0 ft pooh & lay dn and analyze csp assy. Completed operations Derrick management Rigged down Completion string handling equipment Equipment work completed 3-1/2in. Surge string workstring run Ran Tubing in stands to 4607.0 ft On bottom Serviced Tubing circ. well bore & load pipe shed with 2-7/8" tbg. & strap same. RECEIVED Facility M Pt J Pad Progress Report Well MPJ-08A Page Rig Nabors 4ES Date 2 31 January 00 Datefrime 26 Jan 00 27 Jan 00 21:00 21:00-00:00 00:00 00:00-06:00 00:00-03:30 03:30 03:30-04:00 04:00 04:00-06:00 06:00 06:00-06:00 06:00-14:00 14:00 14:00-02:00 02:00 02:00-04:30 04:30 04:30-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-06:00 08:00-09:00 09:00 09:00-11:00 11:00 Duration 3hr 6 hr 3-1/2 hr 1/2 hr 2hr 24 hr 8 hr 12hr 2-1/2 hr 1-1/2 hr 2hr 2hr 22 hr lhr 2hr Activity Equipment work completed Laid down 4606.0 ft of Tubing 145 joints laid out Run Single completion, 2-7/8in O.D. Ran Tubing to 4600.0 ft (2-7/8in OD) On bottom Circulated at 4600.0 ft Hole displaced with Brine - 100.00 % displaced Pulled Tubing in stands to 2300.0 ft pooh with tbg. to pick up esp assy. Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. (cont...) Serviced ESP mu &service esp &Splice on lower flat lead to esp & investigate ways to test pothead with pressure. etc.. Equipment work completed Ran Tubing in stands to 4652.0 ft rih with esp installing heat trace from 2261' to surface & baker sensor etc. & install hanger. Completed run with ESP to 4652.0 ft Installed Accessories install esp cable upper pig tail & test & also install baker sensor & heat trace. Equipment work completed Installed Tubing hanger Tie-down bolts energised Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree test tree to 5000 psi. Equipment work completed Installed Hanger plug pull twc & set bpv. & make final check on all esp+baker sensor+heat trace all ok. & rig released to move off well & stack on J-pad. Equipment work completed RECEIVED North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-O8A Surveyed: 21 December, 1999 RECEIVED ~Oil&6as~s. Ca~ai~ SURVEY REPORT 30 December, 1999 Your Ref: API-500292249701 Surface Coordinates: 6014971.44 N, 551974.94 E (70° 27' 05.9164" N, 149° 34' 33.3314" W) Kelly Bushing: 66.0Oft above Mean Sea Level DRILL. INEi SERVICES Survey Ref: svy8957 A IkAI2.,IBU~TO~N CO~IsAN¥ Sperry-Sun Drilling Services Survey Report for MPJ-O8A Your Ref: API-500292249701 Surveyed: 21 December, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4816.88 75.610 331.960 3771.95 3837,95 4866.00 75.150 333.320 3784.35 3850.35 4901.53 77.330 330.030 3792.80 3858.80 4933.73 78.000 327.050 3799.68 3865.68 4966.02 78.230 324.060 3806.33 3872.33 4998.14 77.440 321,080 3813.10 3879.10 5030.76 76.160 318. 050 3820.55 3886.55 5062.79 74,940 315.080 3828.55 3894.55 5095.00 74.690 312.100 3836.98 3902.98 5127.58 74.290 313.460 3845.70 3911.70 5159.68 72.300 311.700 3854.92 3920.92 5192.26 71.380 310.430 3865,08 3931.08 5224.84 70.450 309.740 3875.73 3941.73 5257.12 69.930 307.660 3886.67 3952.67 5289.31 69.140 305.160 3897.93 3963.93 5321.89 69.500 303.490 3909.43 3975.43 5354.03 70.080 300.610 3920.54 3986.54 5386.16 69.740 297.580 3931.58 3997.58 5418.74 68.670 296.250 3943.15 4009.15 5450.98 68.430 293.690 3954.94 4020.94 5483.25 68.120 291.230 3966.88 4032.88 5515.48 68.780 287.540 3978.73 4044.73 5547.66 69.290 284.560 3990.24 4056.24 5580.20 70.080 284.060 4001.54 4067.54 5612.41 72.710 283.760 4011.81 4077.81 1637.29 N 1104.73W 1679.50 N 1126.58W 1709.87 N 1142.95W 1736.70 N 1159.37W 1762.75 N 1177.24W 1787.68 N 11'96.32W 1811.85 N 1216.91W 1834.37 N 1238.23W 1855.80 N 1260.74W 1877.13 N 1283.79W 1897.93 N 1306.42W 1918.26 N 1329.76W 1938.09 N 1353.32W 1957.08 N 1377.01W 1974.98 N 1401.28W 1992.17 N 1426.45W 2008.17 N 1452.02W 2022.84 N 1478.38W 2036.63 N 1505.54W 2049.29 N 1532.73W 2060.74 N 1560.44W 2070.69 N 1588.71W 2079.00 N 1617.58W 2086.54 N 1647.15W 2093.88 N 1676.78W 6016600.98 N 550858.81E 6016643.04 N 550836.68 E 6016673.29 N 550820.09 E 6016700.01 N 550803.49 E 6016725.94 N 550785.44 E 6016750.73 N 550766.18 E 6016774.76 N 550745.42 E 6016797.13 N 550723.94 E , 6016818.41 N 550701.28 E 6016839.57 N 550678.09 E 6016860.21 N 550655.31 E 6016880.38 N 550631.83 E 6016900.04 N 550608.14 E 6016918.87 N 550584.31 E 6016936.60 N 550559.92 E 6016953.61 N 550534.63 E 6016969.43 N 550508.95 E 6016983.92 N 550482.49 E 6016997.52 N 550455.24 E 6017009.99 N 550427.95 E 6017021.25 N 550400.17 E 6017031.00 N 550371.83 E 6017039.10 N 550342.90 E 6017046.44 N 550313.28 E 6017053.57 N 550283.60 E Dogleg Rate (°/~OOft) 2.839 10.887 9.277 9.089 9.397 9.858 9.753 8.962 4.206 8.124 4.658 3.486 6.273 7.679 4.921 8.600 8.919 5.035 7.428 7.146 10.843 8.791 2.823 8.213 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 1809.60 1850.65 1880.74 1908.97 1938.01 1967.47 1997.81 2027.87 2058.36 2089.23 2119,49 2150.09 2180.60 2210.78 2240.86 2271.32 2301.48 2331.60 2361.92 2391.67 2421.20 2450.40 2479.24 2508.25 2537.20 Tie-on Survey . Window Point RECEIVED 2000 Continued... 30 December, 1999 - 21:12 - 2 - DrillQuest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey RePort'for MPJ-O8A RECEIVED Your Ref: API-500292249701 Surveyed: 21 December, 1999 Alaska State Plane 4 Milne Point MPJ 5644.49 75,690 284.810 4020.55 5676.59 78,450 287.420 4027.73 5709.16 80.150 287.710 4033.78 5741.29 82.190 290.980 4038.71 5773.59 82.910 293.820 4042.90 5805.83 84.420 298.280 4046.46 5837.95 86.530 300.610 4048.99 5870.08 87.750 303.510 4050.60 5897.38 87.630 303.430 4051.70 5930.78 88.370 303.430 4052.86 5960.63 91.050 302.670 4053.01 5993.94 91.690 302.500 4052.22 6027.11 93.350 300,890 4050,76 6056.69 94,310 298.020 4048.78 6091.93 92.950 295.100 4046.55 6125.16 91,290 292.080 4045.32 6154.98 89.720 291,830 4045.06 6189.68 89.600 285.520 4045.27 6222.67 89.420 281.910 4045.55 6287.47 88,370 275.770 4046.80 6319.90 88.030 274.550 4047.82 6350.43 88.210 272.590 4048.82 6384.14 88.890 272,560 4049.67 6418.10 89.230 272.450 4050.23 6447.24 89.480 274.530 4050.56 Vertical Local Coordinates Global Coordinates Dogleg Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (fi) (ft) (°/100.) Vertical Section (fi) Comment 4086.55 2101.49 N 1706,69W 6017060,98 N 550253.64 E 9.808 4093.73 2110.18 N 1736.74W 6017069.45 N 550223.53 E 11.692 4099.78 2119.84 N 1767.25W 6017078.90 N 550192.95 E 5.292 4104.71 2130.35 N 1797.20W 6017089.21 N 550162.93 E 11.893 4108.90 2142.56 N 1826.81W 6017101.20 N 550133.23 E 8.999 4112.46 2156.63 N 1855.58W 6017115.07 N 550104.36 E 14.525 4114.99 2172.37 N 1883.46W 6017130.62 N 550076.37 E 9.769 4116.60 2189.40 N 1910.66W ' 6017147.46 N 550049.06 E 9.781 4117.70 2204.44 N 1933.41W 6017162.34 N 550026.20 E 0.528 4118.86 2222.83 N 1961.27W 6017180.54 N 549998.22 E 2.216 4119.01 2239.11N 1986.29W. 6017196.64 N 549973.08 E 9.332 4118.22 2257.04 N 2014.34W 6017214.38 N 549944.90 E 1.988 4116.76 2274.45 N 2042.54W 6017231.59 N 549916.59 E 6.968 4114.78 2288.97 N 2068.23W 6017245.92 N 549890.79 E 10.210 4112.55 2304.69 N 2099.69W 6017261.43 N 549859.23 E 9.125 4111.32 2317.97 N 2130.12W 6017274.50 N 549828.71 E 10.365 4111.06 2329.12 N 2157.77W 6017285.46 N 549800.98 E 5.331 4111.27 2340.23 N 2190.63W 6017296.33 N 549768.04 E 18.187 4111.55 2348.05 N 2222.67W 6017303.93 N 549735.95 E 10.956 4112.80 2358.00 N 2286.66W 6017313.43 N 549671.89 E 9.611 4113.82 2360.92 N 2318.94W 6017316.12 N 549639.59 E 3.904 4114.82 2362.82 N 2349.39W 6017317.81 N 549609.13 E 6.443 4115.67 2364.33 N 2383.06W 6017319.09 N 549575.45 E 2.019 4116.23 2365.81 N 2416.98W 6017320.34 N 549541.52 E 1.052 4116.56 2367.59 N 2446,06W 6017321.91 N 549512.42 E 7.189 2566.55 2596.58 2627.52 2658.44 2689.98 2721.82 2753.80 2785.88 2813.16 2846.53 2876.38' 2909.68 2942.81 2972.28 3007.27 3040.08 3069.41 3103.10 3134.35 3193.73 3222.55 3249.29 3278.54 3307.98 3333.50 Continued... 30 Decen]ber, 1999 - 21:12 - 3 - DrillQuest 1.05,04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 6476.28 89.940 274.930 4050.70 6509.19 89.970 274.650 4050.73 6538.28 90.310 278.140 4050.66 6576.15 90.550 278.900 4050.37 6609.06 91.010 280.500 4049.93 6638.70 90.890 281.920 4049.44 6673.05 90.950 281.980 4048.88 6706.71 90.950 282.650 4048.33 6735.44 91.570 283.970 4047.69 6770.75 91.380 283.410 4046,79 6803.44 89.780 282.160 4046.45 6832.41 89.660 283.050 4046.60 6868.56 89.360 282.740 4046.90 6901.06 88.520 281.080 4047.51 6929.69 88.340 282.280 4048.29 6964.84 88.120 281.640 4049.38 6997.91 87.420 280,790 4050.66 7026.82 87.480 278.990 4051.95 7060.53 88.370 278.390 4053.17 7093.58 89.970 278.930 4053.65 7121.94 90.310 278.120 4053.58 7157.93 90.310 279.430 4053.38 7190.59 90.460 278.350 4053.17 7220.22 90.400 279.220 4052.94 7255.91 91.050 279.290 4052.49 Sperry-Sun Drilling Services Survey Report for MPJ-O8A RECEIVED Your Ref: API-500292249701 Surveyed: 21 December, 1999 ~0it&GasCa~s. Ceaai~laska State Plane 4 AIl¢0lil~ Milne Point MPJ Vertical Local Coordinates Global Coordinates Dogleg Depth Northings Eastings Northings Eastings Rate (fi) (ft) (fi) (ft) (ft) (°/lOOff) Vertical Section (ft) Comment 4116,7o 2369.98 N 2475.00W, 6017324.10 N 549483.47 E 2.099 4116.73 2372.73 N 2507.80W 6017326.62 N 549450.65 E 0.856 4116.66 2375.97 N 2536.70W 6017329.66 N 549421.73 E 12.054 4116.37 2381.58 N. 2574.15W 6017335.01 N 549384.24 E 2.104 4115,93 2387.12 N 2606.59W 6017340,33 N 549351.77 E 5.058 4115.44 2392.89 N 2635.66W 6017345.88 N 549322.66 E 4.807 4114,88 2400.00 N 2669.26W 6017352.76 N 549289.01 E 0.247 4114.33 2407.17 N 2702.14W 6017359,71 N 549256.08 E 1.990 4113.69 2413.79 N 2730.09W 6017366.13 N 549228,08 E 5.075 4112.79 2422.14 N 2764,39W 6017374,24 N 549193.73 E 1.674 2796.26W 6017381.25 N 549161.80 E 6.211 2824.53W 6017387.38 N 549133.49 E 3.100 2859.77W 6017395.20 N 549098.19 E 1.193 2891.56W 6017401,68 N 549066.36 E 5.724 2919.59W 6017407.28 N 549038.29 E 4.237 4112.45 2429.37 N 4112.60 2435.70 N 4112.90 2443.76 N 4113.51 2450.47 N 4114.29 2456.26 N 4115.38 2463.54 N 4116.66 2469.97 N 4117.95 2474.93 N 4119.17 2480.02 N 4119.65 2485.00 N 4119.58 2489.20 N 4119.38 2494.69 N 4119.17 2499.74 N 4118.94 2504.26 N 4118.49 2510.00 N 2953.96W 6017414.32 N 549003.87 E 1.925 2986.37W 6017420.52 N 548971.41 E 3.328 3014.82W 6017425.28 N 548942.93 E 6.224 3048.13W 6017430.14 N 548909.59 E 3,183 3080.79W 6017434,89 N 548876.89 E 5.109 3108.84W 6017438.90 N 548848.81 E 3.098 3144.41W 6017444,14 N 548813.21 E 3.640 3176.67W 6017448.96 N 548780.91 E 3.338 3205.96W 6017453.28 N 548751.60 E 2.943 3241.18W 6017458.77 N 548716.33 E 1.832 3359.22 3388.39 3414.54 3449,18 3479.54 3507.18 3539.37 3570.98 3598.13 3631.57 3662.37 3689.63 3723.71 3754.15 3780.93 3813.86 3844.67 3871.36 3902.21 3932.47 3958.41 3991.39 4021.34 4048.50 4081.32 Continued... 30 December, 1999 - 21:12 - 4 - Dr#/Quest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for MPJ-O8A Your Ref: API-500292249701 RECEIVED Surveyed: ~21 December, 1999 : ',-, "6 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) Alall~0ii&GasCons. C0~miali0n Alaska State Plane 4 Allch01'~e Milne Point MPJ 7287.89 92.990 280.830 4051.36 4117.36 7317.83 93.510 281.300 4049.67 4115.67 7352.04 94.370 281.220 4047.32 4113.32 7384.75 93.670 281.910 4045.02 4111.02 7414.12 91.810 283.160 4043.62 4109.62 7446.54 90.770 283.050 4042.89 4108.89 7480.26 90.490 283.260 4042.52 4108.52 7510.87 90.490 283.000 4042.26 4108.26 7545.87 92.460 283.000 4041.36 4107.36 7579.81 92.520 283.000 4039.88 4105.88 7610.12 92.190 283.060 4038.64 4104.64 7643.58 91.970 283.780 4037.42 4103.42 7676.83 90.180 285.540 4036.80 4102.80 7707.19 90.060 285.780 4036.73 4102.73 7743.70 90.400 285.480 4036.59 4102.59 7772.84 90.090 265.360 4036.46 4102.46 7803.90 90.060 285.350 4036.42 4102.42 7837.75 90.490 285.440 4036.26 4102.26 7869.72 91.080 285.870 4035.82 4101.82 7898.33 90.800 285.960 4035.35 4101.35 7933.69 89.940 286.010 4035.12 4101.12 7966.00 89.750 285.450 4035.21 4101.21 7996.43 89.480 285.110 4035.42 4101.42 8030.53 89.910 285.910 4035.60 4101.60 8063.81 91.940 286.040 4035.06 4101.06 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (ft) (°/100ft) (ft) Comment 2515.58 N 3272.64 W 2521.32 N 3301.98 W 2527.99 N 3335.45 W 2534.53 N 3367.42 W 2540.89 N 3396.05 W 2548.24 N 3427.62 W 2555.92 N 3460.45 W 2562.87 N 3490.26 W 2570.74 N 3524.35 W 2578.37 N 3557.39 W 2585.20 N 3586.90 W 2592.96 N 3619.42 W 2601.37 N 3651.58 W 2609.56 N 3680.81 W 2619.40 N 3715.97 W 2627.15 N 3744.06 W 2635.37 N 3774.01 W 2644.36 N 3806.65 W 2652.99 N 3837.43 W 2660.83 N 3864.94 W 2670.57 N 3898.93 W 2679.33 N 3930.03 W 2687.35 N 3959.39 W 2696.46 N 3992.24 W 2705.62 N 4024.23 W 6017464.14 N 548684.83 E 7.743 4110.89 6017469.67 N 548655.45 E 2.339 4138.74 6017476.10 N 548621.94 E 2.525 4170.58 6017482.42 N 548589.93 E 3.001 4201.08 6017488.58 N 548561.25 E 7.627 4228.67 6017495.71 N 548529.63 E 3.226 4259.27 6017503.16 N 548496.74 E 1.038 4291.11 6017509.90 N . 548466.89 E 0.849 4320.01 6017517,54 N 548432.74 E 5.629 4353.02 6017524.93 N 548399.65 E 0.177 4385.01 6017531.55 N 548370.10 E 1.107 4413.58 6017539.09 N 548337.52 E 2.249 4445.21 6017547.28 N 548305.30 E 7.549 4476.88 6017555.27 N 548276.02 E 0.884 4505.95 6017564.86 N 548240.79 E 1.242 4540.92 6017572.41 N 548212.64 E 1.141 4568.79 6017580.43 N 548162.64 E 0.102 4598.49 6017589.18 N 548149.94 E 1.298 4630.87 6017597.60 N 548119.10 E 2.284 4661.48 6017605.25 N 548091.54 E 1.028 4688.92 6017614.75 N 548057.48 E 2.436 4722.84 6017623.29 N 548026.32 E 1.830 4753.80 6017631.10 N 547996.91 E 1.427 4782.89 6017639.99 N 547963.99 E 2.663 4815.52 6017648.93 N 547931.94 E 6.112 4847.44 Continued... 30 December. 1999 - 21:12 - 5- DrillQuest 1.05.04e North Slope Alaska Sperry-Sun Drilling Services Survey Report for MPJ-O8A RECEIVED Your Ref: API-500292249701 Surveyed: 21 December, 1999 !":: :~ 't 6 :?000 NmkaOil & Gas C~s. Cemmi~n Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (fl) (fi) (fi) (ft) (°/lOOff) 8091.35 91.010 286.500 4034.35 4100.35 2713.33 N 4050.66 W 6017656.46 N 547905.45 E 3.767 8126.26 90.120 285.760 4034;01 4100.01 2723.03 N 4084.19 W 6017665.92 N 547871.85 E 3.315 8158.62 90.060 285.570 4033.96 4099.96 2731.77 N 4115.35 W 6017674.44 N 547840.64 E 0.616 8187.21 90.310 285.280 4033.86 4099.86 2739.37 N 4142.91 W 6017681.85 N 547813.02 E 1.339 8225.15 90.250 284.690 4033.68 4099.68 2749.18 N 4179.56 W 6017691.41 N 547776.31 E 1.563 8259.32 90.310 284.660 4033.51 4099.51 2757.84 N 4212.62 W 6017699.83 N 547743.19 E 0.196 8287.67 89.690 284.840 4033.51 4099.51 2765.06 N 4240.03 W 6017706.86 N 547715.73 E 2.277 8323.17 89.690 284.440 4033.70 4099.70 2774.03 N 4274.38 W 6017715.59 N 547681.32 E 1.127 8356.01 88.210 284.220 4034.31 4100.31 2782.16 N 4306.19 W 6017723.49 N 547649.45 E 4.556 8384.31 87.510 283.810 4035.36 4101.36 2789.01 N 4333.63 W 6017730.15 N 547621.96 E 2.866 8420.31 87.260 283.430 4037.00 4103.00 2797.47 N 4368.58 W 6017738.38 N 547586.96 E 1.263 8459.18 87.140 283.470 4038.90 4104.90 2806.50 N 4406.34 W 6017747.14 N 547549.13 E 0.325 8495.00 87.140 283.470 4040.69 4106.69 2814.84 N 4441.13 W 6017755.23 N 547514.29 E 0.000 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 26.814° (16-Dec-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 302.367° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8495.00ft., The Bottom Hole Displacement is 5258.04ft., in the Direction of 302.367° (True). Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 4873.89 4907.41 4938.40 4965.75 5001.96 5034.51 5061.53 5095.35 5126.57 5153.41 5187.46 5224.19 5258.04 Projected Survey Continued... 30 December. 1999 - 21:12 - 6 - DriilQuest 1.05. 04e Sperry-Sun Drilling Services Survey Report for MPJ-O8A Your Ref: API-500292249701 Surveyed: 21 December, 1999 North Slope Alaska Comments Measured Depth (~) 4816.88 4866.00 8495.00 Station Coordinates TVD Nothings Eastings (~) (~) (~) 3837.95 1637.29 N 1104.73W 3850.35 1679.50 N 1126.58W 4106.69 2814.84 N 4441.13W Comment Tie-on Survey Window Point Projected Survey RECEIVED ~ ..... , '~ 6 2000 And~o~ Alaska State Plane 4 Milne Point MPJ 30 December, 1999 - 21:12 - 7 - DrillQues t 1.05. 04e TON Y KNO WL ES, G O VERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Charles Mallary Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Milne Point Unit MPJ-08A BP Exploration (Alaska), Inc. Permit No: 199-117 Sur Loc: 2576'NSL, 1938'EWL, Sec. 28, T13N, R104E, UM Btmhole Loc. 1,,6 NSL, 2626'EWL, Sec. 20. T13N. R10E, UM Dear Mr. Mallary: Enclosed is the approved application tbr permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~S i ~y, , ~~ Robert N. Christenson, P.E. Chair BY ORDER OF THE. j~OMMISSION DATED this ~ ~ day of December, 1999 dlf/Enclosures CC; Department of Fish & Gmne. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~-... /<X ~',-3¢~_.._O_,¢.~ A ASl OO.S VA IO PERMIT TO DFIILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE -- 65.50' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025515 ~)~-~'5-~,? 4. Location of well at surface 7. Unit or Property Name .-~ 11. Type Bond (See 20 AAC 25.025) 2576' NSL, 1938' EWL, Sec. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4772' NSL, 46' EWL, Sec. 28, T13N, R10E, UM MPJ-08A At total depth 9. Approximate spud date Amount $200,000.00 126' NSL, 2626' EWL, Sec. 20, T13N, R10E, UM 12/10/99 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025517, 126' MDI MPJ-09A 73' @ 6254' 2560 8668' MD/4102' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 4880' MD Maximum Hole Angle 91° Maximum surface 1340 psig, Attotal depth (TVD) 4100'/1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3920' 4730' 3813' 8650' 4102' 83 sx Class'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 8593 feet Plugs (measured) o ,'" · £._ true vertical 4075 feet ~'~ 0V ,999 Effective depth: measured 8593 feet Junk (measured) true vertical 4075 feet ~aStfu3, Oil & Gas,,h,,Cons. Comm[ssio~ Casing Length Size Cemented An~t~rage TVD Structural Conductor 80' 13-3/8" 250 sx Arctic Set I (approx) 112' 112' Surface 2483' 9-5/8" 504 sx PF 'E', 250 sx Class 'G' 2516' 2446' Intermediate Production 6102' 7" 220 sx Class 'G' 6131' 4054' Liner Gravel Pack Screen 4-3/4" Uncemented (Pre-packed) Liner 5896' - 8593' 4029' - 4075' Perforation depth: measured 5076'-5136', 5174'-5216', 5806'-5871' ORIGINAL true vertical 3901' - 3916', 3925' - 3934', 4018' - 4026' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer NameWumber: Fred Johnson, 564-5427 Michael Trio/o, 564-5774 Prepared By Name/Number: Michael Williams, 564-4657 21. I hereby certify thab~e f.c/re, aoing i~'tr,~ and correct to the best of my knowledge Signed (!.~ ~ ~"J~'t ~'~' CharlesMallar~"~ 'K'/ ~'1' ~v;4 Title Senior Drilling Engineer Date / Commission Use Only Permit Number I APl Number ~ ...-, _ I Approval Date ISee cover letter //'7 I 50- :z2_,-p/7- / I /o~"' (:~" ,¢; ~'I for other requirements Conditions of Approval: Samples Required [] Yes J~ No Mud Log Required [] Yes ~No Hydrogen Sulfide Measures []Yes'~'No Directional Survey Required r'-"-~Yes [] No Required Working Pressure for mOPE ,[~L2K; I-I 3K; [-] 4K; [~,5K; I-'110K; [-J 15K by order of Date~c~ :Approved By ORIGINAL SIGNEU O"r.¢ Commissioner the commission ~')~--'/,~' Form 10-401 Rev. 12-01-85 Robert N. Chdstenson Submit In Triplicate Well Name: I MPJ-08A Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 2576' NSL, 1938' EWL, Sec. 28, T13N, R10E X = 551,975.86 Y = 6,014,973.28 Target Start: 4772,:NSLi 46,EWL,: sec. 28, T13N, R10E X = 550,064.00 Y = 6,017,156.00 Z = 4,060' TVDss Intermediate Target End: 126!:NSL, 2626!: EWL, Sec. 20, T13N, R10E X = 547,359.00 Y = 6,017,773.00 Z = 4,037' TVDss I AFE Number: 1337170 I I Rig: I Nordic3 I Estimated Start Date: I Dec 10, 1999 I I Operating days to complete: I 14.5 IMD 18,668' I ITVDrkb: 14,102' I IEeE: 165.50' IWell Design (conventional, slim hole, etc.): IExtended Horizontal Sidetrack Objective: Sidetrack out of existing 26#, 7" csg into the Schrader Bluff Formation, directionally drill 6 1/8" hole, land horizontally in the Schrader Bluff 'OB' sands. Geosteer horizontally through the OB target sands to TD at 8,668' MD. Run, cmt and test a 4 1/2" Banzai (slotted/solid) liner, complete with an ESPCP pump, 3-1/2", L-80, EUE tubing. Current Well Information Well Name: APl Number: Well Type: Current Status: Last H2S Sample: Cement: TD / PBTD: BHP: BHT: Is this well frac'd? Mechanical Condition: ~Wellhead: Nordic 3: Tubing: Liner: Casing: Casing Head: Casing Hanger: 7" Packoff: Tubing Spool: Tbg. Hanger: Tree: Open Perfs: 7" Casing Fluids: MPJ-08 50-029-22497 Shrader Bluff Producer All open perf's P & A'd 0 ppm TOC planned to be at top of 7" window at 4,880'. Liner top to be at 4730'. 8,668' / 8,668' 1,800 psi Schader Bluff 'OB' sand. Estimated from shut-in pressure & offset wells 80°F@ 4,020' ss Estimated No Cellar Box MSL = 35.5' KB / MSL = 65.5' No tubing in well at present. Completion tubing will be 3-1/2", 9.3#, L-80, EUE 8rd None Conductor: 112', 13 3/8", 54.5#, K-55, BTC Welded Surface: 2,516', 9-5/8", 40#, L-80, BTC Production: 6,131', 7", 26#, L-80, BTC WKM 10 3,2' BTC x 11 ", 5M 7" WKM Mandrel WKM Mandrel type WKM, 11" x 11", 5M WKM TDF-CS 11" x 2-7/8" EUE top and btm. ESP and heat trace penetrator prep. with dummy mandrels installed 3", 'H' type BPV profile Cameron 5M, 2-9/16" None. Well Decompleted by Nabors 4ES SW with diesel cap down to -2000' No kill string installed Target Estimates: Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Materials Needed: L-80 Intermediate: Expected reserves 1.8 mmbbl Production rate: 1,000 b/d Production rate: 1,000 b/d L-80 Production: L-80 Completion: 2,400' 1,600' 7" x 4-1/2" 4-1/2" 400 - 4-5/8" x 5 7/8" x 8" 4,500' ESPCP 2 - 3-1/2x1" 4,500' 2,330' 4,500' BHP Gauge 4.5", 12.6#, L-80, IBT-Mod Slotted Liner 4.5", 12.6#, L-80, IBT-Mod Solid Liner Baker liner top hanger / packer Halliburton Guide Shoe Rigid Straight Blade Centralizers 20' CTC ECP, HMCV, Indicator subs, packoff bushing, spacer subs 3-1/2", 9.3#, L-80, 8rd EUE tubing Grade [] Centrilift Sidepocket GLM's Centrilift #4 flat cable Raychem heat trace (Rerun existing HT) Baker TEC Wire Baker Sentry Gauge Dr,, in_cl Hazards and Cont,, .qencies 2) 3) Hydrogen Sulfide a) MP J Pad is not designated as an H2S Pad. Hydrates and Shallow Gas - This well is being sidetracked below the known hydrate intervals. Hydrates should not be encountered on this well. Hydrate procedures included for information only. a) Always be prepared for the unexpected possibility of hydrates, shallow gas and hydrocarbons. There has never been any hydrate, shallow gas or unexpected hydrocarbon problems on J pad. If we do encounter hydrates proceed ahead as follows (Ref: Paul Lockwood): Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. · 2 ppb Lecithin - Have in mud system prior to drilling hydrates · 0.6% Drill & Slide. Have in mud system prior to drilling hydrates. Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.8-9.2) once we were 300-400 ft below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. · Weigh mud out with both pressurized and non-pressurized mud scales. The non- pressurized mud scales reflects actual mud cut weight. Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. · Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. · Keep mud circulating temperature as cold as possible. Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper log has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. Watery looking gas cut fluid belching out over the 20" conductor during nipple up of A- rid o . section. The 2 stage lead cement was probably contaminated w~th hydrate gas. Because of the increased temperature resulting from the cement setting up and melting the hydrates, this may have introduced even more than the usual amounts of water into the fluid column, which resulted in larger amounts of water swapping out with the cement. This may have been the reason for finding cement in the 20" x 9 5/8" annulus at 200 ft when probing with the 3,4" top out pipe. Kick tolerance a) The kick tolerance for the 6 1/8" open hole section would be 25 bbls assuming an influx at the 8668' TD in the Schrader OB formation. This is a worst case scenario based on a 8.65 ppg pore pressure gradient i~ .e top of the production section and a mini. .n fracture gradient of 12.5 ppg below the 9 5/8" surface casing shoe with a 9.4 ppg mud in the hole. b) FIT at the 9 5/8" shoe after the original drill out: 12.5 ppg EMW 4) Lost Circulation a) There is no history of lost circulation problems drilling to the Schrader Bluff formation on J pad and none expected drilling this well. However there have been losses on several wells during the cement job. All recent surface casing jobs have required top cement jobs. b) No major faults are expected along the planned well path. The OA sand reservoir pressure is expected to be 7.5 lb/gal equivalent. c) Follow the LOST CIRCULATION DECISION MATRIX if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 5) Faults a) No major faults are expected along the planned well path. 6) Unexpected High Pressures a) 7) It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Adjacent Well J-19 was recently shut-in where reservoir pressure is 1,850 psi, 4,000'TVDss or 8.9 EMW. In this well, the Schrader Bluff formation will be drilled with 9.4 ppg mud. Stuck Pipe a) Sticky clays through the intermediate hole section(2,500' - 6,700' TVD). On J-16 experienced tight hole, swabbing, and had to backream a lot. Frequent wiper trips are recommended in the intermediate hole. (recommended guidelines: every 1,000' drilled). b) Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! c) There is a risk of differentially sticking the 4-1/2" liner. The 9.6 lb/gal mud will be 2 lb/gal overbalanced to the 7.7 lb/gal OA sand reservoir pressure (400 psi differential pressure) and lib/gal overbalanced to the 8.6 lb/gal OB sand reservoir pressure (200 psi differential pressure). The liner should be kept moving as much as possible while running in the open hole. The 5-1/2" casing on the J-151 well was just recently differentially stuck.. 8) Close Approaches a) The directional plan for J-08A comes will come close to the planned but not yet drilled J-09A well. This close approach issue will be fully evaluated after J~09A is drilled. To mitigate this close approach, the J- 09A will not be produced (ESP completion) while drilling the J-08A well. SSD and the WNS Asset will do a qualitative risk assessment. 9) Pad Data Sheet a) Please Read the J-Pad Data Sheet Thoroughly. 10) Breathing a) No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 11) Hydrocarbons a) Will be kicking off i~ .e Schrader Bluff interval, therefore the fir~ .~ssible hydrocarbon zone will be the Schrader Bluff 'NA' sand at @ 4921' MD, 3,798' TVDss. 12) Geosteering a) (2) rig site geologists are required onsite for accurate geosteering through the thin OB sands Drillin_cl Program Overview Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPJ-08A. Close Approach Wells: MP J-09, J-09A (J-09A will be drilled and completed before J-08A) IWell Name MP J-09A ICurrent Status Production Priority New well to be drilled Producer I IPrecautions Pump will be shut down Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP 1,800 psi, 4,100' TVDss (estimated) Max Exp Surface Pressure 1,340 psi (.115 psi/ft gas 9radient) BOPE Ratin9 5,000 psi WP (entire stack & valves) Planned BOPE Test Pres. 3,500/250 psi Rams and Valves 2,500/250 psi Annular Mud Program Production Mud Properties' 9% KCL BaraDriln I 6 1/8" hole section Density (PP~) I Funnel vis YP I HTHP I 9.6 40 - 55 20 - 27 10 - 15 pHI APl Filtrate I LG Solids 8.0 - 8.5 4 - 6 < 15 ppb NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or ARCO KRU 1R. Formation Markers Formation Tops MD TVDss Pore Psi EMW(pp~) Comments TUZC NP TUZB NP Planned Kick Off Point KOP 488O 3785 NA 4900 3790 8.65 NB 5047 3828 8.65 NC 5168 3860 8.65 NE 5255 3886 8.65 NF 5428 3942 8.65 TOA 5547 3983 7.5 TOB 5893 4060 8.65 Top OB sand. Set ECPinthe sand TD 8668 4037 8.65 Casing/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MDrrVD MDrFVD 6 1/8" 4 1/2" 12.6# L-80 IBT-Mod 3,920' 4,730'/3,813' 8,650'/4,102' Banzai Tubing 3-1/2" 9.3# L-80 EUE 8rd 4,500' 30'/30' 4,500'/3,742' w/ESPCP Cement Calculations ILiner Size 1 4 Y2" Banzai IBT~Mod I ,, Basis I 0% excess in o ~en hole (6 1/8" hole), No cement in liner lap (7 casing) or above liner top (3 Y2" dp) I ECP 5,893' MD 4,125 TVDrkb), Window at 4,880' (3,853'), Liner top at 4,730' (3,813") ITotal Cement Spacer None if well displaced to completion fluid. Contingency 15 bbls of B45 Volume: Viscosified Spacer Weighted to 10.2 ppg if cementing in mud Tail 83 sxs, Class 'G'+ .30%D65 + .12%B71 + .4% D167 + .2% D046 Temp BHST -80° F from SOR, BHCT 85° F estimated by Dowell Centralizer Placement: 1. Run (2) rigid straight centralizer per joint first 300' above the ECP 2. Run (1) rigid straight centralizer per joint to the window. 2. Run each single centralizer in the middle of each joint of casing. Other Cement Considerations: 1. Batch mix this single slurry. Survey and Logging Program 6 1/8" Section: Open Hole: MWD / GR/Res / PWD ~ Over production interval. Sample Catchers ~ None! Cased Hole: None Perforating: None Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzle / Flow Rate K-Rev's Hours Number and Section 1 6 1/8" 5,350' - 8,269 PDC 15-15-15: 250+ gpm - - Motors and Required Dogleg. BHA Motor Size and Motor Flow Rate RPM's Required Doglegs Number Required 1 4 3,4" Sperrydrill 4/5, 6.3 stg Slow 250 - 300 gpm 75 mtr, 60 Build out of window at (PDC) Speed, 1.15° adj w/5.9" sleeve rotate 12°/100 to horizontal. Drill to TD. MPJ-08A Operations Summary Pre-Ri.q Operations 1. The prerig decompletion work has been done by Nabors 4ES Snapshot of Well Proqram 1. MIRU Nordic 3. 2. ND Tree, NU Stack and Test. 3. Run and set whipstock on EZSV. Mill window. 4. MU 6 1/8" BHA. RIH. 5. Drill 6-1/8" hole. Build angle and steer to land horizontal in OB sand. 6. Displace hole to new BARADRILn mud. Drill horizontal section. 7. Run 4-1/2" Bonzai liner and inner string. 8. Set liner hanger. Inflate ECP and cement top liner interval above slotted liner. POOH 9. RIH open ended. Displace hole to 9.0 KCL completion fluid 10. Spot Starch Enzyme in 4-1/2" slotted liner. POOH 11. Run 2-7/8" ESP completion with Raychem heat trace and Baker Sentry gauge with TEC wire, 12. ND BOPE, NU tree. Release rig. I DrillQuest North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-08A 3000 - 2500 - o 2000- O II .w Scale: linch: 500ft -4500 -4000 I I Eastings -3500 -3000 -2500 -2000 -1500 .5-/~t'V4o MPJ-OSA 4105.60 tvd 2799.67 N, 4450.52 W MPJ-O8A Poly (June2) MPJ. O8A T2 (June2) - Point W . 65~5.10~O' MI'J-08A TI (June2) - Point 4125.60 tvd 2197.83 N, 1895.66 W Start Dir @ 8.000°/100ft: 5559.15ft MD, 4067.59ft End Dir: 5368.02ft MD, 3997.24ft Tie-on, Start Dir @ 8.000°/100ft: 4880.00ft MD, 3853.65ft TVD I I I I I I I -4500 -4000 -3500 -3000 -2500 -2000 - 1500 Scale: linch = 500ft i=astinns Reference is True North 3000 2500 2000 o© II .t _ .~_ 4000 I I 2197.83 N. 1895.66 W I 2346.22 N, F524.64 *$' I I 2799.~7 N, 4450.52 W 2000 2500 3000 3500 4000 4500 5000 5500 Scale: linch = 500ft Vertical Section Section Azimuth: 301.700° _(True North) I Prepared: Checked: Approved: Sperry-Sun Drilling Services Proposal Report for MPJ-O8A Wp08 Revised: 24 November, 1999 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 4880.00 75.022 333.713 3788.05 4887.67 75.554 333.396 3790.00 4900.00 76.409 332.890 3792.99 4920.00 77.799 332.077 3797,45 4950.00 76.984 329.764 3804,00 5000.00 75.672 325.875 3815.82 5047.29 74.490 322,156 3828.00 5050.00 74.424 321,941 3828,73 5100.00 73,246 317.961 3842,65 5150,00 72.146 313.932 3857.53 5158.02 71.978 313.282 3860,00 5200.00 71.130 309.856 3873.29 5238.59 70.407 306.677 3886.00 5250.00 70.203 305.732 3889.85 5300.00 69.372 301.563 3907.13 5350.00 68,642 297.350 3925.05 5368.02 68.405 295.822 3931.64 5396.16 68.405 295.822 3942.00 5400.00 68.405 295,822 3943.41 5450.00 68.405 295.822 3961.82 5500.00 68.405 295.822 3980.22 5507.56 68.405 295.822 3983.00 5550.00 68.405 295.822 3998.62 5559.15 68.405 295.822 4001.99 5593.59 70.769 294.313 4014.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3853.65 1691.96 N 1132.77 W 6016655.46 N 550830.40 E 3855.60 1698.60 N 1136.08W 6016662.08 N 550827.04 E 3858.59 1709.27 N 1141.48W 6016672.71 N 550821.57 E 3863.05 1726.56 N 1150.49W 6016689.94 N 550812.44 E 3869.60 1752.15 N 1164.72W 6016715.42 N 550798.03 E 3881.42 1793.26 N 1190.58W 6016756.35 N 550771.88 E 3893.60 1830.23 N 1217.42W 6016793.13 N 550744.79 E 3894.33 1832.29 N 1219.03W 6016795.18 N 550743.17 E 3908.25 1869.04 N 1249.92W 6016831.72 N 550712.02 E 3923.13 1903.35 N 1283.10W 6016865.79 N 550678.60 E 3925.60 1908.61N 1288.62W 6016871.02 N 550673.04 E 3938.89 1935.03 N 1318.41W 6016897.23 N 550643.07 E 3951.60 1957.59 N 1347.01W 6016919.59 N 550614.31 E 3955.45 1963.94 N 1355.68W 6016925.88 N 550605.60 E 3972.73 1989.93 N 1394.72W 6016951.60 N 550566.37 E 3990.65 2012.89 N 1435.36W 6016974.27 N 550525.58 E 3997.24 2020.39 N 1450.35W 6016981.67 N 550510.54 E 4007.60 2031.79 N 1473.90W 6016992.90 N 550486.90 E 4009.01 2033.34 N 1477.12W 6016994.43 N 550483.68 E 4027.42 2053.59 N 1518.97W 6017014.39 N 550441.69 E 4045.82 2073.84 N 1560.82W 6017034.35 N 550399.70 E 4048.60 2076.91 N 1567.14W 6017037.37 N 550393.35 E 4064.22 2094.10 N 1602.66W 6017054.31 N 550357.71 E 4067.59 2097.80 N 1610.32W 6017057.96 N 550350.03 E 4079.60 2111.47 N 1639.56W 6017071.43 N 550320.70 E Dogleg Rate (°/100ft) 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 8.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 1852.85 1859.16 1869.36 1886.11 1911.66 1955.27 1997.53 1999.98 2045.57 2091.83 2099.30 2138.52 2174.71 2185.42 2232.30 2278.93 2295.63 2321.66 2325.21 2371.46 2417.71 2424.70 2463.95 2472.41 2504.47 Comment Tie-on Start Dir @ 8.000°;/100ft: 4880.00ft MD, 3853.65ft TVD NA NB NC NE End Dir: 5368.02ft MD, 3997.24ft TVD NF OA Start Dir @ 8.000°/100ft: 5559.15ft MD, 4067.59ft TVD TSBC Continued... 24 November, 1999 - 13:18 - I - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for MPJ-O8A Wp08 Revised: 24 November, 1999 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 5600.00 71.211 294.037 4016.09 5650.00 74.667 291.930 4030.76 5700.00 78.142 289.892 4042.51 5750.00 81.632 287.906 4051.29 5800.00 85.131 285.954 4057.05 5850.00 88.636 284.023 4059.77 5869.45 90.000 283.275 4060.00 5900.00 90.000 283.275 4060.00 5950.00 90.000 283.275 4060.00 6000.00 90.000 283.275 4060.00 6050.00 90.000 283.275 4060.00 6100.00 90.000 283.275 4060.00 6150.00 90.000 283.275 4060.00 6200.00 90.000 283.275 4060.00 6250.00 90.000 283.275 4060.00 6300.00 90.000 283.275 4060.00 6350.00 90.000 283.275 4060.00 6400.00 90.000 283.275 4060.00 6450.00 90.000 283.275 4060.00 6500.00 90.000 283.275 4060.00 6515.70 90.000 283.275 4060.00 6550.00 90.020 283.274 4059.99 6600.00 90.049 283.272 4059.96 6650.00 90.079 283.271 4059.91 6700.00 90.108 283.270 4059.83 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4081.69 2113.95 N 1645.09 W 6017073.87 N 550315.15 E 4096.36 2132.61 N 1689.09 W 6017092.22 N 550271.02 E 4108.11 2149.94 N 1734.48 W 6017109.23 N 550225.51 E 4116.89 2165.88 N 1781.04 W 6017124.85 N 550178.84 E 4122.65 2180.34 N 1828.54 W 6017138.97 N 550131.24 E 4125.37 2193.24 N 1876.76 W 6017151.54 N 550082.93 E 4125.60 2197.83 N 1895.66 W 6017156.00 N 550064.00 E 4125.60 2204.85 N 1925.39VV 6017162.81 N 550034.22 E 4125.60 2216.33 N 1974.06W 6017173.95 N 549985.48 E 4125.60 2227.81 N 2022.72W 6017185.09 N 549936.73 E 4125.60 2239.29 N 2071.39W 6017196.23 N 549887.99 E 4125.60 2250.77 N 2120.05W 6017207.37 N 549839.25 E 4125.60 2262.25 N 2168.71W 6017218.51N 549790.50 E 4125.60 2273.73 N 2217.38W 6017229.65 N 549741.76 E 4125.60 2285.21 N 2266.04W 6017240.80 N 549693.02 E 4125.60 2296.70 N 2314.71W 6017251.94 N 549644.28 E 4125.60 2308.18 N 2363.37W 6017263.08 N 549595.53 E 4125.60 2319.66 N 2412.03W 6017274.22 N 549546.79 E 4125.60 2331.14 N 2460.70W 6017285.36 N 549498.05 E 4125.60 2342.62 N 2509.36W 6017296.50 N 549449.30 E 4125.60 2346.22 N 2524.64W 6017300.00 N 549434.00 E 4125.59 2354.10 N 2558.03W 6017307.64 N 549400.56 E 4125,56 2365.58 N 2606.69W 6017318.78 N 549351.82 E 4125.51 2377.06 N 2655.35W 6017329.92 N 549303.07 E 4125.43 2388.54 N 2704.02W 6017341.06 N 549254.33 E Dogleg Rate (°/100ft) 8.000 8.000 8.000 8.000 8.000 8.000 8.000 0.oo0 0.oo0 o.ooo o.ooo o.ooo o.ooo 0.ooo o.oo0 o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo 0.059 0.059 0.059 0.059 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 2510.48 2557.72 2605.45 2653.43 2701.45 2749.26 2767.75 2796.73 2844.17 2891.60 2939.04 2986.48 3033.92 3081.35 3128.79 3176.23 3223.66 3271.10 3318.54 3365.97 3380.87 3413.41 3460.85 3508.28 3555.72 Comment End Dir: 5869.45ft MD, 4125.60ft TVD Target - MPJ-08A T1 (June2) Geosteer @ 0.059°/100ft: 6515.70ft MD 4125.60ft TVD Target - MPJ-b8A T2 (June2) Continued... 24 November, 1999 - 13:18 - 2 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for MPJ-O8A Wp08 Revised: 24 November, 1999 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 6750.00 90,137 283.269 4059.72 6800.00 90.166 283.267 4059.59 6850.00 90.196 283.266 4059.43 6900.00 90.225 283.265 4059.25 6950,00 90.254 283,263 4059.04 7000.00 90.284 283,262 4058.80 7050.00 90.313 283.261 4058.54 7100.00 90.342 283.259 4058.26 7150.00 90,371 283.258 4057.94 7200.00 90.401 283.257 4057.61 7250.00 90.430 283.255 4057.25 7300.00 90.459 283.254 4056.86 7350.00 90.488 283,253 4056.44 7400.00 90.518 283.252 4056.01 7450.00 90.547 283.250 4055.54 7500.00 90.576 283.249 4055.05 7550.00 90.605 283.248 4054.54 7600.00 90.635 283.246 4053.99 7650.00 90.664 283.245 4053.43 7700,00 90.693 283.244 4052.84 7750.00 90.723 283.242 4052.22 7800.00 90.752 283.241 4051.57 7850.00 90.781 283.240 4050.91 7900.00 90.810 283.239 4050.21 7950.00 90.840 283.237 4049.49 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 4125.32 2400.01 N 2752.68 W 4125.19 2411.49 N 2801.35 W 4125.03 2422.96 N 2850.02 W 4124.85 2434.43 N 2898.68 W 4124.64 2445.91 N 2947.35 W 4124.40 2457.38 N 2996.01 W 4124.14 2468.85 N 3044.68 W 4123.86 2480.31 N 3093.34 W 4123.54 2491.78 N 3142.01 W 4123.21 2503.25 N 3190.68 W 4122.85 2514.71 N 3239.34 W 4122.46 2526.18 N 3288.01 W 4122.04 2537.64 N 3336.68 W 4121.61 2549.10 N 3385.34 W 4121.14 2560.56 N 3434.01 W 4120.65 2572.02 N 3482.68 W 4120.14 2583.48 N 3531.34 W 4119.59 2594.93 N 3580.01 W 4119.03 2606.39 N 3628.68 W 4118.44 2617.84 N 3677.34 W 4117.82 2629.30 N 3726.01 W 4117.17 2640.75 N 3774.68 W 4116.51 2652.20 N 3823.34 W 4115.81 2663.65 N 3872.01 W 4115.09 2675.10 N 3920.68 W Alaska State Plane 4 Milne Point MPJ Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100fi) (fi) 6017352.20 N 549205.59 E 0.059 3603.15 6017363,33 N 549156,84 E 0.059 3650.59 6017374.47 N 549108.10 E 0.059 3698.02 6017385.60 N 549059.35 E 0.059 3745.46 6017396.73 N 549010,61E 0.059 3792.89 6017407.86 N 548961.86 E 0.059 3840.32 6017418,99 N 548913.12 E 0.059 3887.75 6017430.12 N 548864.37 E 0.059 3935.19 6017441.25 N 548815.63 E 0.059 3982.62 6017452.37 N 548766.88 E 0.059 4030.05 6017463.50 N 548718.14 E 0.059 4077.48 6017474.62 N 548669.39 E 0.059 4124.91 6017485.75 N 548620.65 E 0.059 4172.34 6017496.87 N 548571.90 E 0.059 4219.77 6017507.99 N 548523,16 E 0.059 4267.20 6017519.11 N 548474,41 E 0.059 4314.62 6017530.23 N 548425.67 E 0.059 4362.05 6017541.34 N 548376.92 E 0.059 4409.48 6017552.46 N 548328.18 E 0.059 4456.90 6017563.57 N 548279.43 E 0,059 4504.33 6017574.69 N 548230.69 E 0.059 4551.75 6017585.80 N 548181.94 E 0.059 4599.18 6017596.91N 548133.19 E 0.059 4646.60 6017608.02 N 548084.45 E 0.059 4694.02 6017619.13 N 548035.70 E 0.059 4741.44 Comment Continued... 24 November, 1999 - 13:18 - 3 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for MPJ-O8A Wp08 Revised: 24 November, 1999 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 8000.00 90.869 283.236 4048.75 8050.00 90.898 283.235 4047.97 8100.00 90.927 283.233 4047.18 8150.00 90.957 283.232 4046.36 8200.00 90.986 283.231 4045.51 8250.00 91.015 283.229 4044.64 8300.00 91.045 283.228 4043.74 8350.00 91.074 283.227 4042.81 8400.00 91.103 283.225 4041.86 8450.00 91.132 283.224 4040.89 8494.38 91.158 283.223 4040.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4114.35 2686.55 N 3969.34 W 6017630~24 N 547986.96 E 4113.57 2697.99 N 4018.01 W 6017641.34 N 547938.21 E 4112.78 2709.44 N 4066.67 W 6017652.45 N 547889.47 E 4111.96 2720.88 N 4115.34 W 6017663.55 N 547840.73 E 4111.11 2732.32 N 4164.01 W 6017674.66 N 547791.98 E 4110.24 2743.76 N 4212.67 W 6017685.76 N 547743.24 E 4109.34 2755.20 N 4261.34 W 6017696.86 N 547694.49 E 4108.41 2766.64 N 4310.00 W 6017707.96 N 547645.75 E 4107.46 2778.08 N 4358.67 W 6017719.06 N 547597.01 E 4106.49 2789.52 N 4407.33 W 6017730.15 N 547548.26 E 4105.60 2799.67 N 4450.52 W 6017740.00 N 547505.00 E 8500.00 91.158 283.223 4039.89 4105.49 2800.95 N 4456.00W 6017741.25 N 547499.52 E 8550.00 91.158 283.223 4038.88 4104.48 2812.39 N 4504.66W 6017752.34 N 547450.78 E 8600.00 91.158 283.223 4037.86 4103.46 2823.82 N 4553,33W 6017763.44 N 547402.03 E 8644.38 91.158 283.223 4036.97 4102.57 2833.97 N 4596.52W 6017773.29 N 547358.77 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Dogleg Rate (°/100ft) 0.059 0.059 0.059 0.059 0.059 0.059 0.059 0.059 0.059 0.059 0.059 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 4788.86 4836.28 4883.70 4931.12 4978.54 5025.96 5073.37 5120.79 5168.21 5215.62 5257.70 5263.03 5310.45 5357.86 5399.94 Comment End Dir' 8494.38ft MD, 4105.60ft TVD Target - MPJ-08A T3 (June2) Total Depth: 8644.38ft MD, 4102.57ft TVD 4 1/2" Liner The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 301.700° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8644.38ft., The Bottom Hole Displacement is 5399.94ft., in the Direction of 301.656° (True). Continued... 24 November, 1999 - 13:18 - 4 - DrillQuest 1.05.04c TREE. 'Cameron 3-1/8" 5M PROP_O_S_E ::) COMPLETION 1V~.E. LxL~H1E/~,,D:EV~ (Mtoll'~Xbltr~" ~IF~bgH'TI~ad ~ -- ..i~,~I-IIFI II i, !.%~'~J~b. _ "~-~' cKeBilar Box~LLEE~/~635~.570C~, hanger. 'H' BPV profile I I mi CsgheadisWKM11"5m / /i!i :j~.!~I$:~i ;iii 3/8 54.51b/t LBO" f · ~ iiiiiii~ ~!! ~ /~~i~iI---- --Baker TEe Wire I I I i i __ 3-1/2" x 1" sidepocket GLM I 2~16' I 9-sis", 40 ~b/., L-80 Su~ace Casing ~. II!i:~i:i~i~::i:;:i~:::i! ' ' - / j?ii J ~I Selective X Nipple 2.813 Centrilift ~f4 Rat cable "~"- i" = Baker Sentry Gauge I ,.oo, I Capacity: .0383 bbl/ft ...... ' ESPCP assembly (bottom) ~ ~ 7"x4 1/2" liner/hgr pkr. '~--"~-~ 11 ~ Bake,l ECP (top of 'OB' sand)5,893' - Cement retainer at 4890~~' ' - -, ............ ~ 4-1/2', 12.6/fL-80,~SlottedLiner T°ppacilrat5007' !~ ~ DATE REV. BY GOMMENTS Milno ~oin~ Hni~ WELL: J-08A APl NO: 50-029- 22497-01 11/20/99 FJ Horizontal Sidetrack Wellhead: WKM 11" 5M w/11' x 2 7/8" 8rd EUE tbg. hng., 2.5 .... H" BPV profile Tree: Cameron 2-9/16" - 5M Actuator: Baker CAC 13 3/8" L-80, 64 ppf csg. 9 5/8" 40 ppf, L-80, Btrc. b516' md IJ 7", 26 ppf, L-80 Btrc. production csg Minimum gravel pack ID is 3.0" in seal bore below screens (5749' and 5230' md) Stimulation Summary: NB/NC Sands - 12/06 / 95, 14,200 lbs. 16 - 20 Carboite frac pack to screenout NF Sands - 12 / 04/95, 5100 lbs. 16-20 Carbolite frac pack to screenout Perforation Summary: Ref. Loc ^WS GR/CCL - 11/29/95 ,, Size SPF Interval (TVD) 4.5" 12 5076'-5136' (3901'-3916') 4.5" 12 5174'-5216' (3925'-3934') 4.5" 12 5806'-5871' (4018'-4026') Baker Inteq PerfForm 22.7 gr. charges, 135 / 45 deg phasing, EHD = 0.59", TTP = 5.96" Open Hole Summary: Open hole from 7" csg. shoe at 6131' to TD (8593'). 3.5" x 4.75" prepacked (16-30 Baker Bond) screen (0.20 gage) from 6091' to 8573' MPU J-08 tPresent Condition) KB = 65.20' (Nabors 22E) LoL = 35.7' DF to I/7" hng. = 28.65' (N22E) KOP = 1550' Max hole angle = 94 deg. from 8400' to TD. Horizontal section: 6400' - TD DLS of 4 to 7 deg./100' from 5090' to 5500' Cement Cement Retainer "'VTL' pkr. HES closing sleeve 4", 9.5 ppf blank pipe Baker 4" Slimpack pre- packed screen (0.012" ga.) HES 7" 'BWD' Pkr. 4", 9.5 ppf tbg. space out HES 7" 'PGP' pkr. 'HES flow sub (sliding slv.) 9.5 ppf blank pipe 4" Slimpack pre- packed screen (0.012" ga.) Baker 7" F-2 Sz 85-40 Pkr. HES 3.5" 'XN' Npl. (2.63" ng) HES standing valve 7" Csg. Shoe 4.75" x 3.5" prepacked liner 4,890' J 5007' md 5016' md 5037' md 5069' md 5230' md 5749' md 5756' md 5772' md 5803' md 5906' wlm 5911' md 6131' md I 6091' md J 8585' md. TD of 6" open hole = 8593' md Two flapper valve assys. "V" Set Shoe 8593' md DATE 08/94 REV. BY ML COMMENTS Initial ESP Completion 12/08/95 JBF Complete N B/C/F Sands and RunESP 9/27/99 MTT Proposed decompletion 4ES MILNE POINT UNIT Well MP J-08 APl NO: 50-029-20497 BP EXPLORATION (AK) VI:NLIUH I~L~EI~AE I lq* DATE INVOICE / CRED~ ME~ DE~RI~ION GROSS DI~UNT NET 10~7~ CKlO2799F 100. O0 100. O0 HANDLINO INST: S/H TERRIE HUBBLI X4~8 i I THE A.ACHED CHECK IS IN PAYME~ F~ ~ ~RIBED A~. ~ 1 OO. OO l OO~ OO ..:.".'.:.. ,,,~,~,.o~..,.,:o,,~,,~.o No.. :i:H :.~..~:.~:1 581 93. · ..' :.. .... '!.:'.::'?.~ .:.:'i: :j~i~:~,~U^TEO~ .:i::~i~:: ':'::'. :'"" .... ' .................... ..,,.:,.,::,, :::,~.: .... '~v~x~oo,,o ::'::':: ",.'. ::::::.:,' :'.~: ,:' ..,.~'::: .,~:::' '::":::.i ........ , , ........: .... ..,.: : ?: :: :~';::~,, ,:.::.: , ....,,~.:.,. ::,.:.::~, :,....:, , :.:~ :..~: .,':: ,... ,.~:. , .....~"':~:::"'~'~"~:: :" ':' :~"': .. ~:oz 5~z" "::~:~'e~": ~':':::' ~:'"' ...... : ..... :~;~;;,:~.~ ...,. .:;,.:;: ~ ,~ ;~.~.:~:' 412 PAY To Th ORDER oN£. HUN~:RED.i~i& ::00/!********************************************** UE;.:'-DOLLAR .... :/:::! DATE :::::::i:i '" .... : ":::'ii ::AMOUNT :1. O/28/c?c? ALASKA STATE .DEPT OF REVENUE : AOOCC: .':':. !:~: :' ': :: ...... '. 3001 :PORCUPINE'DR AK 99501-3120 ANCHORAQE NOT VALID AFTER 120 DAYS ,~:, c.EcKus co=P^.¥ FIELD & POOL -~-~ ~'/~"/?-_.~ INIT CLASS WELL NAME.,,~A'~_.(/'_ ...,.?"L~,~ PROGRAM: exp~dev ?'~-0// GEOL AREA 'ADMINISTRATION 1. ENGINEERING . 3. 4. 5. 6. 7. 8. 9. 10. 11. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. /~_.PR DATE 26. 28. 29. GEOLOGY 30. 31. 32. ;~ DATE 33. ~ /['-,~,9'6''/¢) 34. ANNULAR DISPOSAL 35. APPR DATE Permit fee attached ....................... Lease number appropriate:¢~. ................. Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic 8, equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to % . f~., psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. · redrll / serv ~ wellbore seg ann. disposal para req __ UNIT# ('~?/ ~ ,,~-~ ON/OFF SHORE N '~N N N Permit can be issued w,o hydrogen sulfide measures ..... (~y~N Data presented on potential overpressure zones~ ...... Seismic analysis of shallow gas zones ............. ~J~ Seabed condition su~ey (if off-shore) ............. ~ Contact name/phone for weekly progress repods [explora~ only] With proper cementing records, this plan (A) will contain waste in a suitable receivin~ ~Y (B) will not contaminate freshwater; or~e drill~aste... to s ¢ ce; ........ (C) will not impair mechanical ~ity ~~ell ~or d~sposal; (D) will not damage producing~b~n or impair recove~ from a pool; and ~ (E) will not circumvent 20 ~C 25.252 or 20 ~C 25.412. GEOLOGY: ENGINEERING: UIC/Annular ;/VM---"-"'"'- JDH., _~ SFDr~ TEM ~-~-_~'"~. -~ ~/,"1 '~%. c:~mso~ce~wordianXdiana~checklist (rev. 09/27/99) COMMISSION: co co,4_~ Comments/Instructions: 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 APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. · Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Mar 02 21:48:37 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/03/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF RECEIVED Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING MWD RUN 2 AK-MM-90211 GREG GRIFFIN TOM ANGLIN MAR 0 7 2000 Naska Oil & Gas Cons. Commission Anchorage MPJ-08A 500292249701 BP EXPLORATION (ALASKA), INC. Sperry-Sun 02-MAR-00 28 13N 10E 2576 1938 66.00 66.00 35.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 4867.0 6.125 6.125 MWD RUN 3 AK-MM-90211 GREG GRIFFIN DON WESTER PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2&3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. EWR4 DATA FROM 5950'MD, 4119'TVD TO 8448'MD, 4104'TVD (MWD RUN 3) IS REPROCESSED TO CORRECT FOR INSTRUMENT DRIFT DUE TO ANTENNA DAMAGE. 5. DIGITAL AND LOG MWD DATA ARE DEPTH-CORRECTED TO THE PDC GR LOG OF 08/15/94 (MWD) WITH KBE = 64' A.M.S.L. THIS WELL KICKS OFF FROM MPJ-08 AT 4867'MD, 3850'TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3 REPRESENT WELL MPJ-08A WITH API%: 50-029-22497-01. THIS WELL REACHED A TOTAL DEPTH OF 8494'MD, 4140'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. EXTRA MEDIUM DEEP $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4760.5 8440.0 ROP 4816.0 8495.5 FET 4858.5 8449.0 RPD 4858.5 8449.0 RPM 4858.5 8449.0 RPS 4858.5 8449.0 RPX 4858.5 8449.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4760 5 4772 5 4778 5 4781 0 4795 0 4798 0 4805 5 4809 5 4814 0 4819 0 4822 0 '4826 5 4844 0 4845 5 4849 0 4860 5 4868 5 8495 5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: GR 4757.0 4769.0 4774.5 4776.5 4791.0 4795 0 4802 5 4806 5 4810 5 4815 0 4818 0 4824 0 4843 0 4845 0 4848 0 4859 0 4867 5 8494 5 EQUIVALENT UNSHIFTED DEPTH ....... BIT RUN NO MERGE TOP MERGE BASE 200 4757.0 5996.0 300 5996.0 8494.0 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 Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max DEPT FT 4760.5 8495.5 ROP MWD FT/H 0 2553.62 GR MWD API 26.76 133.12 RPX MWD OHMM 0.45 687.38 RPS MWD OHMM 0.33 1799.49 RPM MWD OHMM 0.15 2000 RPD MWD OHMM 0.04 1653.53 FET MWD HOUR 0.19 20.38 Mean Nsam 6628 7471 166.765 7360 74.7222 7360 10.3155 7182 12.027 7182 14.0316 7182 14.1776 7182 1.12568 7182 Reading 4760.5 4816 4760.5 4858.5 4858.5 4858.5 4858.5 4858.5 Reading 8495.5 8495.5 8440 8449 8449 8449 8449 8449 First Reading For Entire File .......... 4760.5 Last Reading For Entire File ........... 8495.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR ROP RPX FET RPD RPS RPM $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4757.0 4812 5 4857 0 4857 0 4857 0 4857 0 4857 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): STOP DEPTH 5942 5 5996 0 5949 5 5949 5 5949 5 5949 5 5949 5 19-DEC-99 Insite 0.41 Memory 5996.0 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): 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 68.1 87.8 TOOL NUMBER PBO1394GRV4 PBO1394GRV4 6.125 4867.0 Water Based 9.20 47.0 9.5 14000 4.6 .420 .502 .375 .300 70.0 85.0 70.0 7O.O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD 2 FT/H Min Max Mean Nsam 4757 5996 5376.5 2479 4.44 2553.62 164.186 2368 First Reading 4757 4812.5 Last Reading 5996 5996 GR MWD 2 API RPX MWD 2 OHMM RPS MWD 2 OHMM RPM MWD 2 OHMM RPD MWD 2 OHMM FET MWD 2 HOUR 26.76 132.47 0.45 687.38 0.33 687.46 0.15 2000 0.04 1653.53 0.35 20.26 77.7624 2372 7.69145 2186 8.60652 2186 15.2769 2186 14.7132 2186 1.15658 2186 4757 4857 4857 4857 4857 4857 5942 5 5949 5 5949 5 5949 5 5949 5 5949 5 First Reading For Entire File .......... 4757 Last Reading For Entire File ........... 5996 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/02 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 ....... 00/03/02 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5947.0 FET 5947.0 RPD 5950.0 RPM 5950.0 RPS 5950.0 RPX 5950.0 ROP 5996.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8439 0 8448 0 8448 0 8448 0 8448 0 8448 0 8494 5 22-DEC-99 Insite 0.41 Memory 8495.0 87.4 94.4 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) : 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 TOOL NUMBER PBO1394GRV4 PBO1394GRV4 6.125 4867.0 Water Based 9.20 48.0 8.2 27000 4.5 .350 .520 .200 .500 70.0 91.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 RPX MWD 3 OHMM 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 OHMM 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD 3 FT/H GR MWD 3 API RPX MWD 3 OHMM RPS MWD 3 OHMM Min Max Mean Nsam 5947 8494.5 7220.75 5096 0 1143 167.993 4997 45.46 133.12 73.2537 4985 3.73 555.26 11.4616 4997 3.99 1799.49 13.5212 4997 First Reading 5947 5996.5 5947 5950 5950 Last Reading 8494.5 8494.5 8439 8448 8448 RPM MWD 3 OHMM 4.37 42.3 RPD MWD 3 OHMM 4.7 34.4 FET MWD 3 HOUR 0.19 20.38 13.5918 4997 5950 8448 14.0516 4997 5950 8448 1.12426 5003 5947 8448 First Reading For Entire File .......... 5947 Last Reading For Entire File ........... 8494.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/03/02 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