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190-039
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, October 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC L-05 MILNE PT UNIT L-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/12/2023 L-05 50-029-22030-00-00 190-039-0 W SPT 7024 1900390 1756 1603 1601 1601 1603 244 515 523 518 4YRTST P Sully Sullivan 8/15/2023 PT to 2500 for 500 psi dp 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT L-05 Inspection Date: Tubing OA Packer Depth 323 2500 2442 2426IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230816133943 BBL Pumped:2.5 BBL Returned:2.5 Thursday, October 12, 2023 Page 1 of 1 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/04/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-05 (PTD 190-039) Injection Profile 09/11/2020 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 1900390 E-Set: 34362 Abby Bell 12/09/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Performed: Suspend ❑ Perforate ❑ Plug for Retlrill ❑ :rforate New Pool ❑ 2. Operator Name: Hilcorp Alaska LLC 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 7. Property Designation (Lease Number): ADL0025509 Fracture Stimulatc Pull Tubing Operations shutdown 77 Other Stimulat Alter Casing ❑ Change Approved Program ❑ Repair We❑ Re-enter Sus Well 4. Well Class Before Work: P ❑ Other: Convert to Water Injector ❑✓ 5. Permit to Drill Number. P` SP Development Q Exploratory ❑ 190-039 Stratigraphic❑ Service ❑ 6. API Number: 50-029-22030-00-00 8. Well Name and Number: MILNE PT UNIT L-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 10,550 feet Plugs measured N/A feet true vertical 7,596 feet Junk measured N/A feet Effective Depth measured 10,441 feet Packer measured 9,631 feet true vertical 7,529 feet true vertical 7,024 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Intermediate 6,044' 9-5/8" 6,044' 4,676' 3,520psi 220psi Production 10,528' 7° 10,528' 7,582' 7,240psi 5,410P si Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / L-80 EUE 8rd 9,706' 7,072' Packers and SSSV (type, measured and true vertical depth) PHIL Parma Packer N/A See Above 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: 116 72 1 177 1 360 1 376 Subseq:1 0 0 1 1,980 1 140 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: 1 1,180 Daily Report of Well Operations 0 Exploratory❑ Development Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Gas WDSPL ❑� 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: 319-259 Authorized Name: Chad Helgeson Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: tWellmanahilcorn.corn Authorized Signature: Date: 8/7/2019 Contact Phone: 777-8449 4BDMS A AUG 12 2019 Form 10-404 Revised 4/2017 Submit Original Only n Ilileaep Alaska. LLC Odg. KB Elev.: 32'(Nabors 33E) TD=10,550' (MD)/TD= 7,596(TVD) PBTD=10,441'(MD) / PBTD= 7,529(TVD) SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU L-05 Last Completed: 6/20/2009 PTD: 190-039 Tree 2-9/16" SM WKM Wellhead 11"x11"5M WKM w/11"2-7/8"WKM Tubing Hanger w/ EUE 8rd threads [op and bottom, 2-1/2" CIW "H" BPV profile OPEN HOLE / CEMENT DETAIL 13-3/8" 485 sks Permafrost "C"in 30" Hole 9-5/8" 269bbi Arctic Set IV, 71bb1 Class'G' in 12-1/4" Hole 7" 90bbl Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID 1 Top Btm BPF 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 115' 0.157 9-5/8" Surface 36/J-55/BTRC 8.921 Surface 6,044' 0.0773 7" Production 26/L-80/BTRC 6.276 Surface 10,528' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE Brd 2.441 Surface 9,706' 0.0058 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle = 47' to 52' f/ 2,800' to TD Max Hole Angle through perforations = 51' JEWELRY DETAIL No Depth Item 1 2,175' 2-7/8"HES X Nipple— ID= 2.313" 2 9,586' 2-7/8"HES X Nipple—ID=2.313" 3 9,631' PHL Hydraulic Set Perma-Latch Retrievable 4 9,653' 2-7/8" HES XN Nipple — ID=2.205" 5 9,705' WLEG — Bottom @ 9,706' PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) I Btm (TVD)7 FT Date Status abors 4ES-4/11/2001 9,808' 9,913' 7,137' 7,202' 105 10/20/1990 Open Kuparuk 9'949 9,964' 7,226' 7,234' 15 10/19/1990 Open 9,980' 9,999' 7,243' 7,256' 19 10/19/1990 Open 10,024' 10,098' 7,272' 7,318' 74 10/19/1990 Open STIMULATION SUMMARY Well Frac'd w/ 1,758bbis crosslink gel & 171,920 lbs 16-20 mesh carbolite proppant. GENERAL WELL INFO Revised By: TDF 7/29/2019 2030-00-00 and Comp. by Nabors 27E -10/27/1990 X-7/25/1994 25/1994abors [ESP 4ES-8/4/1997 abors 4ES-4/11/2001 abors 4ES —1/4/2003 ESP RWO by Nabors 3S-1/17/2009 ESP RWO by Nabors 3S- 6/20/2009 Convert to Water Injector by ASR 1 -7/11/2019 Revised By: TDF 7/29/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-05 ASR 1 50-029-22030-00-00 190-039 7/3/2019 7/31/2019 Daily Operations. 7/3/2019- Wednesday Start and service Rig generators. Spot in company Shack and crew shack, spot in Pit Trailer, spot in crane ND well head, NU BOPE (Mud cross, double gate/w 2-7/8"-3-1/2" VBR's, Hydril), Clean Pits and cuttings box from Fishing job with Peak super sucker. Crane Operations cont., Spot Mud Boat, Fly in well but and work floor. Spot in and rig up the ASR, RU all Pump lines and flow lines, Torque up BOPE and run Hydraulic lines, Hook up Fire and gas alarms. Make up test sub, got fill and shell test noticed that test chart recorder damaged. Secure well for the night. 7/4/2019-Thursday Start and service rig and equipment. Finish rig up Flow line and diverter Flow cross. RU New test chart trouble shoot new charts. ended up using old charts. conduct shell test. test good. call out state rep. Bob Noble. Conduct BOPE test as per Sundry 250/low 2,500/high on all Equipment test with 2-7/8" & 3-1/2" test joints. Fire and gas alarms and Pit volume alarms. RD Test equipment, guys have lunch at the same time. RU Spooler containment, hang ESP sheave and elephant trunk, level out HPH and connect trough extension. Pump 40 Bbls of 8.4# source water Pull test plug and BPV. Make up and Unland tbg. ASR RKB 18.32', unseat @63K up wt. 83k. Lay down 2 jnts of 2-7/8" 6.5# EUE 8rnd 1-80. cut cable at clamp and sink 3rd jnt. Secure well for night 7/5/2019 - Friday Star and service rig and equipment, prep fresh water test fluid with KCI. RU pump 40 bbls of 8.4# source water. Hydraulic Pipe Handler had a leak had to repair leak. POOH/w ESP cable/w LaSalle Allen bolt on collar clamps( clams old and eroded fought some of them) on 2-7/8" 6.5# EUE L-80 8rnd tbg string cable over sheave as needed. tie into spooler. 800'/hr double displacement on the way out. 4,743'+- swap ESP cable to second spool. Cont. POOH/w ESP 7,502'+-, cable secure with LaSalle clamp cut cable and sinkjnt. total of 148 Bbls of fluid loss. secure well for night. 7/6/2019-Saturday Start and service rig and Equipment, Check pressure on well. well on a vac. Pump 40 Bbls. Unlock and open well, pull to cable cut, prep and splice together. POOH/w ESP cable/w LaSalle Allen bolt on collar clamps( lams old and eroded fought some of them) on 2-7/8" 6.5# EUE L-80 8rnd tbg 1,100'/hr double displacement on the way out. Lay down ESP BHA and RD Baker equipment. load junk tbg in pipe tub to take to G&I, Adjust pipe racks for range 3 work string. crews take lunch in between. Pumping 5 Bbls every 30 min. Change over tbg handling equipment to 3.5", Rack and tally167 jnts 3.5" Work String. RIH/w 5-5/8" tri cone rock bit on 7" CSG Scraper to 4,000'+- pumping double displacement going in the hole. secure well for the night. 7/7/2019-Sunday Start and service rig and Equipment, Do full inspection and check all fittings and bolds on new HPH. Check Presure on the well. well on a vac. pump 40 bbls of 8.4# source water. Finish in the Hole with 3.5" Work String/7" scraper with 5-5/8" Tri- cone bit to 9,709' and reciprocate. Pumping double Displacement. 1,000'+-/hr. adjust pipe racks and prep to POOH. POOH/w 3.5" Work String/ 7" scraper with 5 5/8" Tri-cone bit to 1,221.30' at 1,304'/hr pumping double displacement. secure well for the night. 7/8/2019 - Monday Start and service Rig and Equipment. Check Pressure on the well. Well on a vac. Pump 40 Bbls of #8.4 Source Water. Finish out of the hole 30 ints of 3.5" Work string. Break off Bit and Scraper and Make up 7" Test PKR. RIH/w 7" Test PKR to 9,709' pumping Double displacement on the way in.1,280'/hr. 48K/Down,1o1K/Up, Set 7" PKR, Fill hole With #8.4 source water 56 bbls to fill. Fluid level @ 2,121'+-. Let air work out of system. Pressure up to 1,950psi as per sundry 1.8Bbls to pressure up. chart for 30 min. Test Good. Bleed off CSG . 2 Bbls return. Release PKR 18k over to release. let elements relax 15 min and lay dwn 2 jnts 3.5" worksting. Secure well for the night. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-05 ASR 1 50-029-22030-00-00 190-039 1 7/3/2019 7/31/2019 Daily Operations. 7/9/2019 -Tuesday Start and service rig and equipment, Check pressure on the well. well on a vac. Pump 40 Bbls of 8.4# Source Water. POOH/w 7" PKR on 3.5" Work string to 2,404' MD pumping double displacement 1,150'/hr. Rig ESD was hit in the X -box on accident. When going to start rig back up the rig would not start. Could not trouble shoot with out computer. Ended up calling VMS to come out. found that starter went bad. Replaced the starter. Adjust Pipe racks, Crew load prep and tally first 104 jnts of 2- 7/8" 6/5# EUE 8rnd injection string. POOH/w 3.5" Work String to 1,200.94'. secure the well for the night. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-05 ASR 1 50-029-22030-00-00 190-039 7/3/2019 1 7/31/2019 Daily Operations. 7/10/2019- Wednesday Start and service the rig and Equipment, Check pressure on the well. Well on a Vac. Pump 40 bbls of Source Water. Finish out of the hole with Test PKR on 3.5" Work String. 1200.94', Pumping Double displacement on the way out. Change over to 2-7/8" Handling equipment, Make up BHA (WLEG, 10'PUP, JNT, 10'PUP, XN Nipple, 10' PUP,5' PUP Retrievable Hydraulic set PKR, 5'PUP,JNT,30'PUP, X Nipple, 10'PUP). RIH/ w Completion 2-7/8" 6.5# L-80 8rnd EUE tbg to 8,064' MD. Fluid loss for the day 84 BBIs. 7/11/2019 -Thursday Start and service the rig and equipment. check pressure on well. well on a vac. Pump 40 Bbls of 8.4# source water. RIH to EOT 9,705.68' MD, XN @ 9,653.03' MD, PKR @ 9,631.00' MD, X Nipple @ 9,585.83' MD, X Nipple @ 2,175.28'. Make up Tbg hanger and land 55/up wt. 32/dwn wt. Start to spot PKR Fluid, filled Csg 15 Bbls, Saw returns @ 115 Bbls 260 PSI @ 3 BPM, total 230 Bbls of 8.4# treated source water followed by 70 Bbls of dieslel. 169 Bbls loss total during the spot. Dropped the ball and rod. filled tbg 5 Bbls pressuered up to 3,000PSI charted 30 Min. Bleed off and test Back side to 1,900 30 p1Ln (witness waived by Brian BixbY). Set BPV Start well Kill on G-14. Start RDMO, ALL pump and flow lines, Rig down rig, Prep and suck out Pits, four bold the stack above double gate. Secure the well for the night, Total fluid loss for the day 220 Bbls. 7/12/2019 - Friday No operations to report. 7/13/2019 -Saturday No operations to report. 7/14/2019 -Sunday No operations to report. 7/15/2019 - Monday No operations to report. 7/16/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit NumberStart Date End Date MP L-05 Slick Line 50-029-22030-00-00 190-039 7/3/2019 7/31/2019 Daily Operations. 7/24/2019- Wednesday No operations to report. 7/25/2019 -Thursday MPU Well Support had Slickline set downhole plug,then a TWC to remove tree. Installed Cameron replacement, PT'd tree to 5,000# and re -tested flowline to 3,650#. Removed TWC and handed well over to Slickline. Slickline pull downhole plug. RD Slickline unit. 7/26/2019 - friday No operations to report. 7/27/2019 -Saturday No operations to report. 7/28/2019 -Sunday No operations to report. 7/29/2019 - Monday No operations to report. 7/30/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-05 Slick Line 50-029-22030-00-00 190-039 7/3/2019 7/31/2019 Daily Operations. 7/31/2019 -Wednesday No operations to report. 8/1/2019 -Thursday MIT -IA to 1756 psi (PASSED) (Witnessed by Brian Bixby) (PT Surface Equip to 250/3500 psi) Pump 2.7 bbls Dsl to reach test pressure. 1st 15 Min IA lost 57 psi. 2nd 15 Min IA lost 15 psi. Bleed IA down w/ 2.7 bbls Dsl returned. 8/2/2019 - Friday No operations to report. 8/3/2019 -Saturday No operations to report. 8/4/2019 -Sunday No operations to report. 8/5/2019 - Monday No operations to report. 8/6/2019 -Tuesday No operations to report. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p DATE: Monday, August 5, 2019 P.1. Supervisor ��f t O/Q/� SUBJECT: Mechanical Integrity Tests ( Hilcorp Alaska LLC L-05 FROM: Brian Bixby MILNE PT UNIT 1.45 Petroleum Inspector See: Inspector Reviewed By: P.I. Supry _ NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT L-05 API Well Number 50-029-22030-00-00 Inspector Name: Brian Bixby Insp Num: mitBDB190805070042 Permit Number: 190-039-0 Inspection Date: 8/1/2019 ' Rel Insp Num: Monday, August 5, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i L-05 ,Type Inj w' TVD 7024 Tubing 1157 1160 1116 1157 - - PTD 1900390 'Type Test SPT Test psi 1756 IA 139 2426 - 2369 2354 - — _ f BBL Pumped: p z 7 ' :BBL Returned: 2.7 OA ' OA 10 61 6866 Interval INITAL - P/F P Notes: Monday, August 5, 2019 Page I of 1 Apck L_ ®s � Iqu�3g� Regg, James B (CED) From: Cody Rymut - (C) <crymut@hilcorp.com> Sent: Tuesday, July 30, 2019 4:25 PM I I To: Regg, James B (CED); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (CED); Wallace, Chris D (CED) Subject: BOPE Test Report Attachments: MIT MPU L-05 07-11-19.xlsx Phoebe, My apologies for the delayed response. Here are the requested changes. Thank you for your help. If for some reason you do not receive a response from the company reps on the ASR or the 401, please feel free to contact me anytime and I'll ensure you get a response. Cody Rymut Rig Manager Hilcorp, Alaska C:907-230-3594 crymut@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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. Submit t0: lm regg091aeka.q. OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test AOGCC.Insoectors�elasksbov: ohoebebrooksl®alaska.00v Milne Pt Unit L chits wellece�alaska.00v 7f �I�IIi Well L-05 INTERVAL Cooes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4x Four Yet, Cycle PTD 1900390 Type Int W Tubing 0 3100 3100 3100 N=Not mjerog Type Test P Packer ND 7024 BBL Pump 2.9 IA 0 1900 - 1900 1900 Interval I Test psi 1756 BBL Re um 2.9 OA 0 0 0 0 Result P Notes: Brian Bixby waived witness. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer NO BBL Pump IA Interval Test psi BBL Return OA j Result Note.: Well Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type lnj Tubing Type T. Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Teslpsi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Int Tubing Type Test Packer ND BBL Pump IA Interval Teslpsi IBBL etumi OA I I I I I Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type lnl Tubing Type Test Packer ND BBL Pump IA Interval Test inti BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes' TYPE INJ Cadets TYPE TEST Mies INTERVAL Cooes Ini C.. W=Water P=Pressure Test 1=1nexal Test P=Pass G=Gas 0= Mar(demlbe In Notes) 4x Four Yet, Cycle F=Fal S=Slurry V= Required by Variance 1=iron Wvve I=industrial Waalawaler 0= Mer (doince m rtes) N=Not mjerog Form 10426 (Revised 0112017) MIT MPu L45 07-11.19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU L-05 Permit to Drill Number: 190-039 Sundry Number: 319-259 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, zvo� Daniel T. Seamount, Jr. Commissioner DATED this,? ? day of May, 2019. RBDMSLtev MAY 2 4 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAY 2 0 2019 0GCC 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: Convert to Info 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0 • Stratigraphic ❑ Service ❑ 190-039 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22030-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT L-05 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025509 MILNE POINT/ KUPARUK RIVER OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,550' 7,596' 10,441' 7,529' 1,520 NIA N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' N/A N/A Intermediate 6,044' 9-5/8" 6,044' 4,676' 3,520psi 220psi Production 10,528' 7" 10,528' 7,582' 7,240psi 5,410psi Perforation Depth MO (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-718" 6.5# / L-80 / EU 8rd 9757 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A & N/A N/A & N/A 12. Attachments: Proposal Summary ❑ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/3/2019 OIL ❑ WINJ Q ' WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman TfN/ Authorized Title: Operations Manager Contact Email: twellfrlaD hilcor .Goth Contact Phone: 777-8449 Authorized Signature: Date: 5/1 712 01 9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that /a representative may witness Sundry Number: 20 —259 ^59 Plug Integrity ❑ BOP Test u Mechanics Integrity Test Location Clearance El Other: -A 7— S -61D 60A L' T 2 4 1019 Post Initial Injection MIT Req'd? Yes No ElRBDMSL�MAY Spacing Exception Required? •� Yes ❑ No Subsequent Form Required: / 1 U APPROVED BY / 311 Approved by: COMMISSIONER THE COMMISSION Date [/ �!/ j,�,&11es-11•'ti ORIGINAL orm 10403 Revised 4!201 Approved application is valid for 12 months from the date of approval. ubmit Form and Attachments in Duplicate K 1Glwo p Alaska, LLI Convert to Injector Well: MPU L-05 Date: 05-15-19 Well Name: MPU L-05 API Number: 50-029-22030-00 Current Status: Shut-in ESP Producer Pad: L -Pad Estimated Start Date: June 3, 2019 Rig: ASR Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-039 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: Job Type: Convert to PWI Current Bottom Hole Pressure: 1,880 psi @ 7,100' TVD Downhole Gauge: 5 day SI (7/31/18) 15.1 PPG Maximum Expected BHP: 2,220 psi @ 7,000' TVD Downhole Gauge: L-43 PBU (9/18/17) 16.1 PPG MPSP: 1,520 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 53' @ 10,400' MD BPV Profile: 2-1/2" CIW Type H Brief Well Summary: MPU ESP producer L-05 well was drilled and completed as a Kuparuk producer in October of 1990. The well was perforated and fracture stimulated in the Kuparuk A, B and C sands. The well has had multiple ESP's and RWO's to replace them with an average run time of just over 4 years. The current ESP was run in 2009 and has a run time of 10 years. The development in the area has 4 prodcuers in the Kuparuk sands in the fault block (L- 04, L-05, L-41, and L-43) and no injectors. Converting L-05 to an injector will support reservoir pressure and sweep to the other producers in this fault block. Notes Regarding Wellbore Condition P� • The 7" production casing passed an MIT to 3,000psi on 04/21/90 Objective: • Pull & recover 2-7/8" ESP completion • Clean and pressure test 7" casing • Run new 3-1/2" tubing and source water injection completion Area of Review — Milne Point Unit L-05 (190-039) / Prior to the conversion of well MPU L-05 from producer to water injector, an Area of Review (AOR) must be conducted. This AOR found one other well (MPU L-43) within % mile of L -05's entry point into the Kuparuk Formation. Table 1: Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity MPU L-05 190-039 0' MIT -IA on 04/21/90 passed to 3,000psi MPU L-43 203-224 1,200' MIT -IA (7" casing and 4-1/2" Production Liner) on 07/02/04 passed to 4,000psi U Hilmn, Alaska. LL, Table 2: Completion Detail Convert to Injector Well: MPU L-05 Date: 05-15-19 API Well No Permit Well Current Status Zonal isolation (method) a. Drift tubing down to XN nipple. b. Set Catcher in 2.205 XN Nipple @ 9,657' MD. ESP Producer— Cement Bond Log run on 05/02/1990 50-029-22030-00-00 190-039 L-05 e. Pull DV from GLM @ 9,515' MD and leave open. indicates TOC at 8,160' MD 1,643' MD f. Pull Catcher in 2.205 XN Nipple @ 9,657' MD 2. RU LRS and PT lines to 3000 psi. Kuparuk Oil Pool above Kuparuk sand. production/returns tank. 4. Bullhead 70 bbls of 8.3 ppg source -water down tubing to the formation. Pumped 26bbls of cement, underdisplaced Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. ESP Producer— wiper plug to not bump plug & leave 3 bbls 50-029-23190-00-00 203-224 L-43 Kuparuk Oil Pool cement in liner. Full returns during RD Little Red Services. �di? 9. RU crane. Set BPV. ND Tree. NU BOPS. RD Crane. 10. cementing. Set liner top packer & circ t Brief RWO Procedure: 11. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 12. clean. Est TOC at 8,820' MD —492' MD pressure off tubing and casing. If needed, kill well w/ 8.3 ppg source -water prior to setting BPV plug. 13. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve above Kuparuk sand. Pre -Rig Procedure (non-sundried steps): 1. MIRU Slickline unit. a. Drift tubing down to XN nipple. b. Set Catcher in 2.205 XN Nipple @ 9,657' MD. c. Pull OV from GLM @ 137' MD. d. Set DV in GLM @ 137' MD. e. Pull DV from GLM @ 9,515' MD and leave open. f. Pull Catcher in 2.205 XN Nipple @ 9,657' MD 2. RU LRS and PT lines to 3000 psi. 3. Pump 1 IA volume (296 bbls) with 8.3 ppg source -water down IA, attempting to take fluids to production/returns tank. 4. Bullhead 70 bbls of 8.3 ppg source -water down tubing to the formation. 5. Clear and level pad area in front of well. Spot rig mats and containment. 6. RD well house and flowlines. Clear and level area around well. 7. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 8. RD Little Red Services. �di? 9. RU crane. Set BPV. ND Tree. NU BOPS. RD Crane. 10. NU BOPE house. Spot mud boat. t Brief RWO Procedure: 11. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 12. Check for pressure and if 0 psi, set BPV plug (converting to a TWC). If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.3 ppg source -water prior to setting BPV plug. 13. 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. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. Convert to Injector Well: MPU L-05 Hil.m Alaska. Lb Date: 05-15-19 d. Test VBR ram on 2-7/8" and 3-1/2" testjoints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails 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 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. 15. Bleed any pressure off casing to 500 bbl returns tank. Pull PBV plug and BPV. Kill well w/ 8.3 ppg source -water as needed. 16. Rig up spoolers for ESP cable. a. Baker Hughes representative should be onsite for ESP pull. 17. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2009 ESP completion was 82K lbs / SOF = 43K lbs (Nordic 3 block weight unrecorded). b. If needed, circulate (long or reverse) pill with lubricant, source -water, and/or baraclean pill prior to laying down the tubing hanger. 18. 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. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. Q 19. POOH and lay down the 2-7/8" tubing. Lay down ESP and motor_ �1p a. Send all tubing to G&I for washing and disposal. 1 b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over -torqued connections from previous tubing runs. d. The completion has the following amount of clamps/guards/cap-string: i. 159 LaSalle Clamps ii. 3 Flat Guards iii. 5 Protectolizers iv. 2 Cannon Clamps 20. MU 7" casing scraper BHA and TIH on 3-1/2" workstring to ±9,700' md. Reciprocate and circulate wellbore clean. H tlilcurp Alaska, LLQ Convert to Injector Well: MPU L-05 1 Date: 05-15-19 21. POOH and LD scraper. M `', 22. PU and TIH w/ 7" test packer on 3-1/2" workstring to ±9,700' md. Set and test packer and pressure test casing to 1,800psi for 30min (charted). a. ±9,700' and / 7,068' TVD: 0.25psi/ft TVD x 7,068' TVD = 1,767 psi 23. Unseat test packer, POOH and LD same. 24. PU and TIH w/ new 2-7/8" injection completion. Packer to be set at±9,650' md. a. 2-7/8" X Nipple (ID=2.313') at ±2,200' and ! b. 2-7/8" X Nipple (ID=2.313') at ±2,200' and c. 1 joint of 3-1/2" tubing C `�' d. 2-7/8"x7" Retrievable Packer at±9,650' and 6 e. 1 joint of 3-1/2" tubing f. 2-7/8" XN Nipple (ID=2.205') — Preloaded w/ RHC plug body g. 1 pup joint of 3-1/2" tubing h. WLEG 25. Land tubing hanger. RILDS. Lay down landing joint. Test tubing hanger packoff to S,OOOpsi. i. Note Pick-up and slack -off weights on tally. 26. Reverse circulate 230bbls of source water with corrosion inhibitor followed by 70bbls of diesel. Bullhead 15bbls of diesel down the tubing. 27. Drop ball & rod and set the packer. Increase the pressure and test the tubing to 3,OOOpsi. a. Deviation is —50 deg. Use rollers as needed. r L 28. Perform an MIT -IA to 1,800psi for 30min (charted). a. Completed MIT -IA form must be submitted to the AOGCC before the rig leaves location. 29. Set BPV. RD ASR #1, ancillary equipment and lines to 500bbl return tank. Post -Rig Procedure (non-sundried operations): 30. RD mud boat. RD BOPE house. Move to next well location. 31. RU crane. ND BOPE. 32. NU 2-1/16", 5,000# tree. Test tubing hanger void to 500 psi low/5,000 psi high. 33. Pull BPV. 34. RD crane. Move 500 bbl returns tank and rig mats to next well location. 35. Replace gauge(s) if removed. 36. Turn well over to production. RU well house and flowlines. 37. RU SL unit. a. Pull ball & rod. t� aW b. Pull RHC plug body. c. RD unit. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. AOR S z,y-(i 4. Blank RWO MOC Form Convert to Injector Well: MPU L-05 Date: 05-15-19 0 .a Alaska. UC Orig. KB Elev.: 32'(Nabors 33E) TD=10,550' (MD)/TD=7,596'(TVD) PBTD = 10,441'(MD) / PBTD= 7,52YWJD) SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU L-05 Last Completed: 6/20/2009 PTD: 190-039 Tree 2-9/16"5MWKM Wt/ Grade/ Conn 11"x11"5M WKM w/11"2-7/8" WKM Tubing Hanger w/ Wellhead EUE 8rd threads top and bottom, 2-1/2" CIW "H" BPV profile OPEN HOLE/ CEMENT DETAIL 13-3/8" 485 sks Permafrost "C"in 30" Hale 9-5/8" 269bb1 Arctic Set IV, 71bb1 Class 'G' in 12-1/4" Hole 7" 90bbl Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 115' 0.157 9-5/8" Surface 36/1-55/BTRC 8.921 Surface 6,044' 0.0773 7" Production 26/L-80/BTRC 6.276 Surface 10,528' 0.0383 (2/1`0 \Nolo TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 1 2.441 1 Surface 1 9,757' 1 0.0058 WELL INCLINATION DETAIL KO1 0:5 00' Max Hole Angle = 47" to 52" f/ 2,800' to TD Max Hole Angle through perforations = 51" JEWELRY DETAIL No Depth Item 1 137' Sta. 2: GLM--Camco 2-7/8" x 1", KBMM w/ DSOV 2 9,515' Sta. 2: GLM--Camco 2-7/8" x 1", KBMM w/ DGLV 3 9,657' 2-7/9" HES XN Nipple - ID= 2.205 4 9,671' WellLift Discharge Guage Unit: 5 91675.9' Discharge Head: FPHVDIS 6 9,676' Pump: SXD 141-P8 7 9,693' Pump: SXD 141-P8 8 9,709' Pump: SXD 141-138 9 9,716' Gas Separator: GRSFTXARH6 30 9,721' Upper Tandem Seal: GSB3DBUTSB/SB PFSA 11 9,727' Lower Tandem Seal: GSB3DBLT SB/SB PFSA 12 9,734' Motor- Rerated: KMHA 165Hp/ 2,133V/ 46A 13 9,754' WellLift MGU Sensor & Centralizer- Bottom @ 9,757' PERFORATION DETAIL KUP Sands Top (MD) Btm (MDbTop(TVD) ESP Btm (TVD) FT Date Status by Nabors 4ES - 8/4/1997 9,808' 9,913' by Nabors 4ES - 4/11/2001 7,202' 105 10/20/1990 Open RWO 9'949 9,964' RWO 7,234' 35 10/19/1990 Open Kuparuk 9,980' 9,999' 7,256' 19 10/19/1990 O en10,024' 10,098' 7,318' 74 10/19/1990 Open STIMULATION SUMMARY Well Frac'd w/ 1,758bbls crosslink gel & 171,9201bs 16-20 mesh carbolite proppant. GENERAL WELL INFO API: 50-029-22030-00-00 Drilled, Cased and Comp. by Nabors 27E -10/27/1990 ESP RWO-7/25/1994 ESP RWO by Nabors 4ES - 8/4/1997 ESP RWO by Nabors 4ES - 4/11/2001 ESP RWO by Nabors 4ES-1/4/2003 ESP RWO by Nabors 3S-1/17/2009 ESP RWO by Nabors 3S- 6/20/2009 Revised By: TDF 3/5/2019 0 PROPOSED SCHEMATIC Hileary Alaska, LLC Odg. KB Elev.: 32'(Nabos 33E) TREE & WELLHEAD Milne Point Unit Well: MPU L-05 Last Completed: 6/20/2009 PTD: 190-039 Tree 2-9/16"SM WKM Wt/Grade/Conn 11"x11"5MWKMw/11"2-7/8"WKM Tubing Hanger w/ Wellhead EUE 8rd threads top and bottom, 2-1/2" CIW "H" BPV profile OPEN HOLE / CEMENT DETAIL 13-3/8" 485 sks Permafrost'Vin 30" Hole 9-5/8" 269bbl Arctic Set IV, 71661 Class'G' in 12-1/4" Hole 7" 90bb1 Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/Weld 12.715 Surface 115' 0.157 9-5/8" Surface 36/J-55/BTRC 8.921 Surface 6,044' 0.0773 7" Production 26/L-80/BTRC 6.276 Surface 10,528' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 1 2.441 Surface 9,720' 1 0.0058 WELL INCLINATION DETAIL KOP @ 500' Max Hale Angle = 47'to 52° f/ 2,800' to TD Max Hole Angle through perforations = 51' TD=10,554 (MD) / TD= 7,596 0VD) PBTD=10,44V(MD) / PBTD = 7,529'(TVD) JEWELRY DETAIL No Depth Item 1 ±2,200 2-7/8"HESX Nipple —ID=2313" 2 ±91600 2-7/8"HES X Nipple —ID=2.313" 3 ±9,650 2-7/8"x7" Retrievable Packer 4 ±9,690 2-7/8" HES XN Nipple — I D=2.205" 5 ±9,720 WLEG PERFORATION DETAIL KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status by Nabors 4ES-8/4/1997 9,808' 9,913' 7,137' 1 7,202' 105 10/20/1990 Open RWO 9'949' 9,964'7,226' RWO 7,234' 15 10/19/1990 Open Kuparuk 9,980' 9,999' 7,243' 7,255' 19 10/19/1990 Open 10,024' 10,098' 7,272' 7,318' 74 10/19/1990 Open STIMULATION SUMMARY Well Frac d w/ 1,7581bbls crosslink gel & 171,920 lbs 16-20 mesh carbolite proppant. GENERAL WELL INFO API: 50-029-22030-00-00 Drilled, Cased and Comp. by Nabors 27E -10/27/1990 ESP RWO-7/25/1994 ESP RWO by Nabors 4ES-8/4/1997 ESP RWO by Nabors 4ES — 4/11/2001 ESP RWO by Nabors 4ES-1/4/2003 ESP RWO by Nabors 3S- 1/17/2009 ESP RWO by Nabors 3S- 6/20/2009 Revised By: TTW 5/13/2019 L i .�0g2 ,036 7 Q -55 L-41LEA1 cosi Ii L-11 i 5 6 996 L- a -43 7,077 7 �1p3 I i I I I L- 9 i 9 L- I TOj PETRA 511612019 9 48:57 AM HILCORP ALASKA LLC Milne Paint AOI MAP AELLMPL-05 025 MLLE RMws CIRCLE IN RED __ wurcc rods tnossl - - esw.': me LATA EYME.l McnIIGMr WELL SM90L5 fI NCI —1 n aiM w LIE Fi. 000 FEET 10,000,000 1,000,000 L C 0 a 100,000 LL V O N M 10,000 ro _ l7 O w O M N a L7 ri o 1,000 u M 100 u1 3 0 s F 10 HILCORP ALASKA LLC, MILNE PT UNIT L-05 (190-039) MILNE POINT, KUPARUK RIVER OIL Monthly Production Rates ■oil Cum- Prod Gas (mcf): 1,363,198 �aaa�aaa�aaa�N��� a��aaa�a�aaa��Naaa�� aaa�aaa�aaa�aaa��aaa��N 1 r���n� r'I O• V ``� IIS cnlb Will,AN '"■: % - �I r �=IZEC°o_�=_o_� 10,000,000 W m 1,000,000 o_ O 100,000 3 O T 10,000 0 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 Produced Gas (MCFM) - GOR -w- Produced Water (BOPM) -•- Produced Oil (BOPM) SPREADSHEET 1900390 MPU L -OS Prod Curves Well Oil V120 20190520.xisx - - - - - - - - - 5/21/2019 ilr • STATE OF ALASKA ~~~~~~~~ AL/•4 OIL AND GAS CONSERVATION CON~SION REPORT OF SUNDRY WELL OPERATIONS JUL 1 3 2[~T~~ ~rAS~C~ ~!1 ~t U~i.°i ~""~1Si`•i ~~14[~i;"ii '~' 1. Operations Performed: ~~tt;#~~~:<5?~ ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Pull Tubing ^ PerForate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown Change out ESP . ^ Perforate ^ Time E~ension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 190-039 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22030-00-00 ~ 7. KB Elevation (ft): 56, . 9. Well Name and Number: MPL-05 - 8. Property Designation: 10. Field / Pool(s): or/ /~eA( ~ ADL 025509 Milne Point Unit / Kuparuk River~apd~ .~ ~'`~' 11. Present well condition summary Total depth: measured 10550' feet true vertical 7596' . feet Plugs (measured) None Effective depth: measured 10441' feet Junk (measured) None true vertical 7529' feet Casing Length Size MD ND Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' 1740 750 Surface Intermediate 6044' 9-5/8" 6044' 4676' 3520 2020 Production 10528' 7" 10528' 7582' 7240 5410 Liner ~-z:+~~c'~s~~~ ~~t~ : s~ ~ ~~L~' . ~, , . Perforation Depth MD (ft): 9808' - 10098' Perforation Depth TVD (ft): 7136' - 7317' 2-7/8", 6.5# L-80 9757' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1050 Subsequent to operation: 264 ' 181 170 260 279 14. Attachments: ~ Copies of Logs and Sunieys run 15. Well Class after work: , ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ~^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: D ~"~ ~ Sig ature Phone 564-4628 at SondraStewman 564-4750 Form 10-404 Revised 04/2006 ~ ~~ ,Jlil ~ ~ 70a~ Submit Original Only /'b I° ~`f'G+~'l ~~i`l .~ ~~/~,y ~l Tree: 2 9/16" - 5M WKM ~ M P L~O ~ Orig. GB Elev~l6:o: (N 27E) Wellhead: 11" x 11" SM W w/ 11" x 2 7!8" WKM tbg. hng.,- 8rd KB To 7" csg. hng. = 34' (N 27E) EUE threads top and bottom, 2.5" CIW H BPV profile KOP @ 500' ~~~.,;,_`;":' Max. hole angle = 47 to 52 deg. Camco 2 7/8" x 1" from 2800' to TD sidepocket KBMM GLM 137~ Hole angle through perforations = 51 deg. . 9S18", 36 ppf, J-55 Btrs. 6,044' md / ~ ~ ' ( 2 7($" 6:5# EUE SRD, L-80 Tbg. I Drift ID: 2.441" Gapacity: 0.00579 BBL/FT 7", 26 ppf, L-80, Btrs. (cap. = 0.0383 bpf, ID = 6.276") PERFORATION SUMMARY REF: LOG: SWS CBT 05/02/96 Size SPF Interval (TVD) 4.5" 5 9808'-9913' (7137'-7202') 4.5" 5 9949'-9964' (7226'-7234') 4.5" 5 9980'-9999' (7243'-7256') 4.5" 5 10024'-10098' (7272'-7318') 4.5" Guns W/ Hyperjet II 5 JSPF & 72 Deg. Phasing EHD = 0.49" TTP= 30.25" Camco 2 7/8" x 1" sidepocket KBMM GLM 9515` HES 2.313" XN Nippie g657` (No-go ID 2.250") Welll.ift Discharge Gauge 9671 ` Tandem Pumps: 141-P8, 141-P8, g676` 18-P75 SXD Gas Separator, model - GRSFTXARH6 9716 i Intake @ 7078` ND ~ Tandem Seal Sections 9721 ~ GSB3DB UT/LT SB(SB PFSA Motor, Rerated: 165 HP, 2933 volt, g~34' 46 amp - model KMH-A WeIILift Intake Gauge w/6 fin 9754` centralizer Gauge @ 7102` TVD Mid-perF TVD - 7227` Mid-perf MD - 9953' PBTD ND - 7566' RWO fill tag 1/14l09, also RIH 10,349' md to 10756` during 6I20/09 RWO 7" float collar (PBTD) 10,441' md 7" casing shoe 10,528' md DATE REV.BY COMMENTS 7/25l94 ase o e omp e ion ESP re-com letion 8/04197 4/11/01 MDO/JBF GMH ESP re-completion by Nabors 4ES ESP RWO Nabors 4ES 1/02/03 1/16109 M. Linder L. Hulme ESP changeout ESP C/O and TD tag - Nabors 3S 6/20/09 L. Hulme ESP C/O and TD tag - Nabors 3S MILNE POINT UNIT wE~~ ~-a~ API NO: 50-029-22030 BP EXPLORATION (AK) • • I BP E~ Operations Legal Well Name: MPL-05 Common Well Name: MPL-05 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 3S Date From -~o Hours Task Gode NPT 6/16/2009 12:00 - 15:00 3.00 RIGD P 15:00 - 16:00 1.00 MOB P 16:00 - 18:00 I 2.00 I MOB I P 18:00 - 19:00 1.00 MOB P 19:00 - 20:00 1.00 RIGU P 20:00 - 00:00 4.00 KILL P I6/17/2009 ~ 00:00 - 02:00 ~ 2.00 ~ WHSUR ~ P 02:00 - 03:00 1.00 KILL P 03:00 - 05:00 2.00 KILL P 05:00 - 06:00 I 1.001 KILL I P 06:00 - 08:00 I 2.00 I KILL I P 08:00 - 09:00 I 1.001 DHB I P 09:00 - 10:00 1.00 WHSUR P 10:00 - 11:30 1.50 WHSUR P 11:30 - 15:00 3.50 BOPSU P 15:00 - 16:00 1.00 BOPSU P 16:00 - 20:00 4.00 BOPSU P Spud Date: 4/10/1990 Start: 6/15/2009 End: 6/23/2009 Rig Release: 6/20/2009 Rig Number: I : rr~ctse uescn~u~E~ or ~~era«c~ru~ PRE Scope and UD Derrick. R/D for move. PRE Held safety meeting with Truck crew on Rig move. Move Pipe shed and Pits. Move Carrier off MPL-11 with Pad Operator and BP / WSL present. PRE Lay Rig mats and position BOP cradle behind MPL-05. Spot Carrier over MPL-05 with Pad Operator and BP / WSL present. PRE Spot Pipe shed and Pits. Raise Derrick and scope up. PRE Rig up Steam, lines and Rig floor. Accepted Rig at 20:00 hours on 6/16/2009. DECOMP R/U kill manifold and hook up hard line to Tiger Tank and Choke. Install second annulus valve. Take on heated seawater to the Pits and Upright Tank. DECOMP PU / MU Lubricator and test with 500 psi. Well support tech pull BPV. WHPs: Tubin = 650 si IA = 1000 si, OA = 0 si. LD Lubricator. DECOMP Pressure test surface lines to 3,500 psi and downstream hardline to the Tiger Tank to 500 psi. DECOMP PJSM with rig crew and vac truck drivers. Initial WHP's: TBG = - A= 0 si. Bleed IA to 200 si tubin t 1 i. Break circulation with heated 8.45 ppg seawater down tubing taking returns thru choke to Tiger tank with 3 BPM / 60 psi. Returns of onlv qas to tank. Circulated 65 bbls at 3 BPM / 60 psi. No liquid returns to Tiger tank. Close choke and bullhead 35 bbls of heated 8.45 ppg seawater down tubing at 2 BPM / 20 psi. Monitor for 15 min, SICP = 80 psi. DECOMP Open choke and continue to circulate down tubing taking returns to Ti er tank at 4 BPM with 110 psi to 950 psi range. Circulate a total 200 bbls so far, returns of crude and gas to tiqer tank. DECOMP Resume pump down tubing up the IA through the choke to the Tiger tank at 3 BPM / 800-940 psi with very little to No Oil or seawater in returns. Pumped a total of 510 bbls seawater and recovered 185 bbls Crude and lost 301 bbls. 60 % loss rate . IA on a sliaht blow. Tubina on a vacuum. U-Tube for 15 DECOMP from above and attem t to in'ection from below, pumped 65 bbls seawater at 4 BPM and did not catch fluid, charted for 10 minutes. DECOMP RD kill manifold, kill lines and valve. DECOMP Cameron well head tech check alignment pin and function LDS - 2-3/4" in, 3-3/4" out. Function alignment pin - 1" in, 1-3/4" out. ND tree and PU/MU landing joint and mark RKB. 8 turns to make-up hangerthreads. DECOMP NU DSA to wellhead. NU BOPE. Feed IA with LRS at 20 BPH with seawater. DECOMP Function test BOPE. DECOMP Test BOPE 250 si low / 3 500 si hi h. Hold each test for a charted 5 min. Test 2-7/8" x 5" VBR with 2-7/8" test joint against the TWC. Test annular with 2-7/8" test joint. Complete Koomey draw down test. Test witnessed by WSLs Dave Rhodes and Matt Martyn and NAD Tourpusher Rick Bjorhus. Printed: 6/29/2009 3:04:02 PM • • BP EXPLORATIDN Page 2 ofi 4. ' Operations Summary R~port _ Legal Well Name: MPL-05 ICommon Well Name: MPL-05 Spud Date: 4/10/1990 ' Event Name: WORKOVER Start: 6/15/2009 End: 6/23/2009 ~~~Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/20/2009 ', Rig Name: NABORS 3S Rig Number: , Date From - To Haurs Task Code NPT Phase ' Deseriptian of Operations 6/17/2009 16:00 - 20:00 4.00 BOPSU P DECOMP AOGCC rep Bob Noble waived the state's right to witness at 14:50 hrs on 6-17-09. Blow down equipment. LD test joint. Mnnitnr IA rlurinn toct - IA nn Var. Cnntinua tn fill hnla with 20:00 - 21:00 1.00 BOPSU P DECOMP RU Opso-Lopso, lo-torque and lubricator. Test with diesel to 500 si. Lubricate out TWC, tubing on vac. LD Opso-Lopso and lubricator. 21:00 - 22:00 1.00 PULL P DECOMP MU landing joint with closed TIW valve and screw into tubing hanger with 8 turns. Monitor IA thru 2" - IA on vac. BOLDS with Cameron rep. Pull hanger off seat with 85K. Hanger to floor with 80K. Pull penetrator with Cameron and disconnect ESP cable with Centrilift. LD hanger for inspection. 22:00 - 23:00 1.00 PULL P DECOMP MU landing joint to string. Secure ESP cable to tubin . RIH on more oints of 2-7 8" tubin to 10 156' md, PU - 87k, SO - 40k. No fill encountered. 23:00 - 00:00 1.00 PULL P DECOMP MU headpin and circulate 65 bbls 8.45 ppg seawater down tubing back to pits at 3 BPM / 570 psi. Slight oil returns came to surface at 50 bbls awa . 6/18/2009 00:00 - 01:30 1.50 PULL P DECOMP PJSM. POOH laying down excess singles of 2-7/8" tubing from 10,156' to 9,745'. Regulate hole fill at 20 bbls per hour with seawater while POOH. 01:30 - 02:30 1.00 PULL P DECOMP RU to spool ESP cable. 02:30 - 04:00 1.50 PULL P DECOMP POH rackin back 26 stands of 2-7/8" tubin to 8,133' md. 04:00 - 05:00 1.00 PULL P DECOMP Change ou4 E8P cable spool. 05:00 - 06:00 1.00 PULL P DECOMP POH racking back 2-7/8" tubing to -7,510 - 36 stands total racked back. RU to circulate. 06:00 - 07:00 1.00 PULL P DECOMP Pum 90 bbls seawater down tubin at 4 BPM and got returns to service, circulate Oil cap off till clean seawater returns. Lost 105 bbis. Tubing and IA on a vacuum. 07:00 - 09:00 2.00 PULL P DECOMP Resume POH with ESP assembly on 2-7/8" tubing and rack in Derrick. Maintain continuous feed rate at 20 BPH. From 7,510' to 6,350'. 09:00 - 10:00 1.00 PULL P DECOMP Centrilift rep made conductivity check at old cable splice. Cable on surface passed, cable below surface failed. 10:00 - 11:00 1.00 PULL P DECOMP Resume POH from joint #108 to joint # 180. 11:00 - 12:00 1.00 PULL P DECOMP Centrilift rep made conductivity check at old cable splice. Cable on surface passed, cable below surface failed. 12:00 - 16:00 4.00 PULL P DECOMP Resume POH from joint #180 to joint # 304. Tight connects joint -136,140-304. UD 3 bad joints 2-7/8" tubing. Pulled 304 joints of tubing, 2 GLMs, 1 XN, 159 LaSalle clamps, 6 protectilizers, 3 flat guards, 2 steel bands. Maintained 20 BPH hole fill while POH. 16:00 - 20:00 4.00 PULL P DECOMP BO / LD ESP pump and motor assembly. Short in last section o cable, exact ocation yet to be determined. No obvious signs o pro ems wit pump or motor assem y. assembly as per Centrilift rep. Wrap ends of components and set in boxes. 20:00 - 21:00 1.00 PULL P DECOMP Clean and clear rig floor. LD double stack tongs. RU tools and equipment to RIH. Put spool of experienced wire in spooler. RD Elephant trunk. 21:00 - 22:00 1.00 RUNCO P RUNCMP PUMU landing joint and tubing hanger. Function alignment pin into position with CIW tech. Land hanger in bowl and visualiy Printed: 6/29/2009 3:04:02 PM • i BP EX Qperations Legal Well Name: MPL-05 Common Well Name: MPL-05 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S i i i i i i ~ va~c n~iti - i v nttu~~ i e~~ 6/18/2009 21:00 - 22:00 1.00 RUN 22:00 - 23:00 1.00 RUN 23:00 - 00:00 1.00 RUN 6/19/2009 00:00 - 06:00 6.00 RUN 06:00 - 13:30 I 7.501 RU 13:30 - 17:30 4.00 RU 17:30 - 19:30 2.00 RU 19:30 - 20:30 1.00 20:30 - 22:00 1.50 22:00 - 23:00 1.00 23:00 - 00:00 I 1.00 I WHSUR ~ P 6/20/2009 I 00:00 - 00:30 I 0.501 WHSUR I P 00:30 - 06:00 I 5.50 06:00 - 17:00 I 11.00 17:00 - 19:00 I 2.001 WHSUR I P 19:00 - 21:00 I 2.00 'LORATION ~'~ ~ummary Report Spud Date: 4/10/1990 Start: 6/15/2009 End: 6/23/2009 Rig Release: 6/20/2009 Rig Number: Phase , Deseription of Operations RUNCMP confirm hanger "J" into positon and land. LD hanger and landing joint. RUNCMP PU and break out connections on crossovers from test joints as needed for Rig stack out. RUNCMP PUMU new ESP Assembl with Centrilift re . Maintain hole fill re ulated at 20 bbls er hour with seawater. RUNCMP Continue to PUMU new ESP Assembly with Centrilift rep. Maintain hole fill regulated at 20 bbls per hour with seawater. Wells group redressed GLMs with new valves. RUNCMP RIH with new ESP Assembly on 2-7/8" Tubinq from the Derrick. Maintain hole fill at 20 bbls per hour with seawater. Utilizing Best-O-Life 2000 Pipe Dope on all connections and making up to a torque of 2,300 ft-Ibs. Fill and flush pump with 10 bbls seawater at 1/2 BPM / 1180 psi. RUNCMP Centrilift rep perform reel to reel cable splice at joint #238. Wells group SIM-OPS to spot Well house on MPL-11. RUNCMP RIH with remaining 2-7/8" tubing joints 238 - 304 from derrick. Continue hole fill at 20 BPH. Place clamps on every other joint. MU torque 2,300 ft-Ibs. Use Best-O-Life pipe dope. MU headpin, final flush on pump at 0.5 BPM / 1,200 psi. Ran a total of 304 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing. Ran two GLMs with the deepest having a DGLV and the shallow one having a DSOV. Ran 159 LaSalle Clamps, 5 Protectolizers, 3 Flat Guards and 2 Bands to secure the tech wire on the WeIILift installation. RUNCMP PU Landing Joint and Hanger. Obtain final PUW = 82K , SOW = 43K. Verify orientation of Hanger. Install Penetrator. RUNCMP Perform Penetrator splice with Centrilift rep. Increase fill rate until returns seen at surface. Loss rate at -60-70 b h. RUNCMP Land Tubing Hanger and RiLDS with Cameron rep. Lay down Landing Joint. RUNCMP PU T-bar and set 2-1/2" T e"H" TWC with Cameron rep. Pressure test from above to 3 500 si for 10 charted mins - OK. Line up to test from below. RUNCMP Line up and pressure test 2-1/2" Type "H" TWC with Cameron reo. from below bv oumoina down the IA at 2.5 bnm / 550 psi i~i I V IIIII IJ ' Vf~. IA NVR O~ UUIJ JCQW2iLC1 ~~ iui n~i iu catching fluid. RUNCMP Clean Pits, Fill w/ heated freshwater, Flush all mudlines, kill line, choke manifold, mud manifold, gun line, hopper etc. Flush out stack. Blow down lines. RUNCMP Remove VBR and Blind rams from BOP stack. ND Dutch system, DSA and BOPE stack. LD BOP stack in shipping cradle. Prep BOPE for final ND prior to Rig stack out. RUNCMP NU Adapter Flange and Tree with Cameron rep. Pressure test the Hanger void to 5,000 psi for 30 minutes. Test tree w/ diesel to 5000 psi on chart for 5 min. 100 psi) and install BPV. RD lubricator. Remove valve. Centrilift make final checks and secure cellar. Release Rig to standby on road repairs ~ 2100 hrs Printed: 6/29/2009 3:04:02 PM . ~ # BP EXPLORATf~N ' Page 4 of 4 Operations Summary Report Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 6/15/2009 End: 6/23/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/20/2009 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Cod~ NPT Phase Deseription vf Opera#ions 6/20/2009 21:00 - 00:00 3.00 RIGD P RUNCMP Scope and UD Derrick. R/D for move to edge of pad. Break apart pipe shed module from carrier. 6/2112009 00:00 - 04:00 4.00 RIGD P OTHCMP Move Carrier Module, Pipeshed Module and Pit Module to edge 04:00 - 06:00 2.00 RIGD P 06:00 - 00:00 18.00 RIGD P 16/22/2009 100:00 - 06:00 I 6.001 RIGD I P 06:00 - 17:00 11.00 RIGD P 17:00 - 19:00 2.00 RIGD P 19:00 - 22:00 3.00 RIGD P 22:00 - 00:00 2.00 RIGD P 6/23/2009 00:00 - 13:00 13.00 DEMOB P of pad. Spot on Herculite. MU modules to Carrier. Berm Herculite. OTHCMP Raise derrick & telescope up (for use of manriders and tugger). Connect lines. Resume demobilizatiQn activities. OTHCMP Wait on electrical tie in to MPF-Pad under Spine road. Break apart BOP stack for Rig stack-out. Power wash exterior wind wall, remove BP tools from Rig. Disconnect Epoch system. Stage environmental waste in Pipe shed for inspection by MPU Environmental Dept. Remove work over tools from Rig floor. Remove cameras and monitors. Load out tools and pipe bunks OTHCMP Continue to clean rig and work through pre-stackout procedure and checklists while waiting on road and rig move prep to be complete. OTHCMP Clean Rig and work to manage Enviromental's removal of SAA / RAA / UAA with MPU Enviro-Tech. OTHCMP Lay down derrick, disconnect lines, split about modules, prep for trucking arrival. Release Riq from standby with full crews at 1800 hrs on 6/22/2009 and prepare for mobilization to stack the Ri on Frontier Pad in Deadhorse. OTHCMP Load modules to trucks and prepare to move. OTHCMP Move rig from MPL Pad to Milne Point Operations center. POST Continue moving the Rig and all associated Modules from Milne Point to Nabors Frontier Pad in Deadhorse. At 0900 hrs, drop off the Camp and Generator Module on J-Pad adjacent to Nabors 4ES in preparation for camp swap. Continue on to Nabors Frontier Pad in Deadhorse with the rest of the Rig Modules. Arrive at Frontier Pad at 1300 hrs and prepare the Rip and Modules for stack out. Printed: 6/29/2009 3:04:02 PM STATE OF ALASKA osrosros OIL AND GAS CONSERVATION COMMISSION BODE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 6117/09 Rig Rep.: G.Sweatt/R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: D.Rhodes/M.Martyn E-Mail adwdr3snu b .com Well Name: MPL-05 PTD # 1900390 Operation: Drlg: Workover. x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular. 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Sall Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" P Pit Level Indicators P P #1 Rams 1 2 718 x 5" P Flow indicator P P #2 Rams 1 blind P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc NA NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8 P Inside Reel valves 0 NA HCR Valves 2 3 1/8 2 1/16 P Kill Line Valves 1 2 1116 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1650 P Quantity Test Result 200 psi Attained 28 P No. Valves 13 P Full Pressure Attained 150 P Manual Chokes 1 NT Blind Switch Covers: All stations Yes Hydraulic Chokes 1 NT Nitgn. Bottles (avg): 2000 i CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 3.0 Hours Repair or replacement of equipment will be made within days. Notify the North Slope Ins ector 659-3607, follow with written confirmation to Su ervisor at: Remarks: Tested with 2 7/8" test joint against TWC. Witnessed by Dave Rhodes Bp WSL, Rick Bjorhus NAD TP 24 HOUR NOTICE GIVEN YES x NO Waived By Bob Noble Date 6/16/09 Time 06:00 Witness Test start 16:00 Finish 19:00 ~~ ~'~ BOP 06/05/09 Nabors 3s BOP Test MPL-05 6-17-09.x1s STATE OF ALASKA ALA OIL AND GAS CONSERVATION C011~SION REPORT OF SUNDRY WELL OPERATIONS DEB 1 2 2D09 Alaska Oil & Gas Cons. Commissiarl 1. Operations Performed: ttG Ora$8 ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing, ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 190-039 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22030-00-00 7. KB Elevation (ft): 56, l 9. Well Name and Number: MPL-05 8. Property Designation: 10. Field /Pool(s): ADL 025509 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 10550' ~ feet true vertical 7596' ~ feet Plugs (measured) None Effective depth: measured 10441' feet Junk (measured) None true vertical 7529' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' 1740 750 Surface Intermediate 6044' 9-5/8" 6044' 4676' 3520 2020 Production 10528' 7" 10528' 7582' 7240 5410 Liner ~' ~- FHB ~ 2009 Perforation Depth MD (ft): 9808' - 10098' Perforation Depth TVD (ft): 7136' - 7317' 2-7/8", 6.5# L-80 9749' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 358 324 176 240 219 Subsequent to operation: 193 174 276 220 232 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oii ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17..1 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 Howard West, 564-5471 N/q Printed Name T rrie Hubble Title Drilling Technologist Prepared By Name/Number' ~Z Signature Phone 564-4628 Date ~ Terrie Hubble 564-4628 ~' ~ ~ Form 10-404 Revised 04!2006 Subm'~~ ly ~. • • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 1/9/2009 End: 1/17/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/17/2009 Rig Name: NABOBS 3S Rig Number: ' I Code' NPT Phase Description of Operations Date ~ From - To Hours Task ~~ _ _ _ __ 1/12/2009 06:00 - 13:00 7.00 RIGD P PRE The ambient temperature is warm enough to begin rig down operations. At 0600, ambient temp = -30 degF. Scope and lower the Derrick at 0700 hrs. Disconnect all Modules and prepare for trucks. Lower the Carrier on its wheels at 1030 hrs. Pull off of well slot MPK-05 at 1245 hrs with the Pad Operator and Toolpusher present. 13:00 - 17:00 4.00 RIGD N WAIT PRE All Rig Modules ready for mobilization to MPL-Pad. Milne Point fuel truck is broken down on the MPK-Pad Access Road. It broke down at 0130 hrs and it is still not out of the way. Wait to mobilize the Rig Modules until they move the fuel truck out of the way due to Rig Modules being wide impassable loads. 17:00 - 19:00 2.00 MOB P PRE Move Rig and Camp from MPK-05 to MPL-05. 19:00 - 00:00 5.00 MOB P PRE Spot Camp units and lay mats. Line up Carrier to Well. 1/13/2009 00:00 - 00:30 0.50 MOB P PRE Spot Carrier over Well MPL-05, witnessed by Pad operator and BP / WSL. 00:30 - 03:30 3.00 MOB P PRE Spot Pipe Shed and Pits. Raise Derrick and scope up. 03:30 - 07:00 3.50 RIGU P PRE Rig up Steam, lines and Rig floor. Accepted Rig at 07:00 hours on 1/13/2009. 07:00 - 10:00 3.00 KILL P DECOMP R/U kill manifold and hook up hard line to Tiger Tank and Choke. Install second annulus valve. Take on 140 degF seawater to the Pits and Upright Tank. 10:00 - 11:00 1.00 KILL P DECOMP Pressure test surface lines to 3,000 psi and downstream hardline to the Tiger Tank to 500 psi. Push steam through the line. Blow down lines. 11:00 - 13:00 2.00 WHSUR P DECOMP PU / MU Lubricator and test with diesel to 500 psi. Well su ort tech ull BPV. WHPs: Tubin = 250 si IA = 6 si OA = 0 psi. LD Lubricator. 13:00 - 13:30 0.50 KILL P DECOMP Hold pre-kill safety meeting with the crew. 13:30 - 17:30 4.00 KILL P DECOMP Open the well to a closed Choke and note pressures: Tubing = 250 psi , IA = 670 psi. Bleed the IA down to 30 psi. Bleed the Tubing down to 0 psi. Break circulation with 140 degF, 8.5 ppg seawater down the Tubing taking returns up the IA through the Choke out to the Tiger Tank. Pump 65 bbls without returns at a rate of 3 bpm / 40 psi on the Tubing and 0 psi on the IA. Close the Choke and bullhead 45 bbls down the Tubing at a rate of 3 bpm / 30 psi on the Tubing with final pressure on the IA of 50 psi. Zero bbls pumped. Open the Choke and resume circulating the long way at a rate of 3 bpm. Returns on surface observed after 40 bbls um ed. Continue circulating at a rate of 3 bpm with final pressures on the Tubing of 580 psi and 20 psi on the IA. Clean seawater returns observed on surface and weight of returns = 8.5 ppg. Pumped a total of 515 bbls to achieve clean returns. Strap the Tiger Tank and total returns on surface 303 bbls (approx 60% returns). 17:30 - 18:00 0.50 KILL P DECOMP Shut down the Pump and monitor the well for 30 minutes. Both the Tubing and IA are on a vacuum. 18:00 - 18:30 0.50 WHSUR P DECOMP Crew change. Check PVTs, pre-tour checks. 18:30 - 20:00 1.50 WHSUR P DECOMP D rod TWC with Cameron technician. Com lete rollin test from below TWC to 100 si for 10 min -charted. Test from above TWC to 3500 psi for 10 min -charted 20:00 - 23:00 3.00 WHSUR P DECOMP PJSM. ND tree and adapter flange and secure in cellar. RU LRS to IA and ravit feed Burin ND at 20 BPH IA on vac. Changeout LDS packing in gland nuts. Check hanger threads, Printed: 1/26/2009 11:05:09 AM • BP EXPLORATION Operations Summary Report Page 2 of 4 ~ Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 1/9/2009 End: 1/17/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/17/2009 Rig Name: NABOBS 3S Rig Number: Date !From - To Hours Task .Code NPT Phase Description of Operations 1/13/2009 20:00 - 23:00 3.00 WHSUR P DECOMP good with 8 turns. 23:00 - 00:00 1.00 BOPSU P DECOMP PJSM. NU BOPE. 1/14/2009 00:00 - 03:00 3.00 BOPSU P DECOMP Continue NU BOPE. 03:00 - 07:30 4.50 BOPSU P DECOMP Test BOPE 250 psi low / 3500 psi high for 5 charted min each. 07:30 - 09:00 1.50 BOPSU P DECOMP 09:00 - 10:30 1.50 PULL P DECOMP 10:30 - 13:00 2.50 PULL P DECOMP 13:00 - 14:00 1.00 WHSUR P DECOMP 14:00 - 15:30 1.50 PULL P DECOMP 15:30 - 19:30 4.00 PULL P DECOMP Test 2-7/8" x 5" VBR with 2-7/8" test joint. Test witnessed by NAD Toolpusher and BP WSL. AOGCC rep John Crisp waived state witness at 19:25 hrs on 1-13-09. Blow down and rig down all test equipment. Lay down the 2-7/8" Test Joint. Drain the BOP Stack. RU the Elephant Trunk and containment. PU Opso Lopso and break off the 3" L.H. Acme XO. MU the 2-7/8" EUE 8rd XO. LD Opso Lopso. Clear and clean under the Pipe Racks. Wait on WSL to return to location after meeting with ADW Management in Deadhorse was cancelled. PU Opso Lopso and Pump-In Sub and screw into the Hanger. PUMU Lubricator and Polished Rod. Test to 500 psi - OK. Pull 2-1/2" Type "H" TWC with Well Support Techg. Confirm the Tubing is on a vacuum. Check the IA and it is on a vacuum. Lay down Lubricator and Opso Lopso. PUMU 2-7/8" Landing Joint to the Hanger. MU Headpin and circulating hose. BOLDS with Cameron rep. Check the IA prior to pulling and it is on a vacuum. Pull the Hanger off seat with PUW = 90K and pull to the Floor with PUW = 85K. Break circulation down the Tubing to CBU. Catch fluid after 15 bbls awav (-2.585'). Pumping at a rate of 4 bpm / 510 psi. 5 min loss rate of 6 bbls = 60% returns. Light crude and slight gas observed in initial returns but cleaned up shortly thereafter. Circulated 581 bbls total with average loss rate of 53 bbl/hr during circulation. RD circulation equipment and blow down lines. Monitored the well for 15 minutes -visibly see fluid level dro in .The well is on a vacuum. 19:30 - 20:00 0.50 PULL P DECOMP PJSM. PU singles from shed and RIH with 10 jts to 10,070' with out tagging. Shut down tripping and stab valve, door hinge on Blind ram leakin h draulic oil due to failure in hin a seal. Isolate spill area and bleed and disconnect hydraulic hose to Blind ram. Make all appropriate calls. 20:00 - 21:00 1.00 PULL P DECOMP POH above perfs at 9789'. LD joints in pipe shed. Stab valve and continue to fill hole with charge pump at 20 BPH. 21:00 - 23:00 2.00 PULL N SFAL DECOMP Milne Pt. environmental tech on location. Inspect area and clean hydraulic oil as per ACS technician. All fluid was contained in cellar area and secondary containment. 23:00 - 00:00 1.00 PULL N SFAL DECOMP Rig Mechanic on location. Conduct PJSM and identity leak point. Pull pistons out of hinge and found blown o-ring and flattened o-ring,, 1/15/2009 00:00- 02:00 2.00 PULL N SFAL DECOMP Replace failed o-rings and reassemble pistons in hinge. Hook lines back up to Blind ram and pressure test connectiop - no leaks. Maintain hole fill at 20 BPH. 02:00 - 04:00 2.00 PULL P DECOMP PJSM. Single in hole from shed to tag depth of 10,359' (261' of rathole). Tagged several times to confim depth. LD singles to tag. 04:00 - 09:00 5.00 PULL P DECOMP PJSM. LD 10' pup and secure ESP tail. POOH with 2-7/8" Printed: 1/26/2009 11:05:09 AM • • BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 1/9/2009 End: 1/17/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/17/2009 Rig Name: NABOBS 3S Rig Number: Date From - To 'Hours Task I Code' NPT j Phase Description of Operations 1/15/2009 04:00 - 09:00 5.00 PULL P DECOMP tubing. Regulate hole fill at 20 bbls per hour with seawater while POOH. 09:00 - 14:00 5.00 PULL N WAIT DECOMP Stop with 48 stands in the Derrick. Floorhand had his left ring finger cut while working the manual tongs on the Pipe -see remarks section for details. Shut operations down and hold stand down with HSE Drilling Adviser, ADW Operations Superintendent, Nabors Superintendent, Nabors Safety, WSL, Toolpusher and Crew. Discuss the incident and plan forward to resume operations. 14:00 - 16:00 2.00 PULL P DECOMP RD 4-1/2" single Eckels power tongs and lay down in the Pipe Shed. PU and RU 4-1/2" double Eckels power tongs with Nabors Casing rep. 16:00 - 00:00 8.00 PULL P DECOMP Resume POOH with existing ESP Completion standing back 2-7/8" Tubin in the Derrick. Regulate hole fill at 20 bbls per hour with seawater while POOH. Have Nabors Casing rep observe for one hour to ensure proper operation - OK. Centrilift changeout ESP spools at 20:00 hrs. 135 stands pulled at 24:00 hrs. 1/16/2009 00:00 - 02:00 2.00 PULL P DECOMP Continue to POH with 2-7/8" tubing. Pulled 305 joints of tubing, 2 GLMs, 1 XN, 160 LaSalle clamps, 5 protectilizers, 3 flat guards. Maintained 20 BPH hole fill while POH. 02:00 - 04:30 2.50 PULL P DECOMP LD ESP assembly as per Centrilift rep. Wrap ends of components and set in boxes. 04:30 - 06:30 2.00 PULL P DECOMP Clean and clear rig floor. LD double stack tongs. RU tools and equipment to RIH. Put spool of experienced wire in spooler. RD Elephant trunk. Wells group redressed GLMs with new valves. 06:30 - 12:00 5.50 BUNCO RUNCMP PUMU new ESP Assembly with Centrilift rep. Maintain hole fill regulated at 20 bbls per hour with seawater. 12:00 - 14:00 2.00 BUNCO RUNCMP Pre-tour checks with incoming crew. First day back so take the time to check out all equipment and the rig as a whole. Service the Rig. Centrilift rep had to go back to the Centrilift Shop for proper flat guards. 14:00 - 00:00 10.00 BUNCO RUNCMP RIH with new ESP Assembl on 2-7/8" Tubin from the Derrick. Maintain hole fill at 20 bbls per hour with seawater. Stop every 2,000 ft to check the conductivity of the ESP Cable. Fill the Tubing and flush the pump with 10 bbls of seawater at a rate of 0.5 bpm / 625 psi. Utilizing Best-O-Life 2000 Pipe Dope on all connections and making up to a torque of 2,300 ft-Ibs. 128 stands in the hole at 24:00 hrs. Flushed pump with 10 bbls at 0.5 BPM / 950 psi. 1/17/2009 00:00 - 00:30 0.50 BUNCO RUNCMP Continue RIH with 2-7/8" tubing. 00:30 - 03:30 3.00 BUNCO RUNCMP Make field splice on .ESP cable with Centralift hand. Maintain hole fill at 20 BPH. 03:30 - 06:00 2.50 BUNCO RUNCMP RIH with remaining 2-7/8" tubing from derrick. Continue hole fill at 20 BPH. Place clamps on every other joint. MU torque 2,300 ft-Ibs. Use Best-O-Life pipe dope. MU headpin, final flush on pump at 0.5 BPM / 1,100 psi. Ran a total of 304 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing. Ran two GLMs with the deepest having a DGLV and the shallow one having a DSOV. Changed out the XN Nipple to a new one with an ID = 2.250". Ran 159 LaSalle Clamps, 6 Protectolizers, 3 Flat Guards and 2 Bands to secure the tech wire on the WeIILift installation. Printed: 1/26/2009 11:05:09 AM • BP EXPLORATION Operations Summary Report __ Pressure test from above to 3,500 si for 10 charted mins - OK. Line ua to test from below. Pressure test from below by pumping down the IA at 4 bpm / 110 psi (friction) for 10 mins - OK. 11:30 - 12:00 0.50 WHSUR P RUNCMP Blow down lines and RD test equipment. 12:00 - 16:30 4.50 BOPSU P RUNCMP Drain the Stack. ND 13-5/8" BOPE and 11" x 13-5/8" DSA. 16:30 - 18:30 2.00 WHSUR P RUNCMP NU Adapter Flange and Tree with Cameron rep. Pressure test the Hanger void to 5,000 psi for 30 minutes. Test tree to 5000 psi on chart for 5 min. 18:30 - 20:00 1.50 WHSUR P RUNCMP RU lubricator and test to 500 psi with diesel. Pull TWC and install BPV. RD lubricator. 20:00 - 21:00 1.00 WHSUR P RUNCMP Norm up tree and wellhead. Centrilift make final checks and secure cellar. Pressure at intake = 2,474 psi ,Pressure at discharge = 2,452 psi ,Temperature at intake = 159 degF , Temperature at motor = 158 degF ,Phase to phase = 4.2 Ohms ,Phase to ground = 700 Mega Ohms. "'Rig released at 21:00 hrs on 1-17-09"' Page 4 of 4 ~ Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 1/9/2009 End: 1/17/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/17/2009 Rig Name: NABOBS 3S Rig Number: Date From - To 'Hours Task Code NPT Phase ~ Description of Operations 1/17/2009 06:00 - 07:00 1.00 BUNCO RUNCMP PU Landing Joint and Hanger with Cameron wellhead rep. Verify orientation of Hanger. Install Penetrator. 07:00 - 08:30 1.50 BUNCO RUNCMP Perform Penetrator splice with Centrilift rep. Continue feeding the well with 20 bbls per hour with seawater. 08:30 - 09:30 1.00 BUNCO RUNCMP Obtain final PUW = 82K ,SOW = 43K. Land Tubing Hanger and RILDS with Cameron re .Lay down Landing Joini. 09:30 - 11:30 2.00 WHSUR P RUNCMP PU T-bar and set 2-1/2" Type "H" TWC with Cameron rep. Printed: 1/26/2009 11:05:09 AM Tree: 2 9/16" - 5M WKM M P L 0 5 Wellhead: 11" x 11" SM ~ ~ w/ 11" x 2 7/8" WKM tbg. hng.,- 8rd EUE threads top and bottom, Z.5" CIW H BPV profile KOP @ 500' Max. hole angle = 47 to 52 deg. from 2800' to TD Hole angle through perforations = 51 deg. 9 5/8", 36 ppf, J-55 Btrs. 6,044' and , 2 7/8" 6.5# EUE 8RD, L-80 Tbg. Drift ID: 2.441" Capacity: 0.00579 BBL/FT 7", 26 ppf, L-80, Btrs. (cap. = 0.0383 bpf, ID = 6.276") ~ PERFORATION SUMMARY REF: LOG: SWS CBT 05/02/96 Size SPF Interval (TVD) 4.5" 5 9808'-9913' (7137'-7202') 4.5" 5 9949'-9964' (7226'-7234') 4.5" 5 9980'-9999' (7243'-7256') 4.5" 5 10024'-10098' (7272'-7318') 4.5" Guns W/ Hyperjet II 5 JSPF & 72 Deg. Phasing EHD = 0.49" TTP= 30.25" Orig. KB EI~56.0' (N 27E) Orig. GL EI 21.0' KB To 7" csg. hng. = 34' (N 27E) Camco 2 7/8" x 1" sidepocket KBMM GLM 138' Camco 2 7/S" x 1" sidepocket KBMM GLM 9516` HES 2.313" XN Nipple 9658` (Novo ID 2.250") WeIILift Discharge Gauge 9671 ` Tandem Pumps: 127-P8, 127-P8, 9677` 18-P75 SXD Gas Separator, model - ` GRSFTXARH6 9713 Intake @ 7076' TVD Tandem Seal Sections 9718 GSB3DB UT/LT SB/SB PFSA Motor, 152 HP, 2325 volt, 9731 ` 40 amp -model KMH WeIILift Intake Gauge w/6 fln 9745` centralizer Gauge @ 7097' TVD Mid-pert TVD - 7227` Mid-pert MD - 9953' PBTD TVD - 7566' RWO t-ill tag 1/14/09 10,349' and 7" float collar (PBTD) 10,441' and 7" casing shoe 10,528' and MILNE POINT UNIT WELL L-05 API NO: 50-029-22030 DATE REV. BY COMMENTS 10/27/90 Cased hole 8 ESP Completion 27E 7/25/94 8/04/97 MDO/JBF ESP re-completion ESP re-completion b Nabors 4ES 4/11/01 1/02/03 GMH M. Linder ESP RWO Nabors 4ES ESP changeout 1/16/09 L. Hulme ESP C/O and TD tag -Nabors 3S BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3224' NSL, 4860' WEL, SEC. 08, T13N, R10E, UM X= 545022, Y= 6031415 MPL-05 9. Permit Number/ Approval No. At top of productive interval *~i .~ 190-039 4083' NSL, 805' EWL, SEC. 05, T13N, R10E, UM x = 545348, Y = 6037555 10. APl Number At effective depth ~- t 50-029-22030-00 4581' NSL, 829' EWL, SEC. 05, T13N, R10E, UM x= 6463~s,Y=603~o64 11. Field and Pool At total depth Kuparuk River Field 4649' NSL, 831' EWL, SEC. 05, T13N, R10E, UM X=545369, Y=6038121 12. Present well condition summary Total depth: measured 10526 feet Plugs (measured) true vertical 7581 feet Effective depth: measured 10441 feet Junk (measured) true vertical 7529 feet Casing Length Size Cemented MD TVD Structural Conductor 82' 13 3/8" 485 sx PF 'C' 115' 115' Surface 6011' 9 5/8" 1510 cuft 'G', 1510 cu ft AS IV 6044' 4676' Intermediate Production 10493' 7" 398 cu ft Class 'G' 10528' 7582' Liner Perforation depth: measured 9809' - 9913', 9949' - 9964', 9980' - 9999', 10024' - 10098' true verfical 7136 '-7203', 7225 '-7234', 7244'- 7256', 7272'- 7318' ~E C, ~ ~ ~'~~~ ~ ~D Tubing (size, grade, and measbred depth) 2 7/8" 6.5# L-80 8RD EUE tubing to 9764' .. !/..!,.~ ~.; ~v~.-' Packers and SSSV (type and measured depth) None ~8.$~,8. 0ii {.~- '~.~.s ~0~ A~cho~e- 13. Stimulation or cement squeeze summary Intervals treated (measured) , C NNED FEB 0 2003 Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I here~~~~orrect to the best of m~ knowledge Si.qne~dr~ S~t~ew~~, ~'~.~Y'.~~ ~ Title Technical Assistant Date O ~- ~"7 ~{~)5 Prepared By Name/Number: $ondra Stewman, 564-4750 Submit In Duplicate Form10-404 Rev. 06/15/88 ~B[~S BFL .... BP EXPLOF~,TtON Page 1 of 2 Operations Summary Report Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 1/2/2003 End: 1/4/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/4/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/1/2003 22:00 - 00:00 2.00 MOB P PRE PJSM. SCOPE DOWN & LAY OVER DERRICK. 1/2/2003 00:00 - 03'00 3.00 MOB P PRE PJSM. MOVE RIG F/MPC-2' TO MPL-05. 03:00 - 07:00 4.00 MOB P PRE SPOT SUB & MUD PITS, PIPESHED. RAISE & SCOPE UP DERRICK. GO SLOWLY DUE TO CLOSE QUARTERS. RIG ACCEPTERD @ 07'00 HRS 01/02/03. 07:00 - 08:30 1.50 MOB !P PRE SPOT TIGER TANK & RIG UP HARDLINE. PT SAME TO 3500 PSI, OK. 08:30 - 09:30 1.00 KILL P DECOMP PJSM. P/U LUBRICATOR & PULL BPV. 09:30 - 10:00 0.50 KILL P DECOMP TEST HARD LINES TO 3500 PSI, OK. PJSM W/CO MAN & TP, WELL KILL OPERATIONS. 10:00 - 14:00 4.00 KILL P DECOMP INITIAL SITP = 740 PSI, SlAP = 650 PSI BULLHEAD 15 BBLS DOWN TUBING & CIRCULATE WELL @ 5 BPM, 1550 PSI TO CLEAN RETURNS. HOLE TAKING APPROX 10-15 BPH W/CIRCULATING. 14:00-14:30 0.50 WHSUB P DECOMP SET 2 WAY CHECK VALVE 14:30 - 15:30 1 00 WHSUB P DECOMP N/D TREE. 15:30- 17:00 1.50 BOPSUF P DECOMP N/U BOPE. 17:00 - 18:30 1.50 BOPSUF P DECOMP CONDUCT BODY & FLANGE TEST ON 13 5~8" x 5M BOPE. AOGCC STATE MAN JOHN SPAULDING WAIVED WITNESSING THE TEST. 7 "x 2 7/8" ANNULUS FLOWING @ 1 GPM. 18 30 - 20:30 2.00 KILL P DECOMP BRING UP BRINE WEIGHT TO 8.6-8.7 PPG & CIRCULATE @ 4-5 BPM / 1500 PSI. LOSS RATE 15-30 BPH W/ CIRCULATING. 20:30 - 21:30 I 00 PULL P DECOMP WELL STABLE, PJSM. BOLDS & PULL HANGER TO FLOOR, 75K UP WT TUBING NOT DRAINING, (HEAVY ON BACKSIDE). 21:30 - 22:30 1.00 PULL P DECOMP CIRCULATE @ 5 BPM / 1500 PSI. CIRC OUT HEAVY SPOT IN BRINE, 8.7 PPG IN, 8.6+ PPG OUT SHUT DOWN & MONITOR, WELL STABLE. 22:30 - 00:00 1.50 PULL P DECOMP PJSM. POOH W/2 7/8" TBG, (STANDING BACK), & SPOOLING UP ESP CABLE. 1/3/2003 00:00 - 06:00 6.00 PULL P DECOMP CONTINUE TO POOH W/2 7/8" EUE TBG. & ESP CABLE. BREAK DOWN PUMP STAGES & L/D SAME. CALCULATED HOLE FILL 23 BBLS, ACTUAL HOLE FILL 32 BBLS, WELL STABLE. 06:00 ~ 07:00 1.00 RUNCOI~ !:) COMP CIO ESP REELS. LOAD NEW PUMP IN PIPESHED. 07:00 - 10'00 3.00 RUNCOr~ ~ COMP P/U & SERVICE NEW ESP CABLE. PLUG IN & TEST, OK. 10:00 - 15:00 5.00 RUNCOI~ I:) COMP M/U PUMP & RIH W/ESP CABLE & 2 7/8" EUE TBG, TORQUING EACH CONNNECTION TO 2100 FT/LBS. CIRCULATE PUMP EVERY 2000' @ 1.5 BPM / 1500 PSI. 15:00 - 18.00 3.00 RUNCOI~P COMP MAKE REEL TO REEL SPLICE. 18:00 - 19'00 1.00 RUNCOI~P COMP CONTINUE IN HOLE W/2 7~8" TBG & ESP CABLE 19:00 - 19:30 0 50 RUNCOr~I~ COMP PICK UP TUBING HANGER & M/U LANDING JOINT, 74K UP WT, 46K DOWN. RAN (160) LASALLE CLAMPS, (3) FLAT GUARDS, & (5) PROTECTALIZERS 19.30 - 21:30 2.00 RUNCOI~ P COMP INSTALL PENETRATOR IN HANGER, CUT ESP CABLE & ATTACH FIELD CONNECTION. TEST CONNECTION, OK. 21:30 - 22:00 0.50 RUNCOI~ P COMP DRAIN STACK, ENSURE LOCK DOWNS ARE OUT, LAND TBG HANGER. SET & TEST 2 WAY CHECK. 22'00 - 23:30 1.50 WHSUR P COMP N/D BOPE. 23:30 ~ 00:00 0.50 WHSUR P COMP N/U TREE Printed 11612003 2 56 32 PM SCANNED FEB 0 4 2003 BP EXPLORATION Page 2 of 2 Operations Summary 'Report Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 1/2/2003 End: 1/4/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/4/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/4/2003 00'00 - 01:00 1.00 WHSUR P COMP CONTINUE TO N/U TREE. TEST TREE @ 5000 PSI, OK. PERFORM FINAL CHECK ON ESP CABLE, OK. 01:00 - 02:00 1.00 WHSUR P COMP SET BPV, SECURE WELL. RIG RELEASED @ 02:00 HRS, 01/04/05. FIRST ENERGY TO FREEZE PROTECT WELL AFTER RIG MOVES OFF. SCANNED ~j~ ~'~°~2~1~ STATE OF ALASKA ALASKA-,.4L AND GAS CONSERVATION COMrv,,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE - 56' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service ..... 4. Location of well at surface 8. Well Number 3224' NSL, 4860' WEL, SEC. 08, T13N, R10E, UM MPL-05 At top of productive interval 9. Permit Number / Approval No. 190-039 4083' NSL, 805' EWL, SEC. 05, T13N, R10E, UM 10. APl Number At effective depth 50-029-22030-00 4581' NSL, 829' EWL, SEC. 05, T13N, R10E, UM 11. Field and Pool At total depth Kuparuk River Field 4668' NSL, 832' EWL, SEC. 05, T13N, R10E, UM 12. Present well condition summary Total depth: measured 10550 feet Plugs (measured) true vertical 7596 feet Effective depth: measured 10441 feet Junk (measured) true vertical 7529 feet Casing Length Size Cemented MD TVD Structural Conductor 82' 13 3/8" 485 sx PF 'C' 115' 115' Surface 6011' 9 5/8" 1510 cuft 'G', 1510 cuft AS IV 6044' 4676' Intermediate Production 10493' 7" 398 cuft Class 'G' 10528' 7582' Liner Perforation depth: measured 9809' - 9913', 9949' - 9964', 9980' - 9999', 10024' - 10098' true vertical 7136 '-7203', 7225 '-7234', 7244'- 7256', 727' - 7317'RECEIVED Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 8RD EUE tubing to 9762' 0 2 2001 Packers and SSSV (type and measured depth) None Alaska 0il & Gas Cons. Commission 13. Stimulation or cement squeeze summary A~,;horage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby cert~~n~rrect to the best of my knowledge Signed Son -~'. Title Technical Assistant Date O-~' "~-(.~1 ' Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate RePort Legal Well Name: MPL-05 Common Well Name: MPL-05 Spud Date: 4/10/1990 Event Name: WORKOVER Start: 4/5/2001 End: 4/11/2001 !Contractor Name: NABORS Rig Release: 4/11/2001 Group: RIG !Rig Name: NABORS 4ES Rig Number: O t H~Urs Description of Operations 4/9/2001 06:00 - 09:00 3.00 MOB PRE MOVE RIG FROM MPU L-06 TO MPU L-05, BERM AND SPOT 09:00 - 11:00 2.00 RIGU PRE RAISE AND SCOPE DERRICK 11:00 - 13:00 2.00 RIGU PRE RIG UP TIGER TANK AND & TAKE ON SEA WATER 13:00 - 13:30 0.50 WHSUR DECOMP RIG UP LUBRICATOR AND PULL BPV, 650 PSI TBG AND WEIGHT UP TO 8.9 PPG 13:30 - 14:30 1.00 WHSUR DECOMP RIG UP HCR AND RU LINES TO WELL AND TEST TO 3500 PSI 14:30 - 18:30 4.00 KILL DECOMP HELD PJSM WITH TOOL PUSHER AND COMPANY REP. OPEN UP TO WELL 620 PSI SITP AND 660 PSI SICP. KILL WELL WITH 8.9 PPG BRINE FLUID. 18:30 - 19:00 0.50 KILL DECOMP MONITOR WELL FOR FLOW. WELL STATIC 19:00 - 19:30 0.50 WHSUR DECOMP SET TWCV AND TEST TO 3500 PSI 19:30 - 20:30 1.00 WHSUR DECOMP BLEED VOID & ND TREE AND HCR VALVE 20:30 - 22:00 1.50 WHSUR DECOMP NIPPLE UP BOP EQUIPMENT 22:00 - 23:00 1.00 WHSUR DECOMP TEST BOP EQUIPMENT TO 250/3500 PSI BODY TEST FUNCTION TEST BOP AND PERFORM ACCUMULATOR TEST 23:00 - 00:00 1.00 WHSUR DECOMP PICK UP LUBRICATOR/PULL TWC VALVE / LD LUBRICATOR 4/10/2001 00:00 - 01:00 1.00 WHSUR DECOMP PU LANDING JOINT / MU IN HANGER AND BOLDS/PULL HANGER TO THE FLOOR L/D HANGER& TEST ESP PICK UP WEIGHT 85 K 01:00 - 02:00 1.00 PULL DECOMP ATTACH ESP LINE TO SPOOL AND POH WITH 2 7/8" ESP COMPLETION 02:00 - 02:30 0.50 PULL DECOMP REMOVE SPOOL FROM SPOOLING UNIT AND REPLACE WITH NEW EMPTY SPOOL 02:30 - 08:30 6.00 PULL DECOMP POH WITH 2 7/8" ESP COMPLETION 08:30 - 11:00 2.50 PULL DECOMP INSPECT AND LAYDOWN PUMP. CHANGE OUT SPOOLS 11:00 - 12:00 1.00 PULL DECOMP CLEAR RIG FLOOR 12:00 - 14:30 2.50 RUNCO~I COMP MAKE UP AND SERVICE ESP 14:30 - 15:00 0.50 RUNCOI~I COMP SERVICE RIG 15:00 - 20:30 5.50 RUNCOr~ COMP TIH W/2 7/8" ESP COMPLETION 20:30 - 23:30 3.00 RUNCOr~ COMP CHANGE OUT SPOOLS AND MAKE MID-RUN SPLICE 23:30 - 00:00 0.50 RUNCOI~I COMP ,CONTINUE TO TIH W/2 7/8" ESP COMPLETION 4/11/2001 00:00 - 00:30 0.50 RUNCOI~I COMP !CONTINUE TO TIH W/2 7/8" ESP COMPLETION 00:30 - 03:00 2.50 WHSUR COMP PU LANDING JT./MU HANGER AND INSTALL PENN/ATTACH TO CONNECT & TEST 03:00 - 04:00 1.00 WHSUR COMP LAND HANGER AND RILDS 04:00 - 04:30 0.50 WHSUR COMP SET TWC AND TEST to 3,500 psi L/D landing joint 04:30 - 06:00 1.50. WHSUR COMP NIPPLE DOWN BOP ~06:00 - 08:00 2.00 WHSUR COMP NIPPLE UP TREE AND TEST VOID TO 5,000 PSI. !08:00 - 09:00 1.00 WHSUR COMP PULL TWC VALVE AND SET BPV. SECURE WELL ~ I Printed: 5/1/2001 10:09:38 AM MEMORANDUM TO: THRU: Julia Heusser, ~\~ Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 22, 2000 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Field L Pad December 22, 2000: I traveled to BPX's Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failures. Wellhouses are clean & in good condition. The AOGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected, No failures to report. Attachments: SVS MPU L pad 12-22-00jc ,cc; NON-CONFIDENTIAL SVS MPU L Pad 12-22-OOjc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Date: 12/22/00 Separator psi: LPS 140 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE L-01 1840050 L-02 1900060 140 100 90 P P OIL L-03 1900070 L-04 1900380 140 100 105 P P OIL L-05 1900390 140 100 100 P P OIL, L-06 1900100 140 100 100 P P OIL L-07 1900370 140 100 100 P P OIL L-08 1901000 4000 2000 1950 P P WAG L-09 1901010 L-Il 1930130: 140 100 1151 P P OIL L-12 1930110! 140 100 100' P P OIL !L-13 1930120~ 140 100 100 P P OIL~ L- 14 1940680 140 100 95 P P OIL L-15 1940620 L-16A 1990900 L-17 1941690 ~-20 1971360 140 100 100 P P OIL L-25 1951800 140 100 105 P P OIL L-28A 1982470 140i 100 110 P P OIL L-29 1950090 1401 100 95 P P OIL L-32 1970650 140 100 100 P P OIL L-33 1971050 L-35 1970920 140 100~ 105 P P OIL L-36 1971480 140 100 105 P P OIL L-37A 1980560 ~ L-40 1980100 140 100 100 P P F-~\~M:~\'~ OIL L-45 1981690 140 100 105 P P ~' OIL L-34 1970800 4000 2000 1900 P 4 WAG Wells: 20 Components: 40 Failures: 1 Failure Rate: 2.5% El90 Day Remarks: 12/26/00 Page 1 of 2 SVS MPU L Pad 12-22-00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 12/26/00 Page 2 of 2 SVS MPU L Pad 12-22-OOjc.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging., Pull tubing x Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory ,. Stratigraphic Service .,, 4. Location of well at surface 2055' SNL, 420' EWL, SEC. 8, T13N, RIOE At top of productive interval 4086' NSL, 783' WEL, SEC. 5, T13N, RIOE At effective depth 4578' NSL, 805' WEL, SEC. 5, T13N, RIOE At total depth 4649'NSL, 807' WEL, SEC. 5, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical ORIGINAL 10526 feet Plugs (measured) 7581 feet 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Milne Point Unit 8. Well number MPL-05 9. Permit number/approval number 90-39/94-196 10. APl number 50- 029-22030 11. Field/Pool Kuparuk River Field Effective depth: measured 10437 feet Junk (measured) true vertical 7528 feet Casing Length Size Cemented Structural Conductor 82' 13-3/8" 485 sx PF "C" Surface 6011' 9-5/8" 400 sx "G" & Intermediate 1257sx AS IV Production 10493' 7" 435 sx Class "G" Liner Perforation depth: measured 9809'-9913', 9949'-9964', 9980'-9999', 10024'-10098' Measured depth 115' 6O44' 1O526' True vertical depth 115' 4676' 7581' true vertical 7183'-7203', 7225'-7234', 7244'-7256', 7272'-7319' Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing to 9759' MD Packers and SSSV (type and measured depth) Otis XNipple @ 9615'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or Iniection Data -- OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report o,~Well Operations x Oil x. Gas Suspended 17. I l~ereby cert~,Jfft~t,l~r~oing/s true and correct to the best of my knowledge. Si~ned ~fC/~/'L Title Orilling Engineer Supervisor Form 10-404' Re~ 06/15/88 Service Dat~~jp SUBMIT IN I~OPLI{3ATE MP L-05 07/22/94 10,528' MOVE RIG FROM L-15 TO L-05. SPOT AND SET RIG ON L-05, BUILD BERMS AROUND RIG. SCOPE DERRICK. SET TIGER TANK IN BERMED AREA. BLEED DRY GAS OFF ANNULUS IN TO TIGER TANK AND OBSERVE. N/D TREE AND ADAPTER FLANGE. N/U BOP, CONTROL LINE TO 5000 OPEN SSSV CHG. PIPE RAMS TO 2 7/8" AND OFF LOADING 325 BBL SOURCE WATER THROUGH FILTERING UNIT. ACCEPT RIG @1900 HR'S ON 07/21/94. 07/23/94 10,528' CONTINUED CHG. 2 7/8" RAMS. RU FLOW METER, FILL LINE CHANGE COMP FLG ON CHOKE. PULL BPV AND SET 2 WAY CHECK. TEST ALL BOP EQUIPMENT. PULL 2 WAY CHECK, SSSV LINE AND ANNULAR VENT. RU CAMCO, RIH W/RETRIEVING TOOL, PULL PXX PLUG, A'I-i'EMPT RO POH, HUNG UP IN TRSSV AND CUT WIRE LINE AT ROP SOCKET. POH LOST TOOLS. PUMP 25 BBL DOWN ANNULUS TO CK ANNULAR VENT VALVE FOUND VALVE TO BE OPEN. FILL TBG. CLEAN OUT MUD PUMP. CIRC DN TBG. PUMP 30 BBL ZANVIS PILL, NO RETURNS. SPOT ZANVIS PILL AND LET PILL SET. FILL ANNULUS W/SOURCE WATER. RU CAMCO, TEST LUBRICATOR AND RIH TO SSSV AND LOCK OPEN. POH AND CHG. TOOLS, RIH TO 9662' & LATCH LOST TOOL STRING AND PXX PLUG AND POH AND LAY DOWN SAME. PUMPED 30 BBL HI-VIS XANVIS PILL FOLLOWED BY 50 BBL FILTERED SOURCE H20. WAIT ON PILL. ClRC TBG AND ANNULUS VOLUME. PU 27 JTS 3 1/2" DP AND STAND IN DERRICK TO RACK 2 7/8" TBG. 07/24/94 10,528' CONTINUED PU 3 1/2" DP AND MONITOR WELL FOR FLUID LOSS. MU LANDING JT IN HGR BOLDS, UNSEAT PKR. POH WITH ESP. SPOOLING E- LINE AND TAKING BANDS OFF AND SPOOL CONTROL LINE TO SSSV AND SLM TBG. TOTAL OF 306 JTS 2 7/8" TBG. LAY DOWN ESP AND CK OUT W. TECHNICIANS. RU CAMCO AND RIH FOR TD. TAG @10365' PUTS. FILL AT 267' BELOW BOTTOM PERF. RU TO RUN ESP AND CHECK ALL OIL AND TAKE SAMPLES OF MTR AND PUMPS ETC. RIH W. SAME. 07/25/94 10,528' CONTINUED RIH WITH ESP AND TOTAL OF 306 JTS 2 7/8" 6.5#/FT L-80 8RD EUE TBG TO 9760' USED TOTAL OF 659 SS BANDS AND 6 FLAT GUARDS FOR MOTOR CABLE. MU HANGER AND LANDING JT W/SAFETY VALVE. MAKE PENETRATOR SPLICE IN ELECTRIC LINE. LAND TBG AND RILDS TEST HANGER. PUMP 130 BBL'S CRUDE OIL DOWN 3 1/2"X 7" ANNULUS + PUMP 20 BBL DIESEL DOWN TBG. SET TWC. NIPPLE DOWN BOPS._ N_U_ RECEIVE: D AUG -4 1994 Alaska Oil & Gas Cons. Commission Anchorage ADAPTER FLG AND TEST. NU TREE AND TREE. PULL TWC AND SET BPV. TYPE "H" PROFILE. LAY DOWN 3 1/2" DP OUT OF DERRICK USED FOR BELLY BOARD FOR 2 7/8" TBG. RELEASE RIG @0600 HR'S ON 07/25/94. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 28, 1994 Hal Stevens/John Hendrix Prod Spvr Wells BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX MPU wells # C-3 and L-5 PTD 82-050 and PTD 90-039 Dear Mr. Stevens/Hendrix: On July 20, 1994, our Inspector Jerry Herring witnessed no-flow tests on BPX's MPU wells No. C-3 and L-5. The wells had been shut-in and were bled down. Both wells were essentially dead, venting a small amount of gas from the tubing. The Inspector concluded that subject wells were not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valves from B?X's MPU wells C-3 (PTD 82-050) and L-5 (?TD 90-039) on the condition that the low-pressure sensors and surface safety valves must be maintained in good condition; and, if for any reason, the wells again become capable of unassisted flow of hydrocarbons, the subsurface safety valve(s) must be reinstalled and maintained in good working condition. Sincerely, Blair E. Won~fell PI Supervisor c: Larry Niles/John Ketchum Jerry Herring bew/nlm~3cl 5 MEMORANDI ,., State c,. Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johnsto,,~'~ Chairman.;::~> DATE: July 25, 1994 Blair Wondzell, ~ P. I. Supervisor '~-'~ FROM: i~eT,Herri_ng, ~'~ SUBJECT: e roleum Inspector FILE NO: lw9kgtbe.doc No Flow Tests BPX, Milne Pt. Unit MPU C-3 & L-5 Wednesdav..Julv 20. 1994: I traveled to BPX's Milne Point Unit to witness no flow testing on wells C-3 and L-5. The'wells were shut-in and depressurized upon my arrival. Both wells demonstrated good no-flow capabilities. Well L-5 had a down hole pump failure problem. A workover of L-5 is planned for the near future. Well C-3 had been on gas lift and traces of gas vented from the tubing throughout the day as the lift gas worked its self out of the system. Both of these wells demonstrated that they are not capable of unassisted flow. Summary: I witnessed no flow tests on MPU wells C-3 & L-5. 9 ,I ERROR IN TAG - PSL 2530 .Al ERROR IN TAG - PSH-2530 .Al 94-J~i 2e ±8:ee;ee STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing ~ Repair well __ Plugging __ Time extension ~ Stimulate __ Change approved program __ Pull tubing x Variance __ Perforate __ Other X __ Replace ESP 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development x Exploratory __ 3. Address Stratigraphic __ 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ 4. Location of well at surface 8. 2055' SNL, 420' EWL, SEC. 8, T13N, RIOE At top of productive interval 9. At effective depth 10. 4578' NSL, 805' WEL, SEC. 5, T13N, RIOE At total depth 4649' NSL, 807' WEL, SEC. 5, T13N, R10E Datum elevation (DF or KB) KBE = 56' feet Unit or Property name Mi/ne Point Unit Well number MPL-05 Permit number 90-39 APl number 50- 029-22030 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10526 feet Plugs (measured) 7581 feet 10437 feet Junk (measured) 7528 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 82' 13-3/8" 485 sx PF "C" 115' 115' Surface 6011' 9-5/8" 400 sx "G" & 6044' 4676' Intermediate 1257sx AS IV Production 10493' 7" 435 sx Class "G" 10526' 7581' Liner Perforation depth: measured 9809'-9913', 9949'-9964', 9980'-9999', 10024'-10098' RECEIVED JUL 9 1994 true vertical 7183'-7203', 7225'-7234', 7244'-7256', 7272'-7319' Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing to 9725' MD Alaska 0ii & Gas Cons. Commission Anchoraqe Packers and SSSV (type and measured depth) Otis 2-7/8", 'FMX' TRSV @ 549' MD; Otis 7" 'RDH' Packer @ 572' MD' 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 7/2O/94 16. If proposal was verbally approved Oil x Gas ~ Name of appro~er Date approved Service 17. I hereby ce~if~,/a~~oi~yrue and correct to the best of my knowledge. Signed / '~ ~/t%, Title Drilling Engineer Supervisor I FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended Conditions of approval: Notify Commission so representative may witness I Plug integrity BOP Test ~ Location clearance ~/o ,~[o~,.,, -/%~-~. Approval No. ~ ~ _ / ~ ~ Mechanical Integrity Test ~ Subsequent form required 10- 4 c~ 4 Approved by order of the Commission jr ginal Signed By ' vid W. JohnSton Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE 'WELL No. COMPLETION MILNE POINT SKETCH UNIT (13) APl No.: 50-029-22030 PERMIT No.: 90-.39 COMPLETED: 10/27/90 LAST WORKOVER: 6/11/91 ,/-- WKM TUBIN(3 HANGER W/ 2.5 .... H" PROFILE BPV ANNULAR VENT VALVE NOTES: 1. ALL DEPTHS MEASURED KDB = 55' RIG 27E KDB-SL = 56' KDB-GL = 35' 2. MAX. ANGLE = 52' @ 10,400' 5. K.O.P. = 500' 4, SLANT HOLE: YES 5. MIN. ANGLE = 47.2' @ 8400' 6. TREE TYPE: WKM 2 9/16" 5000# W/2 7/8" 8rd TREETOP CONNECTION 7. MIN. ID = 1.875" @ 583' & 968' 8. COMPLETION FLUID: 8.4 PPG SOURCE WATER 9. STIMULATION: FRAC (ALL ZONES) PUMPED 171,920 #'s 16/20 MESH CARBOLITE -- 16 JTS 2 7/8", 6.5#, L-80, 8rd EUE TBG -- 1/4" S.S. CONTROL LINE -- ELECTRIC SUBMERSIBLE PUMP CABLE NO. 4 AW(3 CL 350 TO PKR NO. 2 AWG CL 350 FROM PKR TO ESP 549' OTIS 2 7/8 .... FMX" TRSV (2.513" ID) 562' "XO" 2 7/8" x 2 5/8" (1.995" ID) 572' OTIS 7 .... RDH" PACKER (1.94" ID) 585' OTIS 2 5/8 .... X" LANDING NIPPLE (1.875" ID) 585' "XO" 2 3/8" x 2 7/8" (1.995" ID) 585' 289 JTS 2 /8 6.5//, L-SO, 8rd EUE TBG (2.441''7ID)''' 8950' 9686' 9725' 9726' CSG RA TAG LOG @ 8947' OTIS 2 3/8 .... XA" SLIDING SLEEVE W/ "xo"s (ID = 1.875") "XO" 2 7/8" x 2 5/8" (1.995 ID) TOP OF ESP: CENTRILIFT FC 650, 227 STAGE, 130 HP, GAS SEP'ARATOR, PHD W/CENTRALIZER PERFORATION DATA MD DEPTH: LZ 9809'-9913' LK1 9949'-9964' LK2 9980'-9999' LK3 10,024'-10,098' DENSITY: TVD (7138'-720Y) (7225'-7234') (7244'-7256') (7272'-7319') 4.5" GUN W/ HYPERJET II 5 JSPF & 72' PHASING END .49" TTP=30.25" 9774' BOTTOM OF ESP RECEIVED d,JL 'i 9 1994 Gas Cons. Commission Anchorage ~//~ 10,342' TAG FILL S/L 6/9/91 PBTD @ 10,441' '""- 10,528' 7", 26#, L-80, BTRC CSG CONOCO INC. ANCHORAGE DIVISION APPROVED BY: JHA/HDS DATE' 7/30/92 , DRAFTED BY: CFP/SJN CAD FILE: WCOL5 Milne Point L-05 RWO OPERATIONS SUMMARY Obiective: Pull failed electrical submersible pump from well and recomplete with a new ESP and existing tubing. , . . , . . . , Pre- rig: Verify tubing integrity. Shift sliding sleeve open. Test SSSV. Perform no flow test on well. Bullhead kill well down tubing with kill weight brine. Shear annular vent valve and bullhead or circulate to kill annulus. Install BPV. MIRU Nabors 4ES workover rig. Pull existing 2 7/8" tubing and ESP assembly. Tag TD with slickline. Peform fill cleanout if necessary. Set electric line set packer and tailpipe/screen assembly immediately above top perf. If well did not pass no flow test in step 1, install liquid level control valve in packer. Pressure test 7" casing. Re-run existing 2 7/8" tubing and new ESP. RDMO Nabors 4ES. Place well on production. This work is expected to begin 7/20/94, immediately following the L-15 completion. The pump in well L-05 failed 7/17/94 and it is desired to replace it while the workover rig Nabors 4ES is on L-pad. DBR, July 18, 1994,5:40 PM RECEIVED JUL 1 9 1994 Alaska 0il & Gas Cons. CommJssior, Anchorag~ _,onoco Inc. Anchorage Division ~cord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 January 4, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Milne Point Well Log Magnetic Tapes L-5. Quantity Contents Transmittal Approved By L-5 Magnetic Tape. APl #50-029-22030 DTE/LDT/CNL/NGT/CASlNG GR & 1.2" LDT/CNL LOG DATE: 19- APR-90 KB ELEV: 49' RUN: 1 START: 10570 STOP: 932.5 TAPE DATE: 28-JUNE-90 REG #73850 Signed By Date Received By ~ ~/~_~ Date Remarks f~' ~? --- RECEIVED Transmittal Copy Only To JAN 0 zl 199} Alaska Oil & Gas Cons. Commission Anchorage .~noco Inc. Anchorage Division , ~cord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 December 22,, 1992 Anchorac, le, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Milne Point Well Log Magnetic Tapes L-6, L-5, and L-2. Quantity Contents L-6 Magnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-22003, Log Date: 03-May-90, Ref #73866. I 'each Magnetic Tape. GCT Directional Survey (LIS Format), APl #50-029-22030, Log Date: 02-May-90, Ref '#73865. 2 Magnetic Tape. GOT Directional Survey (LIS Format), APl #50-029-21998, Log Date: 08-Nov-90, Ref #74189. . ,~' Signed By Transmittal Approved By C..,_;;,~--',~ ~ /M~~g~*~ Date ~D~-~-e-mb~r 22, 1992 Instructions: Please ackn wledge r~¥eip~(ly~b'~ signing and returning ~ ~ second copy. R[CEIVED Received By " ~ Date Remarks DEC 2 2 1992 Transmittal Copy Only To Alaska 011 & Gas Cons. Commission Anchorage .Oo~ra~lon$ Derrorm~o: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,5$ION 2. Name ot Operator Conoco Inc. REPORT OF SUNDRY WELL OPERATIONS Ocerat~on ShUtdOwn __ Stimulate _.. -'itjCjg~n§ __ ~erfora~e __ ';uti tubing X A;tgr cas, rig __ qeoa~r weil __ AK 99734 Address ?.O.B. _340045, ?rudhoe ;Bay: · '- Location of well at surface 420' FiEL ~ 2055' At tOD of Droductwe mterYal FNL, SEC 8, ~13N, RIOE, T~ 783' FWL x 4096' FSL, SEC At effecbve oeot, 806' F~fL x 4580' FSL, SEC At total dcpm 808' F~EL x 4668' _F_SL, SEC 12. Present we~t condition summary Total degm; measured :"ue ver~lcai Effectwe ceutn: measured true verucal 5, T!3N, 5, T13N, 5, T13N, 10,550' 7,596' ].0,439' 7,529' RiOE, U~'I RIOE, bqM R10E,_~ feet .=~ugs (measurecll N / A feet ~eet Junl< (measured) N/A , ,, 6. D~um elevat]on (DF or KB) 5 6 feet ., 7. Unlt or Property name Milne Point Unit 8, Welt numOer L-5 _ 9. Permit numt3er/aDl~roval numoer 90-39/91-109 ,_ :0. APl number 50--029-22030 "11. Field/Pool Kuparuk River Casing Length Structural Conductor 80 ' Surface 60 09 ' ! nterm eOmte P rOductlon 10 493 ' L,ner =erforatton ¢__,eotn: measure(; X/A true ver~ic.~t N / A tubing (size, grade, and measureO Oe~tn) 2 Pack',em aha SSSV (type and measured de~n) 13. Stimulation or cement squeeze summary S~ze Cemented 13 3/8" To Surf 9 5/8" 470 BBL CL.E+ 87 BBL CL.G 7" 90 BBL CL.G MeasureC cegtn True vertical dep~ 115' 115' 6044' 4776' 10528' 7606' 7/8" 6.5¢~ L-80 EU ~ 9686' PACKER: OTIS "RDH" @ 572' SSSV : OTIS "FMX" TRSV !~ DEC 1 4 1992 (B/ESP=9774') Alaska 0il & 6as Cons. Anchorage 549' , ,_ ! ntervais tre~te0 (measured) N / A ?reatment description including volumes used a~ci final pre,~ure Represenfative Daily Average Proctu.ction or fniecuon O_at_a _. Oil-Bbt Gae. Mc'f Water-Bbl Casing Pressure '~,4bing Pressure Prior to well oDeration N/A SubseQuent to operation ~ 5. Attachments 16. Status of w~I classification as: Copies of Logs and Surveys run ~ Daily Mel;~n c4 Welt O~eraUon~ __ Oil X Gas Suspended __ I --" ~ Z I heret2y certify tl~at the foregmr~g is true and corregt tO the be~t of my Knowiedge. Jaigned ~o-~. ¢. 0',1~"3 ,, _ Tftle Senior Production Foreman. Form 10404 Rev 06/15/88 Service .. SUBMIT IN DUPLICATE ) missio~:~ Workover History :{i!ne Point L No. 5 - .~LACE INOPERATIVE ESP Location: Milne Point Field - KUPARUK Drilling Days: Completion Days Workover Days: Planned Actual N/A N/A N/A API No.: 50-059-25030 Planned Actual 10,526' MD 10,448' PB MD RE E VED 06/06/91: Move rig to L-5. @ 1900 hrs, 06/05/91. 06/07/91: MIRU on L-5. N/U choke & kill lines. RU to tod of tree. Wait on water to kill well. Spot slop tank. Take on 410 bbls source water heated to llO'F & filtered to 3~. DP press = 300 psi, csg Dress = 500 psi. Bleed off gas from csg to 250 psi. Begin displacing well w/ source water. 06/08/91: Circ 480 bbl source water. F~tmp 25 bbl HEC Hi-Vis pill. Pump 455 bbl source water until pill ret & clean returns (960 total pu~ped - 364 = tbg/ann vol - lost approx 70 bbl) Install 2-way check, ND tree & NU BOPE. Accum bottle maint. Test BOPE to 500/5000 and annular to 500/3500 - OK. (Note: had called AOGCC on 6 June @ 900 hfs - did not witness). Had to repl 1 valve in choke line. Pull 2-way check, B/O LD screws, PU tbg - SCSSV open confirmed. POOH to SCSSV and RDH PKR. Found vent stuck open (in PKRbypass). LD SCSSV & RDH. POOH w/ 2-7/8" T~g. 06/09/91: POOH w/ 12 stds. Make cut on cable & C/O spools in spooler. Fin CCH w/ total 306 its, cut 668 bands, missing 1 ba~ld on std 45. LD old pump. RU Otis. TIH & tag up at 10,342' (Last tag: 10,421' on 10/22/90; B/ PERFs: 10,098'). RD Otis. TIH 36 stds tbg, RTTS & storm valve, 1 jt tbg and set RTTS and back out of S/valve. ND BOPE. Retrieve & replace alignment pin and NU BOPE. Set test plug & test flange to 500/5000 - OK. Break pup out of RDH pulled from well. TIH 1 jt and unset PKR a POOH w/ PKR & tbg. Locate, transport, and Hi Pot test 10,000' of centrilift CL350, No. 4 AWG cable. (Note: cable POOH had gas between one of conductors and first layer of insulation). 06/10/91: Fin Hi-Pot and make splice. PU Centrilift ESP assby. TIH w/ 145 stds 2-7/8" 6.5# L-80 EU tbg. Two bands being installed per jr. PU RDH PKR & SCSSV. Make splices above and below PKR. 06/11/91: Splice pigtail for PKR mandrel. Plug in pigtail, M/U control line and TIH 10 jts. Locate add'l No. 2 cable and make splice. Run final 6 joints in hole. Total bands installed = 654 (2/Jr + splices, PKRs & flats). Make hanger splice. Land hgt. Freeze protect w/ 60 bbls diesel down 2-7/8" x 7" annulus. RU otis & set XX in X nipple at 583'. Set PKR @ 1900 psi - continue Dumping and teat to 2500 for 15 min. Retrieve plug & RD slickline. Test annulus to 500 psi for 15 min. Freeze pro=sc= =bg w/ 12 bbls diesel. Install BPV. ND BOPE. Take annular to MPOC for servicing. NU tree. Pull BPV, run-2-way check, and test tree to 5000 psi. Rerun BPV and close valves. Make final conductivity check on ESP - OK. Released rig @ 2200 hfs on 10 Julle 91 to AFE 1423. STATE OF, ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLF. TION RI PORT AND LOC il. Status of Well Classification of Servtce Well tO L ~ GAS ~; SUSPENDED r~, ABANDOI~r~)/LLi~-;-~;~,E~Vi ~ CONOCO INC. ~.~.~% m ~ 90-39 3. Address 340045 PRUDHOE BAY, AK 99734 4. Location of welt at surface 420' :FWL, 2055' :FNL, SECTION 8, T13N, R10E, OM At Top Producing Interval 783' FWL, 4096' FSL, SECTION 5,T13N,R10E, UM At Total Depth 808' FWL, 4668' FSL, SECTION 5,T13N, R10E, UM Elevation in feet (indtcate KB, DF, etc.) KB 56' MSL 6. Lease Designation and Serial No. ADL25509 8 APl Number 5o029-22030 9. Unit or Lease Name MILNE POINT UNIT 10. Well Number L-5 11. Field and Pool KUPARUK RIVER FIELD 12. Date SCudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 04/10/90 , 04/20/90 10/27/90 CO]ViP' I N/Aec, MSL 10,550/7596 10,437/7527 I YES [~ N 0 ~_~.= 517' feet MD +1800' 22. Type Electric or Other Logs Run (~i~I~ ~ CET, CBT, CCL, GR, GYRO, PERF, CNL, LDT 23. CASING, LINER AND CEMENTING RECORD J 16 No of Completions 1 CASING SIZE 13-3/8' 9-5/8" 7II WT. PER FT. 48# GRADE H-40 HOLE SIZE 30Ii 36# J-55 12.25 26# SETTING DEPTH MD TOP tBOTTOM ~115 ' RKB 33 ~044 ' 33 10,1528 ' RKB L-80 33 24. Perforations open to Production (MD+TVD of Top and Bottom and 8 . 5II CEMENTING RECORD IAMOUNT PULLED 485 SKS PERMAFROST "C"NONE 269 BBLS ARCTIC BET IVNONE 71 BBLR CnASS 90 BBLS CLASS "G'! NON~ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDI 2 7/8 538' 538' interval, size and number) 10,024-10,098. (7272) 9,980- 9,999~ (7244) 9,949- 9,964' (7225) 9,809- 9,913~ (7138) - 7319') - 7256') - 7234') - 7303') 4.5 00 W/HYPERJET II) 5JSPF & 72 DEGREE PHASING EHD=. 49" TTP=30.25" 9640' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD)I AMOUNT & KIND OF MATERIAL USED ALL PERFORATE~ 200BBL LINEAR GEL, 1050BBLS 11.0 PPG FLU~]~. 27. Date First Production 22/02/90 Date of Test } Hours Tested Flow Tubing Casing Pressure Press. 270 0 28. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) FLOWING IPRODUCTION FOR IOIL-BBL TEST PERIOD I~ 217 CALCULATED OIL-BBL 124-HOUR RATE I~ 868 GAS-MCF 70 GAS-MC F 280 CUR E DATA WATER-BBL ICHOKESIZE IGAS'OIL RAT O i ~ 260 J 322 WATER-BBL lOlL GRAVITY-APl tcorr) 4 I 22.6 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 Submit tn Cluohcat(, R.~ 7-1-R6I CONTINUED ON REVERS= SIDE 29. 30. NAME Kuparuk Fm Middle Kup Lower Kup Base Kup GEOLOGIC MARKERS MEAS. DEPTH Ii TRUE VERT. DEPTH RK~ RKB 9545 i! 6945 9804 ~, 7134 9943 10100 7224 7334 FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, ancl time of each phase, N/A Not Tested 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air iniection, salt water disposal, water supply for injection, observation, iniection 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 welt 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 eievation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item, 27: Method of Operation: Flowing, Gas Lift, Rod Pump: Hvctraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 29: tf no cores taken, indicate "none". 10-40- L-5 DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Point L No. 5 (I) CONFIDENTIAL Location: 2055'FNL, 420'FWL, Sec 8, T13N, R10E Objective: 7400' TVD - Kuparuk River W.I. 100% AFE 10-61-1193 Umiat Meridian 4-10-90: Install Hydril & hookup diverter lines. NU riser & flowlines, function test Hydril, install mousehole. PU BHA, orient moter & MWD. Drld F/ 112' to 947'. POOH cnange MWD, orient Same & RIH. DRLD F/ 947' to 1630'. DEPTH ANGLE DIRECTION 464 1.10 N55.9W 706 4.30 N19.1W 1099 11.80 N8.9W 1340 16.20 N8.6W 1431 18.30 N6.5W Mud wt. 9.20 Viscosity: 59 Nabors 27E (0-01-0) Cum. mud cost:$ 3,999 Drilling Foreman: Mountjoy 4-11-90: Drlg F/ 1630' to 2730'. Short trip 15 stds, no fill. Drlg F/ 2730' to 3806'. Short trip, no fill. Drlg F/ 3806' to 4088'. DEPTH ANGLE DIRECTION 1747 23.90 N07.3W 2155 35.10 N06.5W 2564 45.60 N05.4W 2973 47.00 N00.7E 3483 50.00 N02.7E 3894 49.50 N06.5E Mud wt. 9.30 Viscosity: 47 Nabors 27E (0-02-0) Cum. mud cost:$ 4,976 Drilling Foreman: Polya 4-12-90: Drlg F/ 4088' to 5006'. Short trip 10 stds, no fill. Drlg F/ 5006' to 5963'. DEPTH ANGLE DIRECTION 4112 48.60 N01.4E 4395 49.40 N04.3E 4682 49.00 N05.0E 4935 49.30 N06.7E 5533 47.30 N05.8E 5851 48.60 N07.2E Mud wt. 9.40 Viscosity: 42 Nabors 27E (0-03-0) Cum. mud cost:$ 7,390 Drilling Foreman: Polya L-5 DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Point L No. 5 (I) CONFIDENTIAL Location: 2055'FNL, 420'FWL, Sec 8, T13N, R10E Objective: 7400' TVD - Kuparuk River W.I. 100% AFE 10-61-1193 Umiat Meridian 4-13-90: Drlg F/ 5963' to 6064'. Lost 100 bbls mud @ 6025. Spotted fine mica and medium walnut; no more losses. Circ & cond mud, pump dry job. POOH, tight spot at 945' to 900',worked through tight spot & RIH to 6064', no fill. Circ & cond mud -- no losses. POOH, L/D BHA R/U Csg crew, run 130 jts of 9 5/8" J-55 36# Butt Csg · ! I · DEPTH ANGLE DIRECTION 5993 48.70 N08.8E Mud wt. 9.50 Viscosity: 44 Nabors 27E (0-04-0) Cum. mud cost:$ 14,620 Drilling Foreman: Polya 4-14-90: Ran remaining 20 jts of 9 5/8" Csg, 150 jts total. M/U mandrel hanger & landing jt. Circ one hole volume. Pumped stage one of cement: 20 bbls H20 + 10.5 ppg sepiolite + 20 bbls H20, 269 bbls 11.8 ppg arctic set IV cement, 71 bbls class G cement + .0532 D024 + 0.002 D046 + 0.01 S001. Four unsuccessful attempts to hydro. activate HOS cementer DV tool. Drop bomb, open tool w/1000 psi & circ. Pumped stage two cement: 15 bbls H20 + 90 bbls 10.5 ppg sepiolite + 15 bbls H20, 201 bbls 11.8 ppg arctic set IV cement, 16 bbls class G cement + 0.0532 D024 + 0.002 D046 + 0.01 S001. B/O landing jt., R/D csg grew & clear rig floor. N/D flowline, riser, hydril & diverter. M/U speed head. N/U BOP stack & test BOPs. Strap & M/U BHA, M/U & orient MWD. Mud wt. 8.50 Viscosity: 26 Nabors 27E (0-05-0) Cum. mud cost:$ 20,734 Drilling Foreman: Polya 4-15-90: Finish orienting MWD & M/U BHA. RIH tag cmt @ 1920'. Drlg cmt & DV tool @ 1924'. RIH & tag cmt @ 5936'. Circ & cond mud, pressure test csg to 1750 psig for 30 min.-- ok. Drlg cmt & float equip. Drilled 10' of new FM. to 6074' & perform 13.8 ppg leak off test. Drlg f/6074' to 7064'. Short trip to shoe. Drlg f/7064' to 7476'. DEPTH ANGLE 6133 48.90 6450 50.30 6735 51.80 6985 50.80 7141 49.80 7301 48.00 Mud wt. 9.50 Nabors 27E (0-06-0) Viscosity: 40 DIRECTION N07.6E N06.4E N04.6E N04.4E N04.8E N04.3E Cum. mud cost::$ Drilling Foreman: L-5 DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Point L No. 5 (I) CONFIDENTIAL Location: 2055'FNL, 420'FWL, Sec 8, T13N, R10E Objective: 7400' TVD - Kuparuk River W.I. 100% AFE 10-61-1193 Umiat Meridian 4-16-90: Drlg F/ 7476' to 8009'. Short trip 10 stds--ok. Drlg F/ 8303' to 8762'. Short trip 10 stds--ok. Drlg F/8762' to 9082'. DEPTH ANGLE DIRECTION 7614 47.30 N06.4E 7993 46.10 N05.3E 8246 47.30 N03.6E 8531 47.50 N04.3E 8690 47.70 N01.6E 8878 49.10 N02.9E Mud wt. 9.80 Viscosity: 42 Nabors 27E (0-07-0) Cum. mud cost:$ 28,925 Drilling Foreman: Polya 4-17-90: Drlg. f/9082' to 9554'. Short trip. Drlg. f/9554' to 9824'. Short trip to shoe. DEPTH ANGLE 9004 48.30 9224 48.70 9475 49.60 9635 50.00 Mud wt. 10.20 Viscosity: 42 Nabors 27E (0-08-0) DIRECTION N02.3E N00.6E N00.9E N01.4E Cum. mud cost:$ 35,868 Drilling Foreman: Polya 4-18-90: Ream f/9730' to 9824'. Drlg. f/9824' to 10,520. DEPTH ANGLE 9985 51.00 10237 50.70 10441 54.50 Mud wt. 10.40 Viscosity: 43 Nabors 27E (0-09-0) DIRECTION N02.7E N02.9E N01.2E Cum. mud cost:$ 38,676 Drilling Foreman: Mountjoy 4-19-90: Circ. bottoms up. POOH to shoe, RIH to 10,433, wash to 10,520. Circ and condition. POOH. RU Schlumberger. Run DIL-LDT- CNL-NGT-SP. RD SCHLUMBERGER. Mud wt. 10.40 Viscosity: 43 Cum. mud cost:$ 41,675 Nabors 27E (0-10-0) Drilling Foreman: Mountjoy 4-20-90: MU BHA, RIH to 10,425' and ream to 10,520'. Drlg. f/ 10,520' to 10,550'. Circ and condition. POOH LD DP and BHA. RU to run 7" csg. Start running csg. Mud wt. 10.40 Viscosity: 42 Cum. mud cost:$ 43,021 Nabors 27E (0-11-0) Drilling Foreman: Mountjoy L-5 DRILLING HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Point L No. 5 (I) CONFIDENTIAL Location: 2055'FNL, 420'FWL, Sec 8, T13N, R10E Objective: 7400' TVD - Kuparuk River W.I. 100% AFE 10-61-1193 Umiat Meridian 4-21-90'. Finish running 244 jts. 7", 26 #/ft, L-80, BTRS csg. FC @ 10,439', shoe @ 10,528'. RU cement head. Pump 50 BBLS sepiolite spacer, 30 BBLS water, 90 BBLS Class G cement. Displace w/383 BBLS NaBr and 20 BBLS diesel. Bump plug to 3000 psi and hold for 30 min. to test csg. -OK. Set packoff, test to 5000 psi. ND stack, NU tree. Mud wt. 10.40 Viscosity: 42 Cum. mud cost:$ 43,021 Nabors 27E (0-12-0) Drilling Foreman: Mount~oy 4-22-90: Clean pits and freeze protect L-5. Released rig at 2400 HRS. This well will be droped from the drilling report until it is completed. Mud wt. N/A Viscosity: N/A Cum. mud cost:$ 43,021 Nabors 27E (0-13-0) Drilling Foreman: Mountjoy Milne Point L No. 5 COMPLETION HISTORY Kuparuk River Field - North Slope Borough, Alaska Milne Point L No. 5 (I) CONFIDENTIAL Location: 2055'FNL, 420'FWL, Sec 8, T13N, R10E Objective: 7400' TVD - Kuparuk River W. I. 1.0 AFE 10-61-1193 Umiat Meridian 10-15-90: MIRU. Accept rig @ 21:00 hrs. ND tree and NU BOP. Mud wt. N/A Viscosity: N/A Cum. cost:$ 1,614,952 EWS Rig 4 (0-13-0) Drilling Foreman: Stevens 10-16-90: Continue Ru, Nu BOPE. Repair electrical pressure switch on accumulator. Rack and strap 2 7/8 tubing. Haul source water from CFP to rig tanks. Heat to 120 deg F. GIH w/test plug. Test Pipe Rams, Choke manifold. Pull test plug and found gouge up the side of plug. Alignment pin in tubing hanger was not retracted. Pin was bent and clould not be backed out. ND BOPE. Remove alignment pin and replace, Re-work test plug and begin NU BOPE. Mud wt. 10.2 Viscosity: N/A Cum. cost:$1,807,582 EWS Rig 4 (0-13-2) Drilling Foreman: Stevens 10-17-90: Test BOP to 3000 PSI, RIH W/ 2 7/8 TUB W/ 6 1/8 BIT & 7" scrapper set nominal tag ice plug at 45' CIRC throw ice plug & continue RIH. Mud wt. 9.8 Viscosity: N/A Cum. cost:$1,654,126 EWS Rig 4 (0-13-3) Drilling Foreman: FOX 10-18-90: Continue RIH W/ bit & scraper on TBG. Tag fill at 10,416' RKB. Circulate 100 BBLS. continue to bring fluid system from 10.2 PPG tow a 9.8 PPG. Tagging bottom while circulating - fill appears to be solid Lost surface working volume when diesel cap was circulated out of the hole. Suck contaminated diesel out of pits. Mix up first HEC gel pill (3 1/2 # HEC/BBL) and dirt magnet pill (1 drum of DM-40 in 50 BBLS) Using source water reverse circulate 150 BBLS of brine. Reverse circulate 25 BB1 HEC pill followed by 50 BBL dirt magnet pill. Unable to keep 10M or 3M filters from plugging up immediatly (filters plugging W/materials that look like dilling mud) Pump rate 4 BPM. Suck contaminated brine out of pits. and replace with 300 BBLS of 9.8 NACL brine. Mix up final 25 BBL gel pill (3 1/2 # HEC/BBL) Using newbrine. Attempt to continue reverse circulateing. Thow out frozen pump discharge line. Replace cracked pump liner. Mud wt. 9.8 Viscosity: N/A Cum. cost:$1,675,144 EWS Rig 4 (0-13-4) Drillinq Foreman: FOX Milne Point L No. 5 COMPLETION HISTORY Page 2 10-19-90: Continue to thaw out discharge line. Reverse circ. final 25 bbl HEC pill and circ w/ 512 bbls 9.8 ppg brine. POOH w/ tbg, and L/D bit & scraper. Fill hole w/ 26 bbls brine & R/U Schlum. Conduct safety meeting. P/U 20' csg. gun with GR/CCL & RIH. Correlate with GR/CC1 & tag fill @ 10,421 RKB. Perf. & POOH. Made 6 more csg. gun runs for a total of 7. Preparing to perforate w/ run # 7. Mud wt. 9.8 Viscosity: N/A Cum. cost:$1,790,300 EWS Rig 4 (0-13-5) Drilling Foreman: FOX 10-20-90: Continue to perforate csg. Made 3 more csg. gun runs for a total of 10. Had 2 gun failures with top section of guns due to swithch failures. R/D Schlumberger. Change out pipe rams & P/U BOP saver. Spot & R/U Dowell. Mix frac fluids & Qc fluids & sand. OK. Hold safety meeting. Press. test lines to 7000 psig. OK. Pump 200 bbl gel prepad @ 40 BPM @ 2816 psig and shut down for 15 min. ISIP 1845 psig and 15 min SI 925 psig. Pump frac job @ 40 bpm. Pumped total of 1758 bbls cross linked gel, 171,920 lbs 16-20 carbolite, and displaced w/ 375 bbls 11.0 ppg NaCl/NaBr brine. Final treating press. 2600 psig. S/D pumps & monitor well. R/D frac equip. Allow for gel to break. Rig up mud pumps and annular inject 525 bbls 9.8 ppg brine and frac tank bottoms followed by 60 bbls diesel. Rate 2 bpm @ 1600 psig. Well head press @ 2400 hrs was 50 psig. Mud wt. 9.8 Viscosity: N/A Cum. cost:$2,182,714 EWS Rig 4 (0-13-6) Drillinq Foreman: FOX 10-21-90: Continue to monitor wellhead press. Down to 0 psig and L/D Dowell valves and BOP saver. Install wear bushing. Tally & M/U BHA. RIH w. collar, xo, csg. scraper, xo, 4-4 3/4" DC's and 4" drill pipe. Tag fill @ 10,154' RKB. POOH w/ tbg. Prep to run bailer. Mud wt. 11.0 Viscosity: N/A Cum. cost:$2,218,786 EWS Rig 4 (0-13-7) Drillinq Foreman: FOX 10-22-90: Continue to POOH & L/D Scraper, bumper sub, jars, & DC's. P/U saw tooth collar, XO, flapper valve, 32 jts drill pipe, XO, safety joint, XO, & 3 3/4" Bulldog bailer. RIH w/ 4" DP. Tag fill @ 10,112' RKB. CO to 10,187', short trip. Tag @ 10,142' & CO to 10,249'. Short trip. Tag @ 10,193' & CO to 10,249' Short trip. Tag fill @ 10,149' & CO to 10,421' PBTD. Short tri~, allow 1 hr. for sand to settle. Tag @ 10,421' PBTD. Prpare to POOH. Mud wt. 11.0 Viscosity: N/A Cum. cost:$2,242,035 EWS Rig 4 (0-13-8) Drillinq Foreman: FOX SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO INC. MILNE POINT UNIT L-5 MILNE POINT IJOFILHED NORTH SLOPEr ALASKA SURVEY DATE: Z-MAY-90 ENGINEER: SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo OISTo PROJECTED ONTO A TARGET AZIMUTH OF NORTH 3 DEG Z! MIN EAST CONOCO INC. MILNE POINT UNIT L-5 MILNE POINT NORTH SLOPE~ ALASKA COMPUTATION DATE: 17 \Y-gO / TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG ;E ~' DATE OF SURVEY: Z-MAY-90 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -56.00 0 0 N 0 0 E 0.00 0.00 0.00 N 0.00 100.00 100.00 44.00 0 17 S 68 32 W -0.06 0.23 0.05 S 0.13 200.00 2.00.00 144.00 0 3Z S 86 31 W -0.24 0.03 0.19 S 0.83 300.00 299.99 243.99 0 36 N 79 28 W -0.24 0.15 0.14 S 1.78 400.00 399.99 343.99 0 45 N 67 58 W 0.03 0.19 O.ZO N 2.89 500.00 499.97 443.97 I 18 N 47 57 W 0.85 0.79 1.10 N 4.32 600.00 599.93 543.93 2 14 N 29 36 W 3.01 1-76 3-37 N 6.11 700-00 699.77 643.77 4 4 N 18 14 W 7.96 1.38 8.45 N 8.19 800.00 799.41 743.41 5 43 N 16 37 W 15.91 0.77 16.56 N 10.70 900.00 ,898.75 842.75 7 47 N 11 35 W 26.78 2.38 27.62 N 13.56 1000.00 997.59 941.59 9 31 1100.00 1095.90 1039.90 11 29 1200.00 1193.66 1137.66 12 45 1300.00 1290.85 1234,85 14 47 1400.00 1386.90 1330.90 17 19 1500.00 1482.01 1426.01 18 24 1600.00 1576.58 1520.58 19 53 1700.00 1669.77 1613.77 22 28 1800.00 1761.57 1705.57 24 11 1900.00 1852.28 1796.28 25 18 N 7 42 W 41.61 Z.lO 42.61 N 9 Z7 W 59.48 2°02 60.67 N 11 21 W 79.92 1.17 81.37 N 10 9 W 102.69 3.19 104.44 N 8 5 W 129.81 2.13 131.86 N 8 I W 160.11 0.35 162.47 N 9 40 W 191.87 2.84 194.57 N 9 30 W 227.17 2.48 Z30.29 N 8 51 W 265.89 2.07 269.44 N 8 39 W 307.03 0.72 311.03 ZO00.O0 1941.45 1885.45 29 16 2100.00 2026.68 1970.68 33 48 ZZO0.O0. Z108.61 2052.61 35 55 2300.00 Z188.47 Z13Z.47 37 52 Z400.O0 Z265.71 2209.71 41 14 2500.00 2.339.02 2283.02 44 11 2600.00 2.409.45 2353.45 45 54 gTo0.o0 Z478.64 2422.64 46 23 Z800.O0 2547.07 2491.07 47 18 2900.00 2614.58 2558.58 47 33 N 7 8 W 351.34 4.81 N 6 41 W 40Z.77 4.10 N 6 26 W 459.24 2.44 N 6 6 W 518.57 1.85 N 5 29 W 581.Z4 3.67 N 4 55 W 648.48 2.40 N 4 21 W 718.7B 1.05 N 3 29 W 790.37 1.72 N 0 18 W 862.99 1.40 N 0 49 E 936.66 0.97 3000.00 2682.21 2626oZ1 47 31 3100.00 2749.26 2693.26 48 13 3200.00 2815.53 2759.53 48 47 3300.00 Z881.06 28Z5.06 49 24 3~00.00 2945.61 2889.61 50 5 3500.00 3009.71 2953.71 50 10 3600.00 3074.66 3018.66 48 ~5 3700.00 3139.91 3083.91 49 58 3800.00 3203.74 3147.74 50 7 3900.00 3268.65 3212.65 49 27 N 1 54 E lOlO.Z7 N g 53 E 1084.46 N 4 4 E 1159.34 N 5 8 E 1234.86 N 5 14 E 1311.18 N 4 31 E 1387.91 N 3 54 E 1463.93 N 4 25 E 1539-70 N 5 6 E 1616.65 N 4 28 E 1692.70 0.00 N 0 0 E 0.14 S 68 3 W 0.85 S 77 4 W 1.79 S 85 31 W 2.89 N 86 5 W 4.45 N 75 42 W 6.98 N 61 6 11,,77 N 44 6 k 19.7Z N 3Z 51 W 30.77 N 26 9 W 15.83 W 45.46 N 20 22 W 18.55 W 63.44 N 17 0 W 22.39 W 84.39 N 15 2.3 W 26.90 W 107.85 N 14 26 W 31.25 W 135.51 N 13 20 W 35.53 W 166.31 N 12 20 W 40.53 W 198.75 N 11 46 W 46.71 W 236.98 N 11 28 W 52.91 W 274.59 N 11 7 W 59.38 W 316.65 N 10 49 W 1.08 1.07 0 1.2:6 1.93 0.75 0.99 1.83 2.33 0.79 355.78 N 65.65 W 361.79 N 10 27 W 407.66 N 71.78 W 413.93 N 9 59 W 464.61 N 78.36 W 471.18 N 9 34 W 524.42 N 84.92 W 531.26 N 9 12 W 587.58 N 91.35 W 594.64 N 8 50 W 655.30 N 97.46 W 662.51 N 8 28 W 726.05 N 103.24 W 733.35 N 8 6 W 798.06 N 108.31 W 805.38 N 7 44 W 870.94 N 110.54 W 877.93 N 7 14 W 944.71 N 110.17 W 951.11 N 6 39 W 1018.35 N 108.42 W 1024.10 N 6 5 W 109Z.48 N 105.35 W 1097.55 N 5 30 W 1167.22 N 100.79 W 1171.57 N 4 56 W 1242.52 N 94.75 W 1246.13 N 4 22 W 1318.54 N 87.47 W 1321.44 N 3 48 W 1395.05 N 81.31 W 1397.41 N 3 20 W 1470.85 N 75.49 W 1472.79 N 2 56 W 1546.45 N 70.23 W 1548.04 N Z 36 W 1623.14 N 63.68 W 1624.39 N 2 15 W 1698.96 N 57.43 W 1699.93 N I 56 W" ' L' :ONOCO TNC. 4[LNE POTNT UNIT L-5 q]LNE POINT 40RTH SLOPE~ ALASKA COMPUTATION DATE: 17 zY-90 , .,E Z DATE OF SURVEY: 2-MAY-90 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHNARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOR]Z. DEPARTURE ~ASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECT]ON SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH DEPTH DEPTH DEPTH DEG iO00.O0 3333.76 3277.76 48 54 1100o00 3399.80 3343.80 48 45 1200.00 3465.08 3409.08 49 51 ~300.00 3528.81 3a72.8! 50 31 1400.00 3593.28 3537.28 49 47 1500.00 3657.03 3601.03 50 59 ;600.00 3719.85 3663.85 50 27 ;700.00 3784.80 3728.80 49 10 ;800.00 3849.90 3793.90 49 39 ;900.00 3914.62 3858.62 49 42 ~000.00 3979.49 3923.49 49 28 ilO0.O0 4044.67 3988.67 49 ~200.00 4110.97 4054.97 47 54 i300.00 {178.45 4122.45 47 13 3400.00 {246.34 4190.34 47 23 ~500.00 {314.09 4258.09 47 14 ~600.00 4381.74 ~325.74 47 44 }700.00 4448.53 4392.53 48 23 ~800.00 4514.79 4458.79 48 35 ~900.00 {580.95 4524.95 48 33 5000.00 4647.21 4591.21 48 38 5100.00 4713.19 4657.19 48 53 5200.00 {778.98 4722.98 48 50 5300.00 {844.80 4788.80 49 5~00.00 {909.85 4853.85 49 51 5500.00 {973.63 4917.63 50 51 5600.00 5036.25 4980.Z5 51 38 5700.00 5097.89 5041.89 52 5 5800.00 5159.37 5103.37 51 59 5900.00 5222.14 5166.14 50 37 ?000.00 5285.38 5229.38 50 56 T100.00 5348.69 5292.69 50 3 r200.O0 5413.10 5357.10 49 55 r300.O0 5478.62 5~22.62 48 20 7400.00 5544.82 5488.82 48 55 7500.00 5610.09 5554.09 49 go 7600.00 5676.76 5620.76 47 23 7700.00 5743.97 5687.97 48 11 7800.00 5810.33 5754.33 48 39 7900.00 5876.98 5820.98 47 3 DEG HIN FEET OEG/IO0 FEET FEET FEET OEG MIN N 2 27 E 1/'68.59 N 1 49 E 18{3.65 N 2 15 E 1919.38 N 2 44 E 1996.44 N 3 26 E 2072.88 N 4 9 E Z149.91 N 4 39 E 2227.70 N 5 23 E 2303.70 N 6 15 E 2379.54 N 7 14 E 2455.63 N 7 53 E Z531.53 N 8 26 E 2607.10 N 5 21 E 2681.80 N 5 33 E 2755.56 N 6 26 E 2828.91 N 5 1E 2902.38 N 5 2 E 2976.00 N 5 35 E 3050.38 N 6 28 E 3125.20 N 7 46 E 3200.02 N 8 53 E 3274.63 N 8 36 E 3349.~3 N 8 12 E 3424.45 N 7 50 E 3499.48 N 7 46 E 3575.21 N 7 47 E 3652.00 N 8 I E 3729.72 N 7 32 E 3808.21 N 6 22 E 3886.93 N 6 12 E 3964.68 N 6 4 E 4042.04 N 5 4Z E 4119.37 N 5 38 E 4195.81 N 5 45 E 4271.28 N 5 42 E 4346.17 N 5 45 E 4421.86 N 5 50 E 4496.32 N 5 48 E 4570.30 N 5 57 E 4645.03 N 5 56 E 4719.49 2.94 1774.68 N 0.89 1849.74 N 1.49 1925.44 N 1.48 2002.43 N 1.31 2078.76 N 1.26 2155.63 N 3.44 2233.21 N 0.68 2308.95 N 1.23 2384.47 N 0.59 2460.16 N 0.45 2535.61 N 0.80 2610.66 N 1.32 2684.97 N 0.86 2758.46 N 0.60 2831.48 N 1.04 2904.64 N 0.92 2978.01 N 0.60 3052.12 N 0.82 3126.61 N 1.02 3201.01 N 0.80 0.62 0.38 0.98 1.14 0.80 0.85 1.60 1.12 0.51 0.66 1.62 1.04 0.75 0.85 1.17 0.34 0.71 0.58 3.35 52.47 W 1775o46 N I 42 50.05 ~ 1850.42 N I 33 47.33 W 1926.02 N I 24 44.01 W 2002.91 N I 16 39.88 W 2079.14 N I 6 W 34.76 W 2155.91 N 0 55 28.85 W 2233.39 N 0 44 · 22.20 W 2309.05 N 0 33 14.51 W 2384.51 N 0 21 W 5.55 W 2460.17 N 0 8 W 4.49 E Z535.61 N 0 6 E 15.32 E 2610.71 N 0 ZO E 24.35 E 2685.08 N 0 31 E 31.13 E 2758.63 N 0 39 E 38.81 E 2831.74 N 0 47. E ~6.34 E 2905.01 N 0 55 E 52.62 E 2978.48 N I I E 59.51 E 3052.70 N I 7 E 67.31 E 3127.33 N I 14 E 76.55 E 3201.93 N I 22 E 3275.12 N 87.43 E 3276.28 N I 32 E 3349.37 N 98.97 E 3350.83 N I 42 E 3423.87 N 109.97 E 3425.64 N I 50 E 3498.42 N 120.43 E 3500.50 N I 58 E 3573.68 N 130.72 E 3576.07 N Z 6 E 3649.99 N 141.13 E 3652.71 N 2 13 E 3727.21 N 151.8~ E 3730.30 N Z ZO E 3805.20 N 162.72 E 3808.68 N 2 27 E 3883.52 N 172.07 E 3887.33 N 2 32 E 3960.89 N 180.55 E 3965.01 N 2 37 E 4037.90 N 188.87 E ¢04Z.32 N Z 41 E 4114.90 N 196.82 E ~119.60 N Z 44 E 4191.03 N 204.34 E 4196.00 N Z 47 E 4266.19 N 211.8~ E 4271.45 N Z 51 E ~340.77 N Z19.30 E 4346.31 N Z 54 E 4416.15 N 226.86 E 4421.97 N 2 56 E 4490.30 N 234.37 E 4496.41 N Z 59 E 4563.96 N 241.89 E 4570.37 N 3 Z E 4638.38 N 249.54 E ~645.08 N 3 5 E 4712.51 N 257.31 E 4719.53 N 3 8 E CONOCO INC. MILNE POINT UNIT L-5 MILNE POINT NORTH SLOPEm ALASKA COMPUTATION DATE: 17 ~Y-90 ;E 3 DATE OF SURVEY: 2-MAY-90 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: SCHNA~TZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN 8000.00 5945.93 5889.93 46 23 8100.00 6014.53 5958.53 46 57 8200.00 6082.55 6026.55 47 23 8300.00 6150.07 6094.07 47 38 8400.00 6217.95 6161.95 47 2 8500.00 6Z85.TZ 6Z29.72 47 37 8600.00 6352.67 6296.67 48 7 8700.00 6419.44 6363.44 48 15 8800.00 6685.58 6429.58 48 58 8900.00 6550.63 6694.63 49 48 9000.00 6615.41 6559.41 49 9 9100.00 6680.88 6624.88 49 6 9200.00 6766.52 6690.52 49 4 9300.00 6811.53 6755.53 49 49 9400.00 6875.86 6819.86 49 55 9500.00 6940.27 6884.Z7 69 55 9600.00 7004.55 6948.55 50 8 9700.00 7068.34 701Z.34 50 33 9800.00 7131.71 7075.71 50 55 9900.00 7194.58 7138.58 51 12 0000.00 7Z56.99 7Z00.99 51 32 0100.00 7319.0Z 7Z63.0Z 51 48 0200.00 7381.28 7325.28 51 1 0300.00 7443.80 7387.80 51 50 0400.00 7504.79 7448.79 52 40 0500.00 7565.45 7509.45 52 40 0526.00 7581.22 7525.22 52 40 DEG MIN, VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG N 5 41 E 4,791.86 N 5 41 E 4864.56 N 5 38 E 4937.81 N 5 36 E 5011.51 N 5 38 E 5084.89 N 5 48 E 5158.35 N 5 33 E 5232.57 N 4 5 E 5306.99 N 4 6 E 5381.98 N 4 3 E 5457.93 0.70 0 0.52 0.33 0.55 0.56 1.07 0.84 1.09 0.66 4784.58 N 264.58 E 4791.89 N 3 10 E ¢856.98 N 271.77 E 4864.57 N 3 12 E 4929.93 N 279.00 E 6937.82 N 3 14 E 5003.33 N 286.22 E 5011.51 N 3 16 E 5076.4Z N 293.37 E 5084.89 N 3 18 E 5149.58 N 300.70 E 5158.35 N 3 21 E 5223.48 N 308.19 E 5232.57 N 3 23 5297.67 N 316.28 E 5306.99 N 3 24 E 5372.49 N 319.60 E 5381.98 N 3 26 E 5448.26 N 325.02 E 5457.93 N 3 25 E N 3 49 E 5534.10 N 3 15 E 5609.69 N I 58 E 5685.12 N I 51 E 5761.08 N 2 20 E 5837.62 N 3 22 E 5914.11 N 3 50 E 5990.71 N 4 12 E 6067.72 N 3 38 E 6145.06 N 3 14 E 6222.83 1.11 1.72 0.59 0.91 0.97 0.63 0.45 0.47 0.85 0.68 5524-24 N 330.25 E 5534.10 N 3 25 E 5599.68 N 335-10 E 5609-69 N 3 25 E 5675.05 N 338.34 E 5685.13 N 3 25 E 5750.99 N 340.86 E 5761.08 N 3 Z4 E 5827.50 N 343.47 E 5837.62 N 3 22 E 5903.90 N 347.31 E 5914.11 N 3 22 E 5980.35 N 35Z.16 E 5990.71 N 3 22 E 6057.17 N 357.56 E 6067.7Z N 3 23 E 6134-33 N 363-00 E 6145-06 N 3 13 E 6211.97 N 367.60 E 6222.83 N 3 23 E N Z 57 E 6300.97 N 2 52 E 6379.40 N 3 5 E 6457.65 N I 58 E 6535-68 N I 16 E 6614.86 N I 16 E 6694.31 N I 16 E 6714.97 0.36 0.34 0.43 1.84 0.00 0.00 0.00 6289.99 N 371.81 E 6300.97 N 3 23 E 6368.33 N 375.78 E 6379.60 N 3 23 E 6446.47 I4 379.81 E 6457.65 N 3 Z2 E 6524.46 N 383.27 E 6535.68 N 3 22 E 6603.63 N 385.21 E 6614.86 N 3 20 E 6683.1Z N 386.97 E 6694.31 N 3 19 E 6703.78 N 387.43 E 6714.97 N 3 18 E CONOCO INC. MILNE POINT UNIT L-5 MILNE POINT NORTH SLOPE, ALASKA COMPUTATION DATE: 1"/ )~Y-90 ,, TRUE SUB-SEA COURSE EASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN DATE OF SURVEY: Z-MAY-90 KELLY BUSHING ELEVATION: 56.00 FT ENGZNEER: SCHNARTZ' INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/14EST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG HIN 0o00 0.00 -56.00 0 0 1000o00 997.59 9¢1.59 9 31 ZO00.O0 1941.45 1885.45 29 16 3000.00 268Z.21 2626.21 47 31 4000000 3333.76 3277.76 48 54 5000.00 3979049 3923.49 49 28 6000.00 4647.21 4591.21 48 38 7000o00 5285.38 5229.38 50 56 8000.00 5.945.93 5889.93 46 23 9000.00 6615.41 6559.41 49 9 0000o00 7256.99 TZO0.99 51 32 0526°00 7581.22 7525.22 52 40 N 0 0 E 0.00 N 7 42 ~ 41.61 N 7 8 14 351.34 N I 54 E 1010.27 N 2 Z7 E 1768.59 N 7 53 E 2531.53 N 8 53 E 3274.63 N 6 4 E 404Z.04 N 5 41 E 4791.86 N 3 49 E 5534.10 N 2 5T E 6300.97 N I 16 E 6714.97 0.00 2.10 4.81 1.08 2.94 0 0.80 0.64 0 .TO 1.11 0.36 0.00 0.00 N 0o00 E 0.'00 N 0 0 E 42.61 N 15.83 14 45.46 N 20 Z2 14 355.T8 N 65.65 14 361.79 N 10 27 14 1018.35 N 108.42 kl lOZ4.10 N 6 5 14 1774.68 N 52.4T 14 1775.46 N I 42 14 2535.61 N 4.49 E Z535.61 N 0 6 E '") 327S.IZ N 87.43 E 3276.28 N I 32 E ./r 4037.90 N 188.87 E 4042.3Z N Z 41 E 4784.58 N 264°58 E 4791.89 N 3 10 E 5524.24 N 330.Z5 E 5534.10 N 3 25 E 6Z89o99 N 371.81 E 6300.9T N 3 23 E 6~03.T8 N 387.43 E 6714.gT N 3 18 E AOGCC GEOLOGICAL MATERIALS iNYENTORY LiST COMPLETION OATE / ~ ~ -~ ? i ?~ CO. CONTACT ~ ~, ~ ~ o cnec~ on or list tiara as it is received.*list received date for 407. if not re~,uired list as NR cored intc~a,!~ core analysis ~1 d~ ditch intc~ais digital data , , , ~~ ~'~ [ LOG TYPE I RUN INTERVALS SCALE .... NO. {to the nearest foot) , ,, 12! ' [ [ [[ , , , 131 ,,,i al ........ , , , ii6] I II !.................. ~ ...... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCAT:[ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation shutdown Re-enter suspended well Alter casing __ Repair well Plugging __ Time extention __ Stimulate Change approved program ~ Pull tubing __ Variance __ Perforate ~ Other X Replace ESP, 2. Name of Operator 5, Type of Well: 6, Datum elevation (DF or KB) Conoco Inc. Development .. x 56' KDB feet 3. Address Exploratory __ 7, Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic. Milne Point Unit Service 4. Location of well at surface 8. Well number 2055' FNL, 420' FWL, Sec. 8, T13N, R10E, U.M. L-5 At top of productive interval 9, Permit number 4086' FSL, 783' FEL, Sec. 5, T13N, R10E, U.M. 90-39 At effective depth 10, APl number 4578' FSL, 805' FEL, Sec. 5, T13N, R10E, U.M. 50- 029-22030 At total depth 11, Field/Pool 4649' FSL, 807' FEL, Sec. 5, T13N, R10E, U.M. Kuparuk River Field 12. Present well condition summary Total depth: measured 10526' feet Plugs (measured) true vertical 7581' feet Effective depth: measured 10437' feet Junk (measured) true vertical 7528' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 82' 13-3/8" 485 sx Permf C 115' 115' surface 6011' 9-5/8" 400 sx Class G 6044' 4676' Intermediate 1257 sx Arctic Set IV Production 10493' 7" 435 sx Class G 10526' 7581' Uner Perforation Depth: measured 9809-9913'; 9949-9964'; 9980-9999'; 10024-10098' ~ '~ ~ E IV ~ D true vertical 7138-7303'; 7225-7234'; 7244-7256'; 7272-7319' Tubing (size, grade, and measured depth) 2-7/8", L-80, 9640' Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 517'; Otis RDH Pkr. @ 538' 13. Attachments Description summary of proposal X Detailed operations program 14. Estimated date for commencing operation 15. Status of well classification as: May 1, 1991 16. If proposal was verbally approved Oil X Gas Suspended Name of approver ~ Date approved Service 17. I hereby cel~ify that~e foregoing is true and correct to the best of my knowledge. / Signed ~,,,.,,il[~ /'~/C)/~/ J.H. Andrew Title Production Engineer Date April 2, 1991 / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprovai No. Plug integrity BOP Test ~ Location clearanceL Mechanical Integrity Test __ Subsequent form required 10-~'~ ~""~' "'J ..- ('/',/~) ~oe~ ~ eC(~ ORIGINAl. SIGNED BY Approved by order of the Commission LONNIF,, C. SMITHC°mmissi°ner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point Unit L-5 Well ESP Replacement Procedure Summary 1. MIRU workover rig. 2. Kill well by circulating hole full with 10.0 ppg NaBr/NaCl brine. Spot salt-based LCM pills, if necessary, to control fluid losses. 3. ND tree. NU and test BOP's. 4. Shear open annular vent valve by pressuring up on the 2-7/8" tubing x 7" casing annulus to 3500 psig with the valve closed. 5. MU landing joint to tubing hanger. PU 20,000# above pipe weight to release Otis RDH retrievable packer at 600'. 6. POOH with 2-7/8" production tubing and ESP. 7. TIH with sand bailer. Tag proppant and bail to clear perf interval, if necessary. 8. MU new ESP assembly and TIH on 2-7/8" production tubing. 9. MU an Otis RDH packer with annular vent valve. Install a 2- 7/8" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. 10. Land production tubing hanger and freeze protect annulus. 11. RU wireline and set a plug in an Otis X nipple located below the production packer. Pressure up against the plug to set the packer. POOH with plug and RD wireline. 12. Pressure test packer and annular vent valve by pressuring up on annulus to 500 psig. 13. Freeze protect tubing. ND BOP's, NU and test tree. 14. RDMO workover rig. RU and test flowline. Return well to production. SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOL(X~Y CORPORATION HOUSTON. TEXAS 7725!-2175 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger ~SE REPLY TO SCHLUMBERGER WELLSERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: BernSe/Shelley Gentlemen: Enclosed ore 2 RI, prints of the Company CONOC0, Inc Perf Rec. Run 1:10/19/90 Well Hilne Point Ilnit 1.-5 Field .. Milne Poinl; .. Additional prints are being sent to: I BL prints CONOCO, Inc. 600 North Dairy Ashford . . Houston, TX 77079 A~[n: George. Lamb - OF 2018 PER County Nmrth Slope. State _l__B2,_prints, 1RF Sepia 1000 South Pine Alaska Ponca City, OK 74603 Attn: Log Library on: I BL prints, 1RF Sepia OXY U.S.A., Inc. .6 Desta Drive Midl~nd~ TX 79710 At~a: John Carrol *(915/685-56OO) _l_~rints, 1RF Sepia __Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn: .Priscilla MacLeroy prints prints 1 BL Al; 1RF Sepia Oil & Gas Conservat on sion 1 Porcupine Drive Ae, AK 99501 tn: John Bo' ~ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints David M, Saalwaechter DISTRICT MANAGER Sw~- ! 327-F STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION. FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdoWn __ Re-enter suspended well __ . Plugging m Time extension __ Stimulate ~ Pull tubing __ Variance ~ ' Perforate __~ Other 2. Name of Operator J CONOCO INC. 3. Address P_O_ ROX' .3Zt~3~&~_ PRIIDHOF RAY. AK gg73 4. Location of well at surface 420' FWL,2055' FNL, SEC 8, T13N, RIOE,UM. At top of productive interval 783' FWL, 4096, FSL, SEC .5, T13N,R10E,Ut4. At effective depth 806' FWL, 4580' FSL, SEC 5, T13N,R10E,UM. At total depth 808' FWL, 4668' FSL, SEC 5, T13N,R10E,UH. 5. Type of Well: Development -.,X, Exploratory ~ Stratigraphic ~ Service __ 6. Datum elevation (DF or KB) 56' KB MSL feet true vertical 175gl~., feet 7. Unit or Property name HILNE pOINT UNIT 8. Well number L-5 feet 9. Permit number 90-39 10. APl number SO-- 029-22030 11. Field/Pool KUPARUK RIVER 12. Present well condition summary Total depth: measured plugs (measured) Effective depth: measured 10439 ' feet true vertical 7529 ' feet Casing Length Size Structural Conductor 80' 13 3/8" Surface 600g' g 5/8" Intermediate Production 10,493' 7" Liner Perforation depth:measured NONE true vertical Tubing (size, grade, and measured depth) NOT APPLICABLE Packers and SSSV (type and measured depth) NOT APPL I CABLE 13. Attachments Description summary of proposal__ Junk(measured) NOT APPLICABLE Cemented Measured depth True vertical depth TO SURFACE 115' 115' 470 BBL CLASS 'E' 6044' 4676' 87 BBL CLASS 'G' 10,528' 84 BBL CLASS 'G' 10,528' 7582' RECEIVED .. OCT 2 41990 Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 115. status of well classification as: OCTOBER I6. ]990 16. if proposal was verbally approved LONNIE SMITH 10/19/90 Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~,~?~ Title SENIOR PRODUCTION FOREMAN ~-, u ~' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so re presentative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- , Original Signed By David W. Johnston Approved by order of the Commission Oil X Gas __ Suspended __ Approved Copy Returned Commissioner I Approval No. ¢~_ '7 ¢ "7 .Form 10-403 Rev 06/15/8~ SUBMIT IN TRIPLICATE /,~ MPU L-5 WELL Milne Point Unit PROPOSED COMPLETION PROCEDURE AFE No. 10-61-1193 10/9/90 - CVL Objective. Clean wellbore fluids; perforate the LK-3, LK-2, LK-1, and LZ sands; fracture stimulate; run an ESP and postpone start-up until surface equipment hook-up is completed. Surface Location- 2055' FNL & 420' FWL of Sec. 8, T13N, RIOE Depths' All depths are measured from original RKB (49.0') and open hole logs dated 4/19/90. Casinq- Surface: 9-5/8", 36 #/ft, J-55, btrs. set @ 6044' Production: 7", 26 #/ft, L-80, btrs. set @ 10,528'. Capacity = 0.0382 bbl/ft Drift ID = 6-.276" Burst Pressure = 7240 psi Tubinq/workstr- 2-7/8", 6.5 #/ft, L-80, EUE 8rd (approx. 10,100' required) Capacity -- 0.00579 bbl/ft tubing; 0.0302 bbl/ft annulus ID = 2.441"; Drift ID = 2.347" Burst Pressure -- 10,570 psi Torque (ft-lb): Min = I730; Optimum-- 2300; Max = 2880 Misc- PBTD = 10,386' RA Tag @ 8947' Pore pressure = 9.6 ppg equivalent (3600 psi) Fluid in well = 10.2 ppg NaBr/CI Proposed completion fluid : tl.0 ppg NaBr/C1 (10 deg F TCT) Max Angle = 52 deg; Angle through pay : 52 deg CBT/CET run on 5/2/90 indicated good bond ECEIVED OCT 2 1990 Oil & Gas Cons. ~ Ancho .ra . Proposed Hydraulic Fracturinq Procedure' . Spot seven 500 bbl frac tanks on location. Elevate the rear of the tanks approximately 8". Visually inspect the interior of the tanks for cleanliness. DO NOT ENTER THE TANKS. Fill five tanks with 440 bbls clean injection water. Check pH of injection water in each tank and neutralize if necessary. Fill the sixth and seventh with 260 bbls filtered 11.0 ppg NaBr/Cl completion fluid w/ 4 gal/lO0 bbl Unitreat 3900 biocide/inhibitor for flush. The water/brine should be heated and filtered to 10 microns absolute with a hot oil truck and maintained at 75 to 80 degrees F to insure proper hydration of the gelling agent. Water from the central facility, carried in clean transports is acceptable. 2. Rig up Dowell Schlumberger to perform the frac treatment. NOTE: a. Use of threaded connections, crossovers, swedges, etc. in the treating line is not acceptable. b. Use two in-line densitometers. c. Use two shut-off valves on the wellhead. d. Set the backup pumps for the crosslinker and diesel. ee Standby pumps (50%) are required. These pumps must be manned and primed to come on line immediately if needed. A standby blender should be hooked up and ready to come on line in case of primary blender failure. f~ BOP saver installation shall be coordinated by Conoco and DS personnel on-site prior to frac RU. Insure that "donut" is butted against 4" pipe rams prior to pumping. ge Tank bottoms are included in the volumes listed. Plan for 75 bbl tank bottoms. h, Use the in-line densitometer during the treatment. rate, pressure, and density on a chart. Record Take samples of the crosslinked gel during the treatment. Place these samples in a bath at 168 deg F. Note the actual break time. Note the pre-pad is not crosslinked and does contain diesel. j · Shut down after pre-pad for meter to tank verification and 15 minute pre-job ISIP. k. DO NOT OVERDISPLACE THE TREATMENT UNDER ANY CIRCUMSTANCES. 0 Batch mix 2200 bbl gelling agent at 50 lb/lO00 gal with additives. The pre-Pad consist of non-crosslinked gel {no diesel}. Particulate fluid loss additive (413#/1000 gal} should be added in the pre-pad and pad fluids Page 4 Proposed ESP and Tubinq Runninq Procedure: · . MU ESP assembly on 2-7/8" tubing as illustrated on the attached Otis completion guide. Strap and record the length of each component. Run a standard Centrilift motor centralizer for 562 Series motors and 7", 26 #/ft casing on the bottom of the motor. ~}o~ RIH w/ ESP no faster than 30' per minute. RIH w/ sliding sleeve in o~ ~ Maintain sufficient hydraulic pressure on the control line while RIH to maintain valves in the open position. Attach two cable bands per joint. Attach additional bands above and below each cable splice. Set the bottom of the motor at 9775'. . Locate packer and safety valves such that the tubing retrievable SCSSV is at a depth of 500' or greater. Packers should be pinned to begin setting at approximately 1100 psi. · Pump 55 bbl of diesel down annulus for 1800' of freeze protection prior to setting packer. · RU slickline and RIH w/ plug and set in "X" nipple located below packer. Pressure up to 1000 psi. Set packer by gradually increasing pressure from 1000 psi to 2500 psi in 500 psi increments. Retrieve plug and POOH. RD slickline. e Pump 11 bbl of diesel down tubing for 1800' of freeze protection prior to closing SSSV' s. 0 Bleed off control line pressure to close the annular vent valve and SCSSV. Pressure test the packer and vent valve system w/ 500 psi of annular pressure for 10 minutes. Bleed off pressure. . ND BOP's. NU tree. RD and move to next well. Await surface facilities connecti on for producti on. Prepared by- C. Van Lineberg~P Sr. Prod· Engineer Reviewed by: Marc Shannon Supervising Prod. Engr. Approved by' D. E. Howell Producti on Supt. CC' DEH, PMS, MPU Sr. Fm. (2), CVL, Original to File- L-5 Well File Page 6 PREPARED POR: Co_noc~__ /.nc. ~C~ OF: ~,r. Van Linemer~er Frown NAME: Milne Point ~ NAME: L P-ad "ESI" (ka~ple~ions CASING: 7" ~9 LB L-80 BTC TU]~I~G: 2-7/8" 6.4 LB ~3 8RD x 2-3/8" 4.6 LB ~J 8RD REFER~: 432/1001/01/90 [l~t~: ~ 17, 1990 (907) 261-7780 4. --16 , 8. 9. · t7 ~8 2-7/8" 6.4 lb ~JE T~bir~ ~ su~pli~ EleCtric ~-~h~. - S~ %2 ~. 0.~9" W~ ~ X ~' ~ 316 ~~ (P~ 22 ~ 31060) 2-7/8" 2.3~" ~ "~ ~ ~ ~1-75, 2-7/8" 6.4 ~8~. ~. ~ ~ ~000' (P~ 778 ~ 233~-E) 2-7/8" 6.4 ~ ~ 8~ 2-?/8" ~ 8 ~ x 2-3/8" 2.44" 3. 668" BZW Power Cable Feed Thru For No. 2 9nur~ Cable. 100 AMP, 2400 Volts, 4 KV Ra~. Field At~a~e Male ~ and Power Feed Thru wir, h a 20' Electric Cable Pig-Tail. (P/N 1~- cs 225) 2-7/32"-14 UNS-2 X 2-3/8" ]~1' 8Rd Bx.? (~,/~ ~ o 6?22) Otis Annular Vent Valve 3,000 psi W.P. Set'~tr~ De~h 540', 2-3/8" EU 8~ BxP (P/N 78 A~ 2001) 10. 2-3/8" 4.6 Lb EU 8 R~ PU~ Joint P-lO5 2.313" 4.76" 7. O ' 2.44" 3.668" 2.44" 3.~:~" 2.25" 6.0m .6' 23' 1.97" 2.62" 1.8' 3.09" 3 · 69" 3.06" 1.83" 1.99" 2.61' 8.0e CENT -"'.IFT EQUIPMENT QUC' ATION A 13aker l'~ugnes comma, ny 200 W, Stuar~ Roosa Or, · Ciaremore, Oktal~oma 74017 · (9~ 81341.9600. 8o03- 90 0TAr~ON NO. b2~13~06 Z2-315~ Z~ENTEO Sy ' S. Ee'~l:e: - ' --- I I , II CAPACITY TO+AL HEAD ~ I=REOUENCY 500' ' 7065 't 59.8 ' - 700 /o~ i ' ~.~' ' - 900 CONOCO _ ATrN: ' ' VaSt L£neberger - W~L~'.~AME: L-5 ' ' ' FIELD NAME: "AUparum ' L(~cATION: Dea~thorse, AK · __ i i i , il___ ! SP. GR. PERF$ ]~elow p. cr, . ~.H.T. 175 i~RIMARY VOLTAGE 480 G.O.m. 145 - C~ING ~.~. 7;' - MOTOR H.P. ~00 VOLTAGE ~5 ~TING SERIES 562 PUMP STAGES ~ TYPE FO-650 -2-~' SERIES ~00 ~UMP ~N rAKE SERIES PUMP OSCMRG. $ERIE~ GAS SEPARATOR SERIES : ~00 · ~AL SECTION SERi~S 5 [~ =CWE~ CABLE AWG FLAT CABLE 5ERIE~ ~ FLAT GUANOS ~~~ &dapcor 400 x 513 CAI~L~ BANDS SWAGED NIPPLE CHECK VALVE 0RAIN VALVE EQUIPMENT COATING: WEIGHT AMPERAGE 27 MODEL ~ LENGTH ~sG. NO. L2 MODEL ~'~ L -~NGTH MOOEL LI;;NGTH MODEL LENGTh ~QOEL F[S-X LENGTH , _ i i LENGTh II SETTING DEPTH 7141 ,,-0% 50 REG. SURF. ACE. VOLTAGE ~_200 REQUIRED EVA FRICTION LOSS T.D.H. Vat't NO. PCS. 1 12.0 NO. PCS. !9.2 842 CONN. 2 A~MOR 582 75 263 ACCESSORIES INCLUDE; OVERLOAD ~. AUTO RESTART VAR~ABLP_ FREQUENCY CONTROLLER: TRANSFOR MENS SIZE PRIMARY TAPS VARIABLE FREQUENCY TRANSFORMER JU NOTION i~OX WEN TED-SAF ETYI TUBING HEAD PMD Dowrtt3o ie ? acka~;e PRD Inductor Package CONOCO Mods VOI. TAGE ; ' ' ' UNDERCURRENT S,D. ~ RECORDING AMMETER " } LIGHTING ;,~RESTER" eTHER ~CS TYPE SECONDARY TAPS KVA KV ~.30 CABLE GUIDE CABLE REEL NO. REEL SUPPORT SHIPPtNG CA,.%E QTY. 5~PP~NG CASE QTY. SHIPPING CAE~E QTY. SHIPPING CASE QTY. SIZE NOTE: SERVICING EQUIPMENT MAY I~IE RETURNS0 FOR !00% CREDIT WITHIN 6 MO. SUBJECT TO A REPAIR CHARGE ECIUAL TO 25~,, OF THE LI:~T PRICE. · . . §4.6 Hz 59.8 Hz ~UNUCU HILNE POINT VSCSystemPerlormanceL_5 ~ ~~ [_!?_ ..f"_.^ I PUMP ,. '~ 2~35' FC6~O MOTOR (fi(: Hz ra:ingl ,-. 5;62 s~.rle~ I00 flO 1205 vol: -1El ami) ' o r~ r a z, t~ " 200 3O0 eng'neered by: [ · )0 500 8EH O. ~3,='IJLO 6~,C, I TOO 800 '.'K'O lOC. O 10,3 ESP .SI21flG F,.nl::t tlR. VAN L NEBER,3ER 1200 13~0 BPD I da=e: 1. lhu,.~g'' .J ~ , .,_ASKA OIL AND ~'AS ~;~NS~-R~/ATI'ON CON ..... SSION REPOF:R' OF SUNDRY WELL OPEF TiON 1. Operations perfOrmed: Operation shutdown ~ Stimulate ~ Plugging Pull tubing __ Alter casir~ __ Repair well __ 2. Name of Operator CONOCO ]'NC. 3, Address P.0. BOX 340045~ PRUDHOE BAY, AK 4. Location of well at suflace 420' FWL, 2055' FNL, SECTION 8, TWP At top of productive interval At effective depth GYRO SURVEY At total depth NOT PRESENTLY AVAILABLE Perforate __ Other --X I5. Type of Well: Development __~ Exploratory __ Sl. ratigraphic ~ 9973 3 Ser,~c~ __ 13N, RIOE, UM 6. Datum elevation (DF or KB) ~ 56 KB MRl 7. Unit or Property name HILNE POINT UNIT 8'.' We~l number feet 12. Present well condition summary Total depth: measured true vedical Effective depth: measured true vedical Casing Length Structural Conductor 80' Surface 6009' Intermediate Production [ 0493 ' Uner Perforation depth: measured 10550' 7618' 10439' 7554' N/A feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 13-3/8" TO SURFACE 9-5/8" 519 BBL CLASS E 83 BBL CLASS G 7" ..... 84-BBL CLASS G 9. P~r~t number/approval number 10. APl-huSh-her 50- 029-22030 .... 11. Field/Pool KUPARUK RTVFR Measured depth True vertical depth 115' 115' 6044' 4680' 10528' 7606' true vertical Tubing (size. grade, and measured depth) *NOTE: TVD' S ARE BASED Packers and SSSV (type and measured depth) 13, Stimulation or cement squeeze summary IntervaJs treated (measured) N/A Treatment description including volumes used and final pressure ON MWD DIRECTIONAL DATA, NOT FROM GY 14. Prior to well operation N/A Subsequent to operation Representative Daily Average Production or Injection Data Oil-BM Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments FO'I o~ Copies of Logs and Surveys run~,~_u Daily Repod of Well Operations~ 16. Status of well classification as: Oil __ Gas __ Suspended Service 17. I hereby cedify thai the foregoing is true and correct to the best of my knowledge. ~/~ Title SENIOR DRILLING FOREMAN Signed Form 10-404 Rev 05/15/88 Date 05/07/90 · · SUBMIT IN DUPLICATE Kuparuk River River Field - North Slope Borough, Alaska W.I. 100% Milne Point Well Number L-5 CONFIDENTIAL API No. 50-029-22030 Alaska Permit No. 90-39 Location: 420' FWL, 2055' FNL, Section 8, TWP 13N, R10E, UM APRIL 10, 1990 INSTALL HYDRILL AND HOOKUP DIVERTOR LINES. NU RISER AND FLOWLINES, FUNCTION TEST HYDRIL, INSTALL MOUSEHOLE. PU BHA, ORIENT MOTOR AND MWD. DRLD F/l12' TO 947'. POOH CHANGE MWED, ORIENT SAME, RIH. DRLD F/947' TO 1630'. DAVID MOUNTJOY Daily Mud Cost: Daily Cost: $ 3,999 Cumulative Mud Cost: $ 3,999 $ 130,553 Cumulative Cost: $ 130,553 APRIL 11, 1990 DRLG F/1630' TO 2730'. SHORTTRIP 15 STDS. DRLG F/2950-3806'. SHORT TRIP 12 STDS. DRLG F/3806'-4088'. DAVID MOUNTJOY (NO PROBLEMS-NO FILL). (NO PROBLEMS-NO FILL). Daily Mud Cost: $ Daily Cost: $ 970 Cumulative Mud Cost: $ 4,976 41,035 Cumulative Cost: $ 171,588 APRIL 12, 1990 DRILG F/4088'-5006'. SHORT TRIP 10 STDS. (NO HOLE PROBLEMS--NO FILL). DRLG F/5006' TO 5963'. DAVID MOUNTJOY Daily Mud Cost: $ 2,414 Cumulative Mud Cost: $ 7,390 Daily Cost: $ 42,673 Cumulative Cost: $ 214,261 APRIL 13, 1990 DRILG F/5963' TO 6064'. NOTE: LOST 100+ BBLS OF MUD AT 6025'. SPOTTED FINE MICA AND MEDIUM WALNUT. NO MORE LOSSES. FRACTURE??? CIRC AND COND MUD, PUMP DRY JOB. POOH (SLM-NO CORR), TIGHT SPOT AT 945' AND 900', WORKED THRU TIGHT SPOT, RIH TO 6064'--N0 FILL. CALC DISP = 53 BBLS, ACTUAL DISP = 57 BBLS. CIRC AND COND MUD--NO LOSSES. POOH, L/D BHA, CLEAR RIG FLOOR. R/U CSG CREW AND HOLD PRE-JOB SAFETY MEETING. RUN 64 JTS OF 9-5/8", J-55, 36#, BUTT CSG. TIGHT SPOT 6525'. CALC PU = 120K, ACTUAL = 175K. M/U CIRC SWEDGE AND CBU WHILE WORKING PIPE TILL PU = 125K. RUN AN ADDITIONAL 66 JTS OF CSG (130 TOTAL). RUNNING SMOOTH. DAVID MOUNTJOY Daily Mud Cost: $ Daily Cost: $ 7,231 Cumulative Mud Cost: $ 14,620 45,045 Cumulative Cost: $ 259,306 APRIL 14, 1990 RAN REMAINING 20 JTS OF 9-5/8 CSG (150 JTS TOTAL). M/U MANREL HANGER AND LANDING JT. CIRC ONE HOLE VOLUME + 25% (7200 STKS). PUMPED STAGE ONE OF CEMENT JOB. 20 BBLS H20 + 100 BBLS 10.5 PPG SEPIOLITE + 20 BBLS H20 269 BBLS 11.8 PPG ARCTIC SET IV. 71 BBLS 15.4 PPG "G" + .0532 D024 + 0.002 D046 + 0.01 SOO1. UNSU7CCESSFUL ATTEMPTS TO HYDROSTATICALLY ACTIVATE HOS CEMEMTER DV TOOL. DROP BOMB AND OPENED DV TOOL WITH 1000 PSI CIRC THRU DV TOOL. PUMPED STAGE TWO OF CEMENT JOB: 15 BBLS H20 + 90 BBLS 10.5 PPG SEPIOLITE + 15 BBLS H20 201 BBLS 11.8 PPG ARCTIC SET IV. 16 BBLS "G" + 0.0532 D024 + 0.002 D046 + 0.01 SOO1. LANDING JT, R/D CSG CREW AND CLEAR OFF RIG FLOOR. N/D FLOWLINE, RISER, HYDRILL AND DIVERTER. M/U SPEED HEAD. N/U BOP STACK AND ASSOC EQUIP. TEST BOP'S. STRAP AND M/U BHA, M/U AND ORIENT MWD. DAVID MOUNTJOY Daily Mud Cost: Daily Cost: $ 6,114 Cumulative Mud Cost: $ 20,734 $ 236,467 Cumulative Cost: $ 495,773 APRIL 15, 1990 FINISH ORIENTING MWD AND M/U BHA. RIH AND TAG CMT AT 1920'. DRLG CMT AND DV TOOL AT 1924'. RIH AND TAG CMT AT 5936'. CIRC AND COND MUD (4500 STKS). PRESS TEST CSG TO 1750 PSIG FOR 30 MIN--OK. DRLG CMT AND FLOAT EQUIP. DRILLED 10' NEW FM TO 6074' AND PERFORM 13.8 PPG LEAK OFF TEST. DRLG F/6074' TO 7064'. SHORT TRIP TO SHOE (NO HOLE PROBLEMS--NO FILL). DRLG F/7064' TO 7476'. JOE POLYA Daily Mud Cost: $ Daily Cost: $ 2,879 Cumulative Mud Cost: $ 23,613 57,168 Cumulative Cost: $ 552,942 APRIL 16,. 1990 DRLG F/7476' TO 8009' (REAM EVERY JT). STD SHORT TRIP (NO HOLE PROBLEMS--NO FILL). DRLG F/8303' TO 8762' (REAM EVERY JT). 10 STD SHORT TRIP (NO HOLE PROBLEMS--NO FILL). DRLG F/8762' TO 9082' (REAM EVERY JT). JOE POLYA Daily Mud Cost: $ Daily Cost: $ 5,312 Cumulative Mud Cost: $ 28,925 44,715 Cumulative Cost: $ 597,316 APRIL 17, 1990 DRLG F/9082' - 9554' (REAM EVERY JT.) 10 STD SHORT TRIP (NO HOLE PROBLEMS -- NO FILL). DRLG F/9601' - 9824' (REAM EVERY JT. ) SHORT TRIP TO SHOE. NOTE: WORKED THRU TIGHT SPOTS AT 8150', 7475', & 7300'. NO INDICATIONS OF THESE TIGHT SPOTS WHILE RIH. CALC HOLE FILL = 26.5 BBLS, ACTUAL - 28 BBLS. Daily Mud Cost: $ 6,943 Cumulative MuG Cost: ' ~ 35,868 · uas Con~,, ",., ~llchora~a Daily Cost: $ 47,786 Cumulative Cost: $ 645,102 APRIL 18, 1990 REAM F/9730' TO 9824'. Daily Mud Cost: $ Daily Cost: $ DRLD F/9824' TO 10,520'. 2,807 Cumulative Mud Cost: 44,215 Cumulative Cost: $ 38,676 $ 689,317 APRIL 19,1990 CIRC BOTTOM UP. POOH TO 9 5/8" SHOE. CUT AND SLIP BRLG LINE. RIH TO 10,433' TO 10,520'. CIRC & COND. RU SHCLUMBERGER. LOG DIL- LDT-CNL-NGT-SP, LOGGER TD 10,522' . RD SCHLUMBERGER, DROPPED IDEA OF CORES DO TO TIGHT HOLE. Daily Mud Cost: Daily Cost: $ 2,899 Cumulative Mud Cost: $ 41,575 $ 221,440 Cumulative Cost: $ 910,757 April 21, 1990 BREAK DOWN TURBINE. MU BHA RIH TO 10,425'. WASH AND RAM 10,425' TO 10,520'. DRLD 10,520' TO 10,550'. CIRC AND COND HOLE. POOH LD DP. CHANGE TOP RAMS TO 7", BREAK KELLY, CUT SLIP DRLG LINE. POOH LD DP AND BHA, PULL WEAR RING. RU CSG CREW. RUN 7" CSG. Daily Mud Cost: Daily Cost: $ 1,447 Cumulative Mud Cost: $ 43,021 $ 264,834 Cumulative Cost: $1,175,591 APRIL 22, 1990 CLEAN PITS AND FREEZE PROTECT L-5, LAYDOWN KELLY, RELEASED RIG TO STANDBY @ 0930 4/22/90. STANDBY WHILE ROAD WAS BEING FINISHED. RELEASED RIG @ 2400 HOURS 4/22/90, WITH 9500 GALS OF DIESEL. Daily Mud Cost: $ Daily Cost: $ Cumulative Mud Cost: $ 43,021 55,153 Cumulative Cost: $1,296,686 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 May 5, 1990 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 301 Porcupine Drive Anchorage, AK 99501 Re: Letter of Application Dear Mr. Minder: I am requesting shutdown of well operations for the L-5 well until we can compact the new pad enough to get a workover rig on location and begin completion operations. This will happen later in the summer. Included is the Form 10-403 and a Form 10-404 with a copy of the Daily Reports of Well Operations will follow the approval of the 403. The cement plug was bumped, casing pressure tested, tree flanged up and tested, and the well was shutin. Sincerely, D. L. Mount joy Sr. Drilling Foreman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Alter casing __ Repair well __ Change approved program __ 2. N a~ ~er~)(~, 3. Address P.Oo BOX 340045, PRUDHOE BAY, AK 4. Location of well at surface 420' FWL, 2055' At top of productive interval At effective depth GYRO SURVEY NOT At total depth FNL, SEC 8, T13N, PRESENTLY AVAILABLE Operation shutdown ~ Re-enter suspended well __ Plugging m Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate m Other __ 5. Type of Well: Development .___X Exploratory __ Stratigraphic __ 997 4 Service__ RIOE, UN 6. Datum e/eyation ('DF or KB) 56' KB HSL 7. Unit or Property name HILNE POINT UNIT 8. Well number L-5 9. Permit number 90-3g 10, APl number 50- 029-22030 11, Field/Pool KUPARUK RIVER feet 12. Present well condition summary Total depth: meas'ured true vertical Effective depth' measured true vertical Casing Length Structural Conductor 80 ' Surface 6009 ' Intermediate Production 10493' Liner Perforation depth: measured N/A 10550' 7618' 10439' 7554' feet Plugs (measured) feet feet Junk (measured) feet Size 13-3/8" 9-5/8" 7" Cemented TO SURFACE 470 BBL CLASS E 87 BBL CLASS G go BBL CLASS G Measured depth 115' 6044' RECEIVE i ,,AY l 1990 Alaska 0ii & Gas Gons. Commission ' ~ ~ll~t~r~al depth 115' 4680' 10528' 7606' true vertical Tubing (size, grade, and measured depth) NOTE: TVD'S ARE BASED ON ltWD DIRECTIONAL DATA, NOT FROM GYRO Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal Detailed operations program m BOP sketch 14. Estimated date for commencing operation AUGUST 10, lggO 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~/~~ Title SENIOR DRILLING FORENAN ' ' FOR COMMISSION USE ONLY DaflAY 9, 1990 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- JApproval Approved by order of the Commission Form 10-403 Rev 06/15/88 Approved Copy Returned ~ ,%' _.it.. ORIGINAL SIGNED ~'~ s§i'oHer Date SUBMIT IN TRIPLICATE 01:46 CONOCO MILNE POINT RIG 141 STATE: OF' AL~KA ALASKA OIL AND G~ I~I~¥ATION ~115510N BOPE Inspection Report .. Lo¢01;ton (general) ~,t,-* ~We11 ~tgn General housekeeping , ,g~:~.~ ~ MUD SYSTD4S ~ v( sual Trtp tank Pi: gauge Flow merit tot Gas detectors ~"' soP~ s~C_._____~: , Annul ar preventer Pi pe ra~s · Blind rams'.'" Choke line valves HCJ~ va 1 ve K~']1 ~tne valves C~ee~ valve ft Test Pressure J mtn 2.~ sec Controls: Master 'I~kJ/~J~'KYR ..... R~ V~, ~ Blind switch cover~ ~ELLY ~D FL~ SA~Y ,yALV~s .... U~er Kelly / Test pre~au~e L~r Kelly ~ Test pressure .. ~11 ty~ ~ Test pressure -,;T~~ .. inside BOP ~ Test pressure .... ~,~~ pressure Choke manifold _~ Test Number valves ! ,~. Numbor t'1 ..g.. Adjustable chokes :._ Hydraul t cai ly opera:ed choke TEST R. EsuLTs: F~:~)_ Test. time hrs .... Z / and inspe~tor/Con~ntsston office no:ified, .... op ; ................ D~ str(but(on: orig -' AOGCC C - SuperviSOr 04/10/90 22:44 CONOCO MILNE POINT RIB STATE OF ALASKA ALA$1<A Oig ANO GM ~L~I~RVATION Drlg contectP Ganera$ houaekeeptng :_~__e.._~ Rig Pi pa ram~ Blind eama Choke line valve~ .... : ........... NCR valve K(11 ~tne v~ves :heok wlve _ . patg Upper Kelly ........... Teat ~o~er ~elly Tee~ pr~i~ure _ . B~11 type ,, Teat preaiure ......... In~Ide BO~ Te&~ preiture Choke ~nt~old , ,, Te~t ~re~$ure .... . ......... Number valvea :== ......... ... Numb~r flangee ...... :. ==A..:_=:.=~--, .... Ad~ul~lble cho~II_. ..... - .................. TEST R,E$,U.LT$1 FaIlueea _~.(~. Te~ t;In~ ........ hl'l Repair oe reple©em~nt of failed equipment to be ~de w~thln deyl and 1 h~p~o to r/C~ eO ~ O~ off ~ oe no~I f t ~. .-.,-=~. ~~_____ ~ ~,.~. ... ..... ~-~::_._...~=._.:_=._..4~_~/.~~ ~ ,, .... .... ,._.,,-- .... · ~ : ~ ~ ~1~ ~ !~ : ................................ . ,/ SCHLUMBERGER WELL I, ERVICE$ A DIVISION OF ~i, CHLUMB£11I~EFI TE:CHNOLO~Y CO~POIqATION HOUSTON. TE:XA5 ?7251 4q, EA~ REPLY TO MAY 0 5 lgg0 Pouch 340069 ?rudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 .~mchorage, AK 99503 Attention: Marc Shannon Gentlemen: Enclosed ore_Z_]U,_prints of the Company CONOCO, Inc, Well. . Mi 1 no_ Poi nt ITni Field Milne Point Additional prints ore being sent to: I BL prints CONOCO, Inc. . .600... Norr,.h Dairy Ash~ord Houston, TX 77079 Attn: George Lamb - OF 2018 PER County N~rtb $!ope . State Alaska . ~rints, 1RF Sepia 1000 Sough Pine Ponca City. OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. _..6 Desta Drive Midland, TX .79710 Atgn: John Carrol *(915/685-5600) _l__]tL_prints, 1RF Sepia .... Chevron U.S.A. 6001BollJnger Canyon Road San Ramon~ CA 94583-0943 Attn: Priscilla MacLeroy ..... *(415/842-1000) AlaSk'a 0il & Gas Conservatlo'n ~'Commission ;~ 3001 Porcupine Drive ..)mc. horage, AK 99501 John Boyle The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints · Naska 0il & Gas Cons. Commission Anchorage Very truly yours, SCHLUMBERGER WELL SERVICES David H, Saalwaechter OlS"rl~ I~ IdANA(~ER Sws-- 13274~ CONOCO, Inc. 3201 "C" Street, Suite 200 AnchoraRe, AK 99503 A~ention: .... Marc Shanno~ SCHLUMBERGER WELL SERVICES A~NVISIONOF$CHLUMBERGER'r~CHNOLOGY COllATION HOUSTON, TE~XAS ?7251-2175 APR 2 2 1990 ~LUMBER~E.~LL ~,US ~ouch 360069 ~:udhoe ~ay, ~ 9973a-0069 Gentlemen: Enclosed ore_~rintsofthe Compony CONOCO, [nc. Well Milne Point Unit L-5 DIT, CNL(PORO), CNL(~W), NGT, Cyberlook, .. Run 1 ~ 4~f-~/90 Field, Milne Point Additionolprintsorebeingsent 1 BL nrints CONOCb, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: GeorRe Lamb.- OF 2018 PER County North Slope Store Alaska 1 BL prints, 1 RF Sepia CONOCO. Inc. .. 1000 South Pine Ponca City? OK ?.~603 Attn: Lng Library 1 BL prints , 1 RF Sepia OXY U.S.A., Inc. .Midland, TX 79710 _._Attn: John Carrol _.* (915/685-5600) I BL prints, 1 RF Sepia Chevron U.S.A. _~001Bollinger Canyon Road San Ramon~ CA 94583-0943 Attn: Priscilla MacLeroy * 1 BL Alask'~[~l & Gas Conserv,~'~on C~is$ion ") .3.07~i Porcupine Drive '~horage, AK 99501~ The film i~ ,returned to Conoco, Log L~brary. We oppreciote the privilege of serving you. -0- prints 1 Field Tape Ch~vrnn --6GOd-~o!!ing~r Canyon ~cad Se~ ~a~on, CA .94583-0943 ATTN: Norm .Ston~ * {415/842-]880) prints prints Received by' Date: APR 2 4 1990 Very truly yourql~aska 0ii & Gas Cons. C0mml~10. SCHLUMBERGER WELL ~ David M. Saalwaechter OISTRmcT #ANAGER Telecopy No. (907) 276-7542 April 11, 1990 D L Mountj oy Sr Drlg Foreman Conoco Inc Pouch 340045 Prudhoe Bay, AK 99734 Re: Mitne Pt Unit L-5 COnoco Inc Permit ~ 90-39 Surf Loc 420'FWL, 2055'FNL, Sec 8, T13N, R10E, UM Btmhole Loc 4585'FEL, 856'FNL, Sec 5, T13N, R10E, UM Dear Mr Mountjoy: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated March 8, 1990, which accompanied the original approved permit are in effect for this revision. Very truly yours, ~V Chatt~r~°n Chai~an Alaska Oil and Gas Conservation Co~ission BY ORDER OF TMH~ COM~IISSION jo Enclosure C: Dept of' Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA-'~-"L AND GAS CONSERVATION Cf'~-"~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill _-X Redrill lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entry - Deepen Service ~ Developement Gas ~_ Single Zone ;-; Multiple Zone L-X , 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and P0ol CONOCO INC 56' NSL feet , 3. Address 6. Property Designation KUPARUK RIVER FIE P.O. 340045, Prudhoe Bay, AK 99734 ADL-25509 ,,, 4. Location of well at surface 7. Unit or property Name 11. Type Bond~see 20 AAC 25.025) 420'FWL, 2055'FNL, Sec 8, T13N, R10E, UN NILNE POINT UNIT BLANKET At top of productive interval 8. Well number Number 4600'FEL, 1200'FNL, Sec 5, T13N, R10E, UN L-5 8086-15-54 At total depth 9. Approximate spud date Amount 4585'FEL, 856'FNL, Sec 5, T13N, RIOE, UN APRIL 9, 1990 $200,000 , , 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 856' feet 60, ~'.'SURFACE feet 2533 lO,242'ND,7450'lf¥1)t 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 49o Maximum surface 3200psig At total depth (TVD)3800 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 13-3/8' 48 H-40 WELD 80' 35' 35' 115' 115' _+485 SKS PERMAFROST C 12-1/4 9-5/8' 36 J-55 BTRS 6019' 35' 35' 6054' 4700' FIRST STAGE: 606 SKS (Arc';lc Gra(e) PERM,,FROST E k 345 SKS CLASS'G 2ND STA~ 5o, 5 ,'KS PERR~FRU$1 E & 8q 5K5 CLA$5 8-i/2 /" 26 L-UU um~) ,zu,zu/ Jb' 35' tU,Z~Z /qbU 1ST ~TG: 305 SKS t.;LS 19. To be completed for Redrill, Re-entry, and Deepen Operations. DOWiiuQUEEZE .ou ~r,,~ r,-rm~rKu~m b & Present well condition summary 60 BBLS DEAD 0IL/DIESE Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor..... Intermediate ,,~*~X ~'~ ,,-c.~.~;,**¢t d/~;~/ ?¢ '-- ,~.-, ~ Production ~-'~ o~ r.~,m Oil.& G~s D~ Commls~,~n Liner Perforation depth: measured true vertical Pit Sketch x 20. Attachments Filing fee FiX Property plat DX BOP Sketch ~ Diverter Sketch r._]X Drilling program ~ Drilling fluid program [7KTime vs depth plot [~X:Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements , , , 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title SENIOR DRILLING FOREMAN Date Commission Us(~ Only oLslo~t~,D~ Permit Number _-- I APl number J App~/~.///~, V" J See c°ver letter ~ ~~ ~ 50m ~,Z ~o ,,2,30 j' O for other requirements Conditid'ns of approval Samples required F-! Yes [] No Mud log r~'~ui~d L-l Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Requiredworki~/~~~~2; D5M; ~ 10M; ~ 15M Other: by order of K,~/~/ Approved by L~ ~'/, L~ Commissioner the commission Date .D Form 10-401 Rev. 12-1-85 Subrrf iplicate RECEIVED APR - 9 ]9,90 Oil & Gas Cons. Commissio. r~ Anchorage HORIZONTAL SCAL'"-"' I N. PROJECTION = 1000 FEET CONOCO. Inc. Psd L. Well Not 5 MIIne Point Unit, Revised Proposel North Slope, Aleska z o 2000 7000 ,,J 1000 I 6000 5000 _ 4000 _ ~000 _ 2000 _ 1000 _ O _ 1000 _ TARGET / LK-1 TVD=71 $0 TH0=9785 DEP=6141 NORTH 6135 EAST 260 SURFACE SURFACE LOCATION' 2055' FNL, +20' FWL SEO. 8, Ti3N, RI OE WEST-EAST 0 I N 2 6141' 1 000 I 2000 I TD LOCAT l ON' 856' FNL, 4585' FEL SEC; $= T!3.u.= R!OE TARGET LOCATION' 1200' FNL, 4600' FEL SEC. 5, TI3N, RI OE DEG 26 HI N E (TO TARGET) RECEIVED APP, - g ],'.9,90 . '~- ~.s~a Oil & Gas Cons. Commissio~ Anchora,q~ CONOCO. ln~. Pad L, Well No' ,5 HI Ins Point: Unl~, Re~ ~ed Proposal North~Slope. Alaska . RI(B ELEVATION' 28' 1000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 - 8000 _ KOP I0 18 TVD=500 THD=500 DEP=O BUILD 2 DEO PER I00 FT 26 ;~0 34. 38 42 4s EOB TVD=2661 TMD-2948 DEP=984 9 5/8" CSO PT TVD'"4TO0 THD=6054 DEP"3326 AVERAGE ANOLE 48 DEO 58 HIN RECEIVED APR - 9 !990 Oil & G~S COILS, CO~tTt"I$$JO~ AnchOrag~ TAROET / TVD=71 50 TD/T" LK-1 THD=9785 DEP=6141 LINER TVD=T450 THD=10242 DEP-6485 I 1 000 2000 I I I i 3000 4000 5000 6000 VFRTIP, AI RFP. TInfi I 7000 3OO 250 200 150 100 50 5O 100 150 I 1500 \ \ \ I ~ I I I I I I I I I I I , lO0 I 5O 0 1300 \ \ \ \ \ ~1100 \ \ \ ~\900 I 1700 I I I I I I I t 1 soo I I I I I 1 300 I I I I I 1100 ! I 900 I 300 ~' 700 ~' 5oo go0 500 150 50 100 I 1 500 / 'x900 ~ 700 ' 500 j, 7o, ox 7' 1100 RECEIVED AP'P, - 9 !990 Oil & Gas Cons. ?,richorag~ 150 I 100 50 0 50 100 150 30C 250 20O 150 100 5O 5O 100 and/or Diesel will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drilling rig. A~ Drill a 30" conductor hole to +80' and set I3-3/8" conductor. B. Drill a 12-1/4" surface, hole to ++700' TVD (6054' MD) and set 9-5/8" cas i rig. C. Drill an 8-]/2" production hole to +7450' TVD (10,242' MD) and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS ~L O' O' Gravel l-]-4 9,0 32 20 90 15 500' 500' Sand/Clay ]-]-4 9,0 25 20 65 15 3672' 4698' "K" Sands 1-1-4 9.2 25 15 65 14 3761' 4808' "M" Sands 1-1-4 9.4 25 15 65 13 4017' 5200' "N" Sands 1-1-4 9.4 25 15 65 12 4189' 5470' "0" Sands 1-1-4 9.4 25 15 65 12 6704' 9170' Sea Bee 1-1-4 10.2 8 12 40 10 6926' 9452' Kup Top 1-I~,6 10.2 8 12 35 5 7150' 9785' L K (l) 1-l-6 10.2 8 12 35 5 7169' 9835' L K (2) 1-]-6 10,2 8 12 35 5 7350' ~)891' B L K 1-1-6 10.4 6 12 35 5 7450' 10,242' TD I-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Not(ce will be submitted. RECEIVED APR - 9 !990 ],'t~,~ska Oil .& Gas Cons. Commissio[~. Anchorag~ March 8, 1990 Telecopy No. (907) 276-7542 D F Rainwater Sr Production Foreman Conoco' Inc Pouch 340045 Prudhoe Bay, AK 99734 Re: Milne Pt Unit L-5 Conoco Inc Permit # 90-39 Surf Loc 420'~WL, 2055'FNL, Sec 8, T13N, R10E, UM Btmhole Loc 840'FEL, 1775'FSL, Sec 6, T13N, R10E, UM Dear Mr Rainwater: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this ofiice 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very trui~y~ur s, Chai~an Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION Eno losure C: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl ,'*'-", STATE OF ALASKA ALASKA -L _ AND GAS CONSERVATION CC...MISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill :~ Redrill E]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development OiH~ Re-Entry [] DeepenE]I Service ~ Developement Gas [] Single Zone [] Multiple Zone ~tq 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Conoco Inc. 56' MSL feet Kuparuk River Field 3. Address 6. Property Designation P.O. Box 340045, Prudhoe Bay, AK 99734 ADL 25509 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025> 420'FWL,2055'FNL,Sec 8, T13N,R10E, UM Milne Point Unit Blanket At top of productive interval 8. Well nu ,mber Number 775'FEL,1575'FSL,Sec 6,T13N,R10E, UM L-5 8086-15-54 At total depth 9. Approximate spud date Amount 840'FEL,1775'FSL,Sec 6,T13N,R10E, UM March 28, 1990 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3505 feet 60', @ Surface feet 2533 ac 8617'MD*7400'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2>) Kickoff depth 750 feet Maximum hole angle 36 0 Maximum surface3200psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 13-3/8" 48#/Ft H-40 Weld 80' 35 35 115 115 485sAs Permafrost C 12-1/4" 9-5/8" 36#/Ft J-55 BTRS 5222 35 35 5257 4650 First Stage: 606 sks ~ Perma:'rost E ~ 345sks Class G~2nd St 545sk,,~ Permaf_"ost E & 84sks Class G 8-1/2" 7" 26#/Ft L-80 BTRS 8582 35 35 First Stage: ~05sks Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Second Stage: 180sks Permafrost C an Present well condition summary 60 bbls Dead Oil/Diesel Total depth: measured feet Plugs (measured) true vertical feet ~GI-/'~o Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate MAR --5 Production LinerAlaska Oil & Gas Cons. comm' ssi¢ Perforation depth: measured Anchorage true vertical Pit Sketch X 20. Attachments Filing fee [] Property plat I~ BOP Sketch [] Diverter Sketch [] Drilling program ~2 Drilling fluid program ~ Timevs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that.~e foregoin_,og_j,s true and correct to the best of my knowledge 22 /~¢-~'~/'~ ~/,-,~--~-//~'~'~':';' Senior Production Foreman Signed Title Date . · Commission Use Only Permit Number I AP, number I Approva, date I See cover letter ':~_~ ,- ,,~ ~' 50-- 43 ~ ~', - ~-_ ~ ~ ,.7 ~ 0 3 / 0 8 / 9 O for other requirements Conditions of approval Samples required [] Yes }:~'No Mud Icg rec~uire~l E} Yes /h~r'No NTT required Hydrogen sulfide measures [] Yes ~No Direction' al survey required "-~'Yes [] No Required working~re fop~BO, B~r-~' []2~1; [] 3M; ~ 5M; [] 10M; [] 15M Cai] for' rep Other: / /~/f///~¢~.~-,/ /" to witness. 7~~ . by order of Approved by ~ ~,~', ~ Commissioner the commission Date zge: Subr~it 'iplicate Form 10-401 Rev. 12-1-85 SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-5 Conoco Inc. P.O. Box 340045 Prudhoe Bay, AK 99734 I · Casing and Cementing Program A· Be The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with +480 sacks Permafrost type "C". Ce The 9-5/8" surface casing will be cemented in 2 stages with the first stage using ±606 sacks of Permafrost "E" cement followed by ±345 sacks of Class "G" cement. A DV tool will be placed at ±1825 MD. The second stage will contain ±545 sacks of Permafrost "E" cement followed by ±84 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. The 7" production casing will be cemented in two stages. The first stage will consist of ±305 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±180 sacks of Permafrost type "C" cement followed by +60 barrels of Dead Crude and/or Diesel pumped down the 7" x 9-5/8" annulus. II. Drilling Fluid Program A. 0-500' 9.0 ppg freshwater spud mud. Be C· De 5260'-7600' 9.0 ppg-9.5 ppg dispersed. 7600'-TD 10.2 ppg-lO.4 ppg dispersed. III. Drilling Program 500'-'5260 9.0 ppg-9.8 ppg freshwater spud mud. R[CEIVED MAR - 5 ]990 Alaska Oil & Gas Cons. CommissiO.~ Anchorage Conoco Inc. proposes drilling the subject well as an injection well in the Kuparuk River Field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at TD will be 10.2 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. Maximumdownhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbores are L-4 and L-7 with 60' of closure at surface. Dead Crude and/or Diesel will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed after releasing the drilling rig. Ae Drill a 30" conductor hole to +80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to +4650' TVD (5257' MD) and set 9- 5/8" cas ing. Ce Drill an 8-1/2" production hole to +7400' TVD (8617' MD) and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL O' O' Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3672' 3886' "K" Sands 1-1-4 9.2 25 15 65 14 3761' 3999' "M" Sands 1-1-4 9.4 25 15 65 13 4017' 4324' "N" Sands 1-1-4 9.4 25 15 65 12 4189' 4542' "0" Sands 1-1-4 9.4 25 15 65 12 6654' 7670' Sea Bee 1-1-4 10.2 8 12 40 10 6876' 7952' Kup Top 1-1-6 10.2 8 12 35 5 7100' 8237' L K (1) 1-1-6 10.2 8 12 35 5 7119' 8260' L K (2) 1-1-6 10.2 8 12 35 5 7300' 8491' B L K 1-1-6 10.4 6 12 35 5 7400' 8618' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. RECEIVED MAR - 5 ]9gO .Oil.& Gas Cons. Commissio? ~chorage CONOCO, ]:nc, Pad L, We l I MI Ine Poln{ No: 5 Rev I sed Propose I Unl{. Nor{h Slope. Alaska 0 . RKB ELEVATION' 28' 1000 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ ?000 8000 KOP TVD=750 TMD=7'50 DEP=O 2 6 IO 14 BUILD 2 DE(~ 18 PER I00 Fl' 22 26 96 THD=2503 DEP=520 ~ 9 5/8" CSG PT .. TVD=4650 TMD5257DEP=2102 AVERAGE ANGLE 35 DEG 4 MI N RECEIVED ~ MAR - ~ Alaska 0/1 & Gas Cons. Commissior? ~ Anchom.q~ AROET / LK-1 ~ ' TVD=7100 THD=8250 DEP=3822 ' ~ TD / 7" LINER TVD=7'400 TMD=8617 DEP=4032 i I I i I 1 000 2000 :3000 4000 5000 VERTICAL SECT!ON HORIZONTAL SCALE 1 IN. PROUECTION = 1000 FEET CONOCO. !nc. Ped L. Well No' 5 Yll Ine Poln'l: Revleed Propoeel North Slope, Aleeke 40O0 TD LOCATION, 1775' FSL. 841' FEL SEC. 6. T13N. RIOE 3000 TARGET LOCATION, 1575' FSLo ??5' FEL SEC. 6. TI3N. RIOE 2000 1000 1000 :3000 2000 I TARGET / LK-I TVD=?IO0 THD=8250 DEP=3822 NORTH 3630 WEST 1195 WEST-EAST 1 000 I 1 000 I RECEIVED Alaska,Oil & Gas Coas. Commissio~~ Anchorag~ SURFACE SURFACE LOCATIONt 2055' FNL. 420' FWL SEC. 8. TI3N. RIOE N 18 DEG 13 HIN W :3822' (TO TARGET) 150 200 250 300 350 400 450 500 550 I",°°~''1 I~°°~'~ 1 650 _ J 1700 / ~ ~ / - ~5oo k . / , ~oo ,ooo r~b ~~ . ~~ ~oo ~ ~ ~zoo / ~~~' 500 ~ co X ~ ' ~so~ 500 ~ ~ ~. t 5500 k ~ ~ /~ I ~~9oo~9oo .....~~ '~ ~ RECEIVED 2100 _ J o Atas~ 0il & Gas Cons. Com~tsslQ~: 2] 5o _ ~h'~e' - 150 200 250 300 350 400 450 500 550 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 NOTES: 1, STATE PLANE COORDINATES ARE ZONE 4. 2, ALL .GEODETIC POSITIONS ARE BASED ON 'N,A,D, 1927, OI:I:SET$ 1'O SECTION LINE8 ARE COMPUTED BASED ON PROTRACTED VALUE8 OF THE 8ECTtON CORNER POSTION$. II I 6~O' _ t60' _ _ 810' __ I~ i T . - · I' ~1~ RESERVE PiT L PAD ! MILN$ POINT UNIT i ~O~I~Y~ DAY MILNfi PT, VICINITY MAP L O CATION IN SEC, 8, T13N, R1OE, UMIAT MERIDIAN WELL J FROM NORTH LINE I r-.o~ W~. LINE L-4 [ 2087' 1 369' L-6 J 20,56' 420' L-7 2023' 47OJ5' STATE PLANE COORDINATES-ZONE 4 WELL Y r X -L-4 4,-o~.Ei' 1 544,970.7' L-6 6,031,41~,4' ~48,021,3 L-7 0,O31,447.6 ~4~i0071,9' · -'m r-l~- 16o' _.._,~. ~10' ~ 16o' ~ I~' GEODETIC POSITIONS NAD 1927 ~,~ '--, ~ -' ~- -. ].~ ~~,~ ~,,~ ~.~ ~o~,~u~r L-5 J TO' 29'48,096' J149' 37'54,651' ~TYPICAL SECTION ~, ~ ~ ~, ~ ~ r ~-~ m N(~ SCALE .... , 5 !990 - '' ...... FIELD 80oK: ~CAL~ 1'~2OO' d j V 11 WELL L-5 TIME_ESTIMATE Hours Days Cum. Days A. Rig Up 8 0.33 0.33 B. Drill Surface Hole 8O 3.33 3.66 C. Run Surface Casing and Cement 36 1.50 5.16 D. Drill Out and Test 0.33 5.49 E. Drill Production Hole 101 4.20 9.69 F. Log Open Hole 36 1.50 11.19 G. Condition, POOH, L.D. 2O 0.83 12.02 H. Run Production Casing 16 0.67 12.69 I. Cement Production Casing 10 0.42 13.11 J. Run Cased Hole Logs & Perf 36 1.50 14.61 K. Run Completion EQ 12 0.50 15.11 L. Move Rig _~ _Q,.33 TOTALS 37 15.44 15.44 RECEIVED '' ollorage ~0 0 -1 -2 -5 -4 -5 -6 -7 -8 -9 MILNE POINT UNIT WELL L 5 Rate vs. Depth 0.00 ~ 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 RIG DAY~ KILL MANIFOLD FRO),4 RE~IOTE HIG~ ~ ~ ~ R~OTE PRESSURE GAGE SENS~ PRESSURE PU~P ~ ~1 ~ ~ ~ ~ ' HYDRAULIC CONTROLLED NOTE: ~ [ REMOTE OPERATED I. H~R~ULIC L~AI[D RE~OTEL~ WITH ~0 PSI ACCUMULATOR ~ 160 G~. RESE~IR B AUX. ENERGY SOURCE. ~NT~L TO 8E ~CalED ON 81G FLO~. DEILLING Z K~L a CNG~ KANIFOLDS ~ MEET A~ EPS] ~. SP~ 5~ S~S. ). KILL UANIF~D SIZE- RATING 2'- 5~ ( CHOKE ~ANIFO~ SIZE - RATING 5"- 5~ . ~ ~ HYDRAULIC CONTROLLED RTE OPIATED ' ~ '~REMOTE PRESSURE GAGE SENSOR I ~ ~- ~OKE I ' ~ TO SHA~ SHAKER BLeD LINE TO /TUOSPHERIC TO PiT MUD/GAS SEPARATOR RECEIVED MAR -.? gJ~ Oil & G~,s Co~s. Commi~ ;Anchorage CHOKE 8 KILL MANIFOLDS FOR q~/8'i a 7" OD CASING BOP STACK BOP ~,{ANIFOLD LAYOUT - CONOCO, INC. : ....... ...... m m i m m l,m . ., mi m Mil. NE POIHT UNLIT BOP STACK FOR 9-5/8" SURFACE CASING Il iLL- I,l P LIII[ (1) I~¥i' APl ~0004 StP[ OUTL[TS L~' ~ SPOOL (2) (3) Il,It APl $000d ~ '11' &PI 5000 II' JPI }000t (6) · ... · · B.O.P. stack size rating meets AP1 RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control eantfold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation· Ram type BOP to include a mtntmu~ of one set of blind rams and two sets of appropriate pipe rams. Choke and kill manifolds sho~a separately to meet APl RP 53 class 5M · requirements, CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 3/8' CONDUCTOR __.~ FLO'W LINI ~ ~IV[RT[I OUlCK CO~NtCT lSS[UtLT ,,,,.,,, RECEIVED ~- ~J~a,~i/.& g~s Oons. Commission' ,~ ~/.' c,s,~o Anchorage .;.- ,'2 ..' ; ' ': . .. · . ': .':. '.'.t. ' · '.~ '~ f~.'~'r~.: 1. ~e hydraulic control sys%a will ~ in a~rda~e wi'th ~I specifications a~ ~ r~uirements. ~. The HCR valve will open ~en the preventer closes. A ~ingle , 10a relief line will run off of the drilling s~ol HCR valve and will have a ta~geted d~nstream tee for downwind dive,ion. Valves on ~th sides of the t~ will be full opening a~ linRed together ~o enable one to always be o~n a~ the other to ~ closed. TROUGH MuD CLEANER WATF...R i~ HCa..E FILL HOLE FILL TAt~K I I MuO ~ex H~R$ VA:UL'J UI,( CHz-:~GECH,'d:~GE I~b~*:,~ 2 Ft.,:~,'P I PUk3P 2 ,; GATE V~LVE MUD GUN R~G 27 E 12*'.;*G' r"B~ kilo SrSTE'4 FLOW SHEET __ ____ AX ELSEN INDUSTRIES LTD. ~[DMONTO~. · PHONE (4,0~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE 1. Is (8) (3) Admin~fl ~ 9. hru 10. . . . (10 and 13) 12. 13. (4) Casg ~C~' I/-/~7~P~ "(14 thru 22) (23 thru 28) 14. 16. 17. 18. 19. 20. 21. 22. Company L e as e & We 11 No. /~f~/~ ::~ ff, J'~__) ~~/'z-~I~/EMARKS YES NO the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. ~_ 3. Is we~] located proper distance from property line .................. ~ . .... 4. Is we,ll located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affeCted party ................................. ~ . 8. Can permit be approved before fifteen-day wai~ ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... _~_ Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ ......... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~ ... Will all casing give adequate safety in collapse, tension and burst.. · Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ 23. 24. 25. 26. 27. 28. Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ....................................... ~___ Is the drilling fluid program schematic and list of equipment adequate ~ Are necessary diagrams and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to ~-'O~)CD psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. /~ Is the presence of H2S gas probable ................................. (6) OTHER /~.;~d_ ~ (29 th ru31) (6) Add: Geology: DWJ ~ Engineering: Lcs ~w rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE .,, ,, CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE , (2 rnru 8) e 3. 4. 5. 6. 7. 8. (8) (9 thru 1'3)' ' 10. (10 and 13) 12. 13. (4) Casg "~,~.~. ~-O-?o (14 thru 22) Company ~-~_.~,~--c~_ Lease & Well No. ~z~ YES NO the permit fee attached ........................................... /~_Jd Is well tff be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ,~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... _~_ Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ (5) BOPE (23 thru 28) 22. 23. 24. 25. 26, 27. 28. Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to .~'OOc~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thr6 '3f) rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ Additional requirements ............................................. ZNITZA~ OEO. UNZZ i 0N/OFF POOL CLASS STATUS A~EA N0. S~0R~ / C :mm ~C
