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198-056
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS REECEIVED JAN 17 2019 1. Operations Abandon LJ Plug Perforations Ld Fracture StimulatLi Pull Tubing rLi Performed: Suspend ❑ Perforate ❑ Other Stimulat Alter Casing ❑ Chane Aparove rogram ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair We[[] Re-enter Susp Well ❑ Other: Plug and Isolate Q 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ® Stratigraphic❑ Exploratory Ell Service ❑ 198-056 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 6. API Number: 99503 50-029-22864-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: _ ADL0025514 MILNE PT UNIT L -37A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 15,425 feet Plugs measured 7,391 CTMD feet true vertical 7,062 feet Junk measured 7,130 feet Effective Depth measured 7,391 CTMD feet Packer measured 7,048 & 7,165 feet true vertical 3,989 feet true vertical 3,892 & 3926 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Production 8,182' 9-5/8" 8,213' 4,190' 5,750psi 3,090psi Liner 154' 4-1/2" 7,202' 4,190' 3,875psi 6,350psi 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 / 8RD EUE 6,970' 3 869' 9-5/8: 'IES Versatrieve — Packers and SSSV (type, measured and true vertical dep:h) 9-5/5' HES BWD See Above N/A - N/A 12. Stimulation or cement squeeze summary: N/A airy t � ,•✓2�� A;,� Intervals treated (measured): N/A i °3 /1% y �,�G�.�� �,✓E, Treatment descriptions including volumes used and final pressure: N/A r r 13. Representative Daily Average Production or Injection Data Oil -Bbl Ga !-- Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 240 0 Subsequent to operation: 10 0 0 200 0 14. Attachments (required per20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Develo ment p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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: 318-118 Authorized Name: Chad Helgeson�"� Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman((17hilcoro.com Authorized Signature: Date: 1/16/2019 Contact Phone: 777-8449 / RBDMS4,53 JAN 1112019 Form 10-404 Revised 412017 /,O l%2'P� Submit Original Only Orig. KBE Elev.:48.2 (N 22E)/GL Elev..:17,6 Milne Point Unit Well: MPU L -37A Last Completed: 7/25/1998 PTD: 198-056 TREE & WELLHEAD Tree Cameron 2-9/16"5M Wellhead 11"5M FMC Gen6 w/2-7/8"FMC Top Tubing Hanger, 2.5" CIW BPV Profile OPEN HOLE/ CEMENT DETAIL 20"Cmt w/ 2SO sx of Ancticset I (Approx.) in 24" Hole 9-5/8" Cmt w/ 2,031 sx PF "E", 625 sx Class "G" In 12-1/4" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 2 2,664' STA #1: GLM w/ Empty Pocket 91.1#/H-40/N/A N/A Surf 112' 6,917 9-5/8" Surface 40#/L-80/Btrc. 8.835 Surf 8,213' JBF20"Conductor 4-1/2" Liner 11.6#/N-80/NUBlank 4.00 7,048' 7174-1/2" 9 6,948' Liner 12.6#/L-80/N/A 3.958 7,165' 7201' TUBING DETAIL 2-7/8" Tubing 6.S#/L-80/8rd EUE 2.441" Surf 6,970' 0.0058 DEVIATION DETAIL STIMULATION SUMMARY KOP @ 350' 6/20/1998 -OA Sand PropLoK Frac 60.1M# of Max Hole Angle =79°from resin coated 12-20 Ottawa sand behind pipe. 3,750'to PBTD (8,211' MD) 6/25/1998-N Sand Frac Pack 81.SM#Of ipe 16/20 Carbolite Placed behind P JEWELRY DETAIL To= 15,425(MD)/TD =7,062'(M) PBTD= 8,1]2' (M)) / PBTD=4,16YM) No F Depth Item 1 116' STA #2: GLM w/ Dual Screen Orifice 2 2,664' STA #1: GLM w/ Empty Pocket 3 6,915 X -Over 3.5" x 2-7/8" 4 6,917 Y -Tool: Trico 3.5" Welded 5 6,922' OTIS 2-7/8" X Profle Nipple: (2.313 No-go I(T)- ()6 6 6,927 Discharge Head: FPDIS 7 6,928' Pump: Type- 178 FC925, Model - FPMTAR 1/1 8 6,945' Rotary Gas Separator: FRSX HP3 9 6,948' Upper Seal Section: CLS GSB3 UT HL AFLAS 12/10/2005 54' LowerSeal Section: CL5 GSB3 LT HSN 60' Motor: KMH 76 HP/ 1,360V/ 34A 4,048' 68.6 PHD&Stablizer-Bottom@6,970.5' Closed 68.7 WLEG - Bottom @ 6,970' 7,690' 48' 95/8" Versatrieve Packer 30 57' fi Frac Closing Sleeve Assembly Ref Log: Sperry Sun EWR 3/12/1998. CA Sand 6/20/1998 -Atlas 28gm lumbo Jet Charges, EHD=0,93",tip= 5.2". N Sands 6/23/1998SWS 43gm Big Hole Charges. All other perforations are 2" 6 Shot Per Foot. W 4-1/2".020 Ga. 30455 Pre -packed S70' 9-5/8"BWD Sump Packer 65' Collet Muleshoe Guide-Bottom@7,171' 186' HES XU Durasleeve 162' 9-5/8" EZSV Retainer PERFORATION DETAIL SchraderA7,610' Btm (MD) Top (TVD) Btm (TVD) FT Date Status N Sand7,160' 3,916' 3,924' 30 12/14/2005 Open 7,160' 3,918' 3,924' 20 6/23/1998 Open 7,605' 4,033' 4,040' 30 12/10/2005 Closed OASand7,630' 4,024' 4,048' 20 6/20/1998 Closed 7,690' 4,052' 4,059' 30 12/10/2005 Closed Ref Log: Sperry Sun EWR 3/12/1998. CA Sand 6/20/1998 -Atlas 28gm lumbo Jet Charges, EHD=0,93",tip= 5.2". N Sands 6/23/1998SWS 43gm Big Hole Charges. All other perforations are 2" 6 Shot Per Foot. GENERAL WELL INFO API: 50-029-22864-01-00 Drilled and Cased by Nabors 22E -3/7/1998 9-5/8" Plugged Back by Nabors 22E -4/12/1998 Gravel Pack & ESP Comm. by Nabors 4 -ES -7/25/1998 Revised By: TDF 1/16/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L -37A CTU 50-029-22864-01-00 198-056 4/10/18 4/13/18 Daily Operations: 4/4/2018 - Wednesday No activity to report. 4/5/2018 - Thursday No activity to report. 4/6/2018 - Friday No activity to report. 4/7/2018 -Saturday No activity to report. 4/8/2018 -Sunday No activity to report. 4/9/2018 - Monday No activity to report. 4/10/2018 -Tuesday MI RU SLB CTU #6 with new 1.75" 424. SDFN. No Night activity CT. Fill and drift coil with 1-3/16" ball. Complete BOP test and record on AOGCC form 10- Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-37A CTU 50-029-22864-01-00 1 198-056 4/10/18 4/13/18 Daily Operations: _:...,,.. 4/11/2018 - Wednesday Crew on site. PJSM PU injector and BOPE. NU to tree. Correct nozzle depth to RKB = 21.8'. Fluid pack and PT low and high - 400psi low / 4,000psi. Open SSV, open SV, SITP = 226psi. RIH with BHA #1- BHA #1 - 1.9" OD CRC, 1.75" OD stingers (2 x 4'), 1.75" BDJSN - OAL = 8.833'. Start well kill while RIH at 2 bpm at 1,500psi WHP. Tag 4-1/2" gravel pack liner top at 7,049' ctmd. Make several attempts with various methods to pass with no luck. POOH. 83 bbls water pumped on well kill before stop pumping. POOH. At surface - insert knuckle joint and rotating tool into BHA. Back on well. PT low and high. RBIH. Tag same at 4-1/2" liner top again at 7,053' ctmd. Work tools and pump, trying to pass with no luck. POOH to change tool configuration. At surface. L/D tools and lubricator. Change out stripper rubber. PU lubricator, MU BHA, put the rotating tool above the KJ, get on well PT low and high. RBIH. Tag same and with same results. Unable to enter liner after various attempts. POOH. At surface. Secure well. Stand injector back. SDFN. No Night activity. 4/12/2018 - Thursday On location. PJSM. MU BHA #4 - WFD - 2.125" OD int dimple CTC, hyd disconnect (9/16" ball), 4' wt bar, knuckle joint, 4' weight bar, 2.125" OD bowspring centralizer (expanded to 9"), X0, XO, 1.75" OD BDJSN - OAL = 16.5'. Pull test CTC to 20k. PT tools to 3,500psi. Stab on well. PT to 340psi / 3500psi. Open well to 203psi SITP / IAP - 340psi. RIH with BHA #4. Pass into 4- 1/2" liner with no problem. Tag PBTD at 8095' ctmd (corrected to RKB). Injection test down coil = 1 bpm at 806psi WHP. Circ 3 x BU volume to remove any gas. Able to get 1:1 returns at 1.5 bpm down coil / 1717psi CTP / 300psi WHP. SLB cementers pump 5 bbls FW / PT hardline to 4,000psi / pump 53 bbls 15.8 ppg "G" Cement / 33.7 bbls FW. Start laying in cement from 8062' after 5 bbls curt out the nozzle taking returns to tank with 1: 1 returns..8bpm / 350psi WHP. ESTTOC at 7,391' MD. POOH. FP coil and tubing with 60/40. At surface, Close SV trapping 395psi WHP. Pop off well, inspect tools. Recovered what looks like partial bladder from IBP in the bowspring centralizer. Secure well. Standback injector. SDFN. WOC for 17 hrs to build 500psi CS before TAG TOC. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-1' CTU 50-029-22864-01-00 198-056 4/10/18 4/13/18 Daily Operations: 4/13/2018 - Friday Crew on site. PJSM. Check out equip. PU Injector and lub. BHA #4 still on pipe. Inspect BHA and stab on well. PT low and high 260psi / 4,100psi. Open well to 192psi SITP / IAP = 400psi. Set counter to 15.8'. Nozzle depth corrected to RKB. RIH with BHA #4 - 2.125" OD int dimple CTC, hyd disconnect (9/16" ball), 4' wt bar, knuckle joint, 4' weight bar, 2.125" OD bowspring centralizer (expanded to 9"), XO, X0, 1.75" OD BDJSN - OAL = 16.5'. Open choke to take pipe displacement returns. Wt Ck at 6,566' = 12k, RIH Wt = 4.2k. Pass into 4-1/2" liner with no problem. Start setting down at 7,136'. Try to make hole jetting and get to 7,141' with weight down. Check inject rate =.6 bpm down coil with 83psi WHP. Check inj rate down backside - pressures up immediately. POOH into the 2-7/8" tubing to 6,787'. Circ down coil with returns to tank-.9 bpm / 2,200psi CTP / 30psi WHP. Try pumping down backside again and pressures right up. Go to POOH and heavy overpull (33k) for 60' and weight returned to normal (12k). Heavy overpull again at 421'. Work coil up/down. WHP start increasing. CTP not tracking. Work coil up to 47' with continuous overpulls. Pump down backside and able to inject now. POOH pumping down backside. Tag up at surface. Upper tension spring of bowspring centralizer brake with half of it missing. Thick heavy crude / parafin on tools. CT tools packed with schmoo / solids. Stab on well. Clear coil out to tanks. MU slick BHA with 2" JSN for 2nd run. Call out LRS to pump hot diesel. Stab on well. PT to 260psi / 4200psi. RIH with 2.125" OD int dimple CTC, 2" OD DBPV, hyd disconnect (9/16" ball), 4' wt bar, knuckle joint, 4' weight bar, XO, 2" OD JSN. OAL = 12.5'. Open well to 165psi SITP / IAP = 350psi. RIH circ hot diesel (145 degrees) down coil (1 bpm) taking returns to tank holding 165psi WHP. Wt Ck at 6,000'= 13k. Adjust WHP to max while maintaining 1:1 returns. WHP at 485psi / returns 1:1. Able to pass into 4-1/2" liner. TAG at 7,127' ctmd. Clean PU at 14k. Close choke / Check injectivity- 1.2 bpm at 1,280psi WHP. SD pumping. WHP,fell from 1,280psi to 1,027psi in 10 min. Resume pumping hot diesel. TAG again same depth. POOH circulating with 645psi WHP. 80 bbls diesel /Swap to 60/40. No obstructions while POOH. Tag up at surface. Close SV and SSV. BD and POP off well. L/D tools. Secure well. RDMO. Crew on site. PJSM. Check out equip. PU Injector and lub. BHA #4 still on pipe. Inspect BHA and stab on well. PT low and high - 260psi / 4,100psi. Open well to 192psi SITP / IAP = 400psi. Set counter to 15.8'. Nozzle depth corrected to RKB. RIH with BHA #4 - 2.125" OD int dimple CTC, hyd disconnect (9/16" ball), 4' wt bar, knuckle joint, 4' weight bar, 2.125" OD bowspring centralizer (expanded to 9"), XO, X0, 1.75" OD BDJSN - CAL = 16.5'. Open choke to take pipe displacement returns. Wt Ck at 6,566' = 12k, RIH Wt = 4.2k. Pass into 4-1/2" liner with no problem. Start setting down at 7,136'. Try to make hole jetting and get to 7,141' with weight down. Check inject rate =.6 bpm down coil with 83psi WHP. Check inj rate down backside - pressures up immediately. POOH into the 2-7/8" tubing to 6,787'. Circ down coil with returns to tank - .9 bpm / 2,200psi CTP / 30psi WHP. Try pumping down backside again and pressures right up. Go to POOH and heavy overpull (33k) for 60' and weight returned to normal (12k). Heavy overpull again at 421'. Work coil up/down. WHP start increasing. CTP not tracking. Work coil up to 47' with continuous overpulls. Pump down backside and able to inject now. POOH pumping down backside. Tag up at surface. Upper tension spring of bowspring centralizer broke with half of it missing. Thick heavy crude / parafin on tools. CT tools packed with schmoo / solids. Stab on well. Clear coil out to tanks. MU slick BHA with 2" JSN for 2nd run. Call out LRS to pump hot diesel. Stab on well. PT to 260psi / 4,200psi. RIH with 2.125" OD int dimple CTC, 2" OD DBPV, hyd disconnect (9/16" ball), 4' wt bar, knuckle joint, 4' weight bar, XO, 2" OD JSN. OAL = 12.5'. Open well to 165psi SITP / IAP = 350psi. RIH circ hot diesel (145 degrees) down coil (1 bpm) taking returns to tank holding 165psi WHP. Wt Ck at 6000'= 13k. Adjust WHP to max while maintaining 1:1 returns. WHP at 485psi / returns 1:1. Able to pass into 4-1/2" liner. TAG at 7,127' ctmd. Clean PU at 14k. Close choke / Check injectivity - 1.2 bpm at 1,280psi WHP. SD pumping. WHP fell from 1,280psi to 1,027psi in 10 min. Resume pumping hot diesel. TAG again same depth. POOH circulating with 645psi WHP. 80 bbls diesel /Swap to 60/40. No obstructions while POOH. Tag up at surface. Close SV and SSV. BD and POP off well. L/D tools. Secure well. RDMO. • • 30 OF 7•4 THE STATE �, � Alaska Oil and Gas 17, Of j\ LAsKA Conservation Commission �t�l� 333 West Seventh Avenue f• Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g . Main: 907.279.1433 SFA 5�� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-37A Permit to Drill Number: 198-056 Sundry Number: 318-118 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, tiaLCCL Hollis S. French Chair DATED this Zeday of March,2018. RBDMS.I. MAR 2 q 2018 • RECEIVED MAR 2 0 2011i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OG C APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Q F 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: Plug and Isolate L' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q, 198-056 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22864-01-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 , Will planned perforations require a spacing exception? Yes ❑ No ❑., / MILNE PT UNIT L-37A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025514 MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15,425' - 7,062' - 8,112' ' 4,165' 1,339 8,112' 6,965' Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Production 8,182' 9-5/8" 8,213' 4,190' 5,750psi 3,090psi Liner 154' 4-1/2" 7,202' 4,190' 5,750psi 3,090psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic f See Schematic 2-7/8" 6.5#/L-80/8RD EUE 6,970' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"HES Versatrieve&9-5/8"HES BWD Sump Packer and N/A 7,048'MD/3,892 TVD&7,165 MD/3,926 ND and N/A 12.Attachments: Proposal Summary LI Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development I ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/1/2018 Commencing Operations: OIL ❑., • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Tr,.,/ Authorized Title: Operations Manager Contact Email: pchan c(�hilcorp.com Contact Phone: 777-8333 Authorized Signature: Date: 3/19/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 318- /is Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No 2 i o 9 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: f 0 �' APPROVED BY Ae_.Approved by: k-ff::21: COMMISSIONER THE COMMISSION Date: 1 I ..„3Ka 37iog ,y ,,,, b. ,t''C 97 ,#," 0 R 1 G I IMS MAR 1' 83-2-6'-161 Submit Form and /I„ Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • CT Schrader OA sands Isolation Well: MPU L-37A Ilikorp Baca.LLP Date:3/16/2018 Well Name: MPU L-37A API Number: 50-029-22864-01 Current Status: SI—Producer Pad: L-Pad Estimated Start Date: April 1, 2018 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-056 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 943-9533 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Numb Job Tyrie; = 1 Mian P!V'4`.11;l1,,,_ Current Bottom Hole Pressure: 1,739 psi @ 4,000'TVDss (SBHPS 02/16/2018/8.36 ppg EMW) Maximum Expected BHP: 1,739 psi @ 4,000'TVDss (SBHPS 02/16/2018/8.36 ppg EMW) MPSP: 1,339 psi (0.1 psi/ft gas gradient) Min ID: 2.313", 2-7/8"X Nipple @ 6,922' and Brief Well Summary: MPU L-37 was drilled in March 1998 as a Kuparuk test well. The well was wet. The well was then sidetracked to another Kuparuk location as MP L-37A. That location was also wet. MP L-37A was then completed as a Schrader Bluff producer. concur. well w45 new/ a fir", rirt,vccee Objective: (eqk (to ch,c s'o'l t"'45 Jvlt- 0.1 BoPD q„' Isolate and abandon the Schrader OA sands. (Vier te- vG °ve 'Or / I;fe ,,,rag < 10 100, 74l5 well 4&j no fvf Volumes: Pc4r b f-,r,r 4,a na .l► ,4,. ,1S Bottom of Gravel Pack Liner to 9-5/8" Retainer: 0.07583bpf x 911' = 69 bbls q dem vM Par /qv( 644 To top perf(7,130'): 0.00579bpf x 6970'+0.07583 x 78'+0.0152 x 82' =48bbls VA W)ico(O 71 P K fru/ wig Pre-Sundry Procedure: 'fit of&' for /hon?1ct'lll,1 Slickline , 4oes,, YI '/'U 1. RU and pressure test PCE to 250psi low/1750psi high. 2. Drift and tag w/2.0" GR toolstring. a. Last tool to go through the lower straddle was coil tubing pulling an IBP. See 01/09/06 WSR for full details. 3. RD SL unit. Sundried Operations(Approved Sundry required before proceeding): Coil Tubing 4. MIRU CT unit with 1.75" CT string and spot support equipment. Fill uprights with filtered seawater. 5. Pressure test BOPE to 250psi low/2,500 high, 10 min each test. a. Each subsequent test of the lubricator will be to 2,500 psi Hi,250 Low to confirm no leaks. 6. MU 1.9" Cementing Nozzle BHA and RIH. 7. Once the nozzle is out the tubing tail, come online with pumps and confirm injectivity into the well. 8. RIH and dry tag bottom. a. Last tag was at 8,093' ctm on 12/09/05. 9. Bring pumps online and attempt to circulate the well with 1:1 returns. • • CT Schrader OA sands Isolation Well: MPU L-37A IIilcorp Alaska,Lb Date: 3/16/2018 10. Begin to blend cement. Once cement is weighted up to 15.8ppg, pump the following volumes down the coil. g'g ±5bbls Fresh water spacer ±52bbls 15.8ppg Class G cement 11. Once 1 bbl of cement has exited the nozzle, begin to PUH and lay in cement in at 1:1. a. Estimated TOC is 7,425' and (based on previous bottom depth of 8,112' md). 12. PU to safety and circulate coil tubing clean. 13. Block in return and squeeze away±5bbls of cement. 14. POOH and WOC to build 500psi compressive strength. 15. MU 2.25" drift nozzle BHA. RIH and tag TOC. POOH. l !' 1' 7.c 7 V 16. MU (PROF BHA(spinner,temp, pressure) and RIH. 17. Stopa 7 4t 00' and and come online with pumps down the coil backside injecting into the formation. a. Pump a minimum of 75bbls prior to starting stop counts. 18. Obtain stop counts at the following depths: ±7,400'; ±7,225'; ±7,020'; and ±7,000'. 19. POOH, download data and verify zero flow into the OA sands. a. Freeze protect well to 2,000' while POOH. 20. RD coil tubing unit. Contingency—Secondary Cement Squeeze 21. MIRU CT unit with 1.75" CT string and spot support equipment. Fill uprights with filtered seawater. 22. Pressure test BOPE to 250psi low/2,500 high, 10 min each test. a. Each subsequent test of the lubricator will be to 2,500 psi Hi,250 Low to confirm no leaks. 23. MU CCL Logging BHA and RIH. 24. Log from TOC to 6900' md. Paint flag on coil at 7100' and and POOH. a. Correlation Log: MPL-37 Memory Jewelry Log dated 09-Dec-2005. 25. MU 2-1/8" inflatable cement retainer BHA. 26. RIH to coil flag and change depths to correlated flag depth. 27. RIH and set retainer at 7,180' and (middle of the pup joint above the HES Durasleeve) as per the service representative. a. Launch ball onto seat and shift open. Continue pumping to inflate the bag. b. Attempt to match fluid temp to reservoir temp. This fluid will be the bag inflation fluid and temperature changes can affect the differential rating of the bag. c. Shear out the ball to inject through the retainer. 28. Establish injection rate thru retainer. a. If needed pump 10bbls of 12% HCI to increase injectivity. 29. Begin to mix cement. Once up to 15.8ppg, pump±15bbls of cement down the coil tubing. a. Use freshwater spacers as needed around the cement. b. Attempt to build a squeeze pressure up to 2000+psi. c. Do not overdisplace cement past the retainer. d. Contingency if squeeze locks up with cement in coil: i. Pull out of retainer and lay in cement on top of retainer. ii. Contaminate/clean out down to just above the retainer. 30. Shut down on the pumps and pull release from the inflatable cement retainer. 31. Wash down to 7,170'above the retainer and POOH. a. Freeze protect well to 2,000' while POOH. 32. RD CT unit. • • • Milne Point Unit SCHEMATIC WelastlCompleted: 7/25/1998 II Howl) L1.(- PTD: 198-056 Orig.KBE Elev.:48.2(N 22E)/GL Elev.:17.6' TREE&WELLHEAD Tree Cameron 2-9/16"5M 11"5M FMC Gen 6 w/2-7/8"FMC ;', Wellhead Tubing Hanger,2.5"CIW BPV Profile 20' 1 ! OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sx of Arcticset I(Approx.)in 24"Hole 9-5/8" Cmt w/2,031 sx PF"E",625 sx Class"G"in 12-1/4"Hole CASING DETAIL Size _ Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1#/H-40/N/A N/A Surf 112' 0.355 9-5/8" Surface 40#/L-80/Btrc. 8.835 Surf 8,213' 0.0758 4-1/2" Liner 11.6#/N-80/Nu Blank 4.00 7,048' 7,171' 0.0155 • 4-1/2" Liner 12.6#/L-80/N/A 3.958 7,165' 7,201' 0.0152 it 2 TUBING DETAIL I 2-7/8" Tubing 6.5#/L-80/8rd EUE 2.441" Surf 6,970' 0.0058 DEVIATION DETAIL STIMULATION SUMMARY Heat Trace KOP @ 350' 6/20/1998-OA Sand PropLoK Frac 60.1M#of to3,500'________•L Max Hole Angle=79°from resin coated 12-20 Ottawa sand behind pipe. 3,750'to PBTD(8,211'MD) 6/25/1998-N Sand Frac Pack 81.5M#of 16/20 Carbolite Placed behind Pipe ' JEWELRY DETAIL No Depth Item 1 116' STA#2:GLM w/Dual Screen Orifice 2 2,664' STA#1:GLM w/Empty Pocket 3 6,915 X-Over 3.5"x 2-7/8" Ti * , 3 4 ,'SnID2.313" 4 6,917 Y-Tool:Trico 3.5"Welded : = X6922' 5 6,922' OTIS 2-7/8"X Profile Nipple: (2.313 No-go ID) 6 i ', 6 6,927' Discharge Head:FPDIS 7 6,928' Pump:Type-178 FC925,Model-FPMTAR 1/1 7 "s 8 6,945' Rotary Gas Separator:FRSX HP3 9 6,948' Upper Seal Section:CL5 GSB3 UT HL AFLAS 8 il_lilal_ 10 6,954' Lower Seal Section:CL5 GSB3 LT HSN 9&10 { I 11 6,960' Motor: KMH 76 HP/1,360V/34A 655' 12 6,968.6 PHD&Stablizer-Bottom @ 6,970.5' 5/4 13 6,968.7 WLEG-Bottom @ 6,970' 11 66,,Ar 14 7,048' 9-5/8"Versatrieve Packer L., 15 7,057' Frac Closing Sleeve Assembly ��� 16 7,135' 4-1/2".020 Ga.304SS Pre-packed Screen 12 "5 13 17 7,170' 9-5/8"BWD Sump Packer 18 7,165' Collet Muleshoe Guide-Bottom @ 7,171' 14 Oli n 19 7,186' HES XU Durasleeve 15 `(1/ ' a 20 8,162' 9-5/8"EZSV Retainer d•iv PERFORATION DETAIL 16" " Schrader Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status CERM1178,18 7,130' 7,160' 3,916' 3,924' 30 12/14/2005 Open 19 ` N Sand 7,140' 7,160' 3,918' 3,924' 20 6/23/1998 Open 7,575' 7,605' 4,033' 4,040' 30 12/10/2005 Open FISH:5.25'x 1.6" t OA Sand 7,610' 7,630' 4,024' 4,048' 20 6/20/1998 Open X-Overand Glass;• .-,-,...1 s 7,660' 7,690' 4,052' 4,059' 30 12/10/2005 Open Disc Assy &HES 42 BO TOC@6112 Ref Log:Sperry Sun EWR 3/12/1998.OA Sand 6/20/1998-Atlas 28gm Jumbo Jet Charges,EHD=0.93",ttp= ShftingTool 5.2".N Sands 6/23/1998SWS 43gm Big Hole Charges.All other perforations are 2"6 Shot Per Foot. 9-5/8 ; - ! , ^^x^"20 GENERAL WELL INFO API:50-029-22864-01-00 ,_. z ,•. +1 Drilled and Cased by Nabors 22E -3/7/1998 TD=15,425'(MD)/TD=7,062'(ND) 9-5/8"Plugged Back by Nabors 22E -4/12/1998 PBTD=8,112'(MD)/PBTD=4,165'(ND) Gravel Pack&ESP Comp.by Nabors 4-ES-7/25/1998 Revised By:TDF 3/19/2018 • • • Milne Point Unit II PROPOSED SCHEMATIC Well: MPU L-37A Last Completed: 7/25/1998 ►1aenru Alaska.1,1A: PTD: 198-056 TREE&WELLHEAD Orig.KBE Elev.:48.2(N 22E)/GL Elev.:17.6' Tree Cameron 2-9/16"5M Wellhead 11"5M FMC Gen 6 w/ "FMC 20 � Tubing Hanger,2.5"CIW BPV2-7/8Profile j 1 OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sx of Arcticset I(Approx.)in 24"Hole 9-5/8" Cmt w/2,031 sx PF"E",625 sx Class"G"in 12-1/4"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1#/H-40/N/A N/A Surf 112' 0.355 9-5/8" Surface 40#/L-80/Btrc. 8.835 Surf 8,213' 0.0758 4-1/2" Liner 11.6#/N-80/Nu Blank 4.00 7,048' 7,171' 0.0155 . 4-1/2" Liner 12.6#/L-80/N/A 3.958 7,165' 7,201' 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5#/L-80/8rd EUE 2.441" Surf 6,970' 0.0058 DEVIATION DETAIL STIMULATION SUMMARY Heat Trace KOP @ 350' OA ProK Frac 60.1M#of to 3,500' Max Hole Angle=79°from resin coated 12-20 Ottawa sand behind pipe. 3,750'to PBTD(8,211'MD) 6/25/19986/20/1998--N Sand FracopLPack 81.SM#of 16/20 Carbolite Fla behind Pipe JEWELRY DETAIL No Depth Item 1 116' STA#2:GLM w/Dual Screen Orifice 2 2,664' STA#1:GLM w/Empty Pocket 3 3 6,915 X-Over 3.5"x 2-7/8" I 4 . Art II:: 2.313" 4 6,917 Y-Tool:Trico 3.5"Welded 5 46,922' 5 6,922' OTIS 2-7/8"X Profile Nipple: (2.313 No-go ID) 6 6 6,927' Discharge Head:FPDIS 7 6,928' Pump:Type-178 FC925,Model-FPMTAR 1/1 8 6,945' Rotary Gas Separator:FRSX HP3 9 6,948' Upper Seal Section:CL5 GSB3 UT HL AFLAS 8 :WI _ 10 6,954' Lower Seal Section:CL5 GSB3 LT HSN 9 810 I 11 6,960' Motor: KMH 76 HP/1,360V/34A 12 6,968.6 PHD&Stablizer-Bottom @ 6,970.5' 13 6,968.7 WLEG-Bottom @ 6,970' 11r 14 7,048' 9-5/8"Versatrieve Packer 15 7,057' Frac Closing Sleeve Assembly 16 7,135' 4-1/2".020 Ga.304SS Pre-packed Screen 12121 13 17 7,170' 9-5/8"BWD Sump Packer 14 18 7,165' Collet Muleshoe Guide-Bottom @ 7,171' I 19 7,186' HES XU Durasleeve 20 8,162' 9-5/8"EZSV Retainer PERFORATION DETAIL Schrader Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ►=-.16 ....:_,01 .17&18 7,130' 7,160' 3,916' 3,924' 30 12/14/2005 Open N Sand 7,140' 7,160' 3,918' 3,924' 20 6/23/1998 Open TOC @7,425 7,575' 7,605' 4,033' 4,040' 30 12/10/2005 Closed FISH:5.25'x 1.6" OA Sand 7,610' 7,630' 4,024' 4,048' 20 6/20/1998 Closed X-Over and Gass r)pc 7,660' 7,690' 4,052' 4,059' 30 12/10/2005 Closed asc Asst' Ref Log:Sperry Sun EWR 3/12/1998.OA Sand 6/20/1998-Atlas 28gm Jumbo Jet Charges,EHD=0.93",ttp= &Hing TOC@8,11Z 8112 Shifting ToolNow 5.2".N Sands 6/23/1998SWS 43gm Big Hole Charges.All other perforations are 2"6 Shot Per Foot. 4 20 GENERAL WELL INFO 9,5/8„ API:50-029-22864-01-00 Drilled and Cased by Nabors 22E -3/7/1998 TD=15,425'(MD)/TD=7,062'(1VD) 9-5/8"Plugged Back by Nabors 22E -4/12/1998 PBTD=8,112'(MD)/PBTD=4,165'(ND) Gravel Pack&ESP Comp.by Nabors 4-ES-7/25/1998 Revised By:TDF 3/19/2018 • MPL-37 2-14-18 • • Swab Valve Cameron FLS-2 2 9/16" 5K tree with a. 9/16" 5K, manual gate valve, IR III 2 7/8" tbg hgr n ii _ t. EE PSL2,PR2 NES T. PN 141522-31-02-01 siiii ® n/ f-„.. .:-... Wing valve Cameron FLS-2 �� —. 9/16" 5K, manual gate valve, EE PSL2,PR2 US<_ III PN 141522-31-02-01 me \ [o<p)o / SSV Cameron FLS-2 9/16" 5K, reverse actuating gate / N o .,; valve, EE.PSL2,PR2 w/ r----li" R Cameron actuator PN 111 174370-08 . 0 �< Assy PN 207043-03-03-01 m " Master Cameron FLS-2 9/ r _ .�' 16" 5K, manual gate valve, EE ` PSL2,PR2 00ii r- \ i- PN 141522-31-02-01 a0 0 o 00Or Tbg Hd adapter FMC 11" 5K LIMN.. Iil _ x 2 9/16" 5K, rotating n Ein to flanges, w/2ea control line preps and lea BIW penetrator prep and lea I wire prep. Bottom prepped for 2 7/8" seal sleeve. I PN 134132-0002 WI/ I. - 1 -4-m iilli FMC Gen 5 Tbg spool.. 11" x k. 'Pal - 10 1" 5K w/ Zea 2 1/16" 5K outs. � pJo 1I �1-i"-i i� , w - O q1 1 1,�... p I. iii lei v r • I Roby, David S (DOA) From: Paul Chan <pchan@hitcorp.com> Sent Monday, March 26,2018 9132.AM To: Roby, David S(# ) Cc: Schwartz,Guy L(DOA); Bettis, Patricia K(DOA) Subject RE:Sundry application for MPU L-37A well (PTD 198-056) Dave Hilcorp Alaska will use the L-37A N sand to monitor the new L-pad drill well patterns and the polymer pilot program for that area. Thanks Pau1 Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) From:Roby, David S(DOA) [mailto:dave.roby@alaska.gov] Sent:Wednesday,March 21.2018 11:55 A: To: Paul Chan<pchan@hilcorp.com> Cc:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject:Sundry application for MPU L-37A well(PTD 198-056) Paul, I have a quick question on the referenced sundry application. Why is the application only for plugging the Schrader OA sands and not also the N sands? For that matter,why isn't the well being P&A'd,or the very least suspended,since it hasn't produced in nearly 2 decades and when it did produce it was nothing to write home about? Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileaed information.The unauthorized review.use or disclosure of such information may violate state or federal law.It you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby@alaska.gov. 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: ,,~ Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [3 Logs of various kinds n Other Complete COMMENTS: Scanned by: Bevedy Mildred Daretha~t.owell TO RE-SCAN Notes' Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is/ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 _ Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 S gt) FEB 2 4 2012 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission _ �� 333 West 7 Avenue 1,q4 Anchorage, Alaska 99501 4 '37' Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, _______() . //h- ----- - Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPL -Pad Date: 10 /08/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPL -01A 2030640 50029210680100 Sealed conductor N/A N/A N/A N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A N/A N/A N/A NA MPL -03 1900070 50029219990000 Tanko conductor N/A N/A N/A N/A NA MPL-04 1900380 50029220290000 Sealed conductor N/A N/A N/A N/A NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A N/A N/A NA MPL -06 1900100 50029220030000 Sealed conductor N/A N/A N/A N/A NA MPL -07 1900370 50029220280000 Sealed conductor N/A N/A N/A N/A NA MPL -08 1901000 50029220740000 Sealed conductor N/A N/A N/A N/A NA MPL -09 1901010 50029220750000 Sealed conductor N/A N/A N/A N/A NA MPL -10 1901020 50029220760000 Sealed conductor N/A N/A N/A N/A NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A N/A N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A N/A N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A N/A N/A N/A NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A N/A N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job MPL -17 1941690 50029225390000 0.2 N/A 0.2 N/A 5.1 9/1/2011 MPL -20 1971360 50029227900000 0.4 N/A 0.4 N/A 3.4 8/10/2011 MPL -21 1951910 50029226290000 1.7 N/A 1.7 N/A 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 MPL -28A 1982470 50029228590100 0.3 N/A 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 N/A 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 N/A 0.5 N/A 5.1 8/10/2011 MPL -33 1971050 50029227740000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 N/A 8.5 8/9/2011 MPL -35A 2011090 50029227680100 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 ----! MPL -37A 1980560 50029228640100 6 N/A 6 N/A 47.6 8/13/2011 MPL-39 1971280 50029227860000 1.7 N/A 1.7 N/A 6.8 8/8/2011 MPL -40 1980100 50029228550000 1 N/A 1 N/A 6.8 8/8/2011 MPL-42 1980180 50029228620000 5.3 N/A 5.3 N/A 30.6 8/14/2011 MPL-43 2032240 50029231900000 17.5 Needs top job MPL-45 1981690 50029229130000 10 N/A 10 N/A 8.5 8/10/2011 _ STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS o o [] 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 46.7 KB 8. Property Designation: ADL-025514 11. Present Well Condition Summary: Total Depth measured 15426 true vertical 7062.57 Effective Depth measured 8112 true vertical 4165.45 Casing Conductor Production Sliding Sleeve Length 80 8181 129 Size 20" 91.1# H-40 9-5/8" 40# L-80 FraclDura sleeve Perforation depth: Measured depth: 7130 - 7160 True Vertical depth: 3915.67 - 3924.59 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x RECEIVED Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ~ Stratigraphic D F 6 Stimulate 0 Other 0 WaiverD At~rii~ons. Commission Re-enter Suspended WA~ r 5. Permit to Drill Number: Exploratory Service 198-0560 6. API Number: 50-029-22864-01-00 9. Well Name and Number: MPL-37 A 10. Field/Pool(s): Milne Point Field/ Schrader Bluff Oil Pool feet feet Plugs (measured) Junk (measured) None 6965 feet feet MD 32 - 112 31 - 8212 7057 - 7186 TVD 32 - 112 31 - 4189.46 3894.28 - 3932.2 Burst 1490 5750 Collapse 470 3090 ~~t\N~E!:. F F 7660 - 7690 7140 - 7160 3918.66 - 3924.59 7610 - 7630 4052.29 - 4059.38 4040.73 - 4045.32 2-7/8" 6.5# L-80 30 - 6941 9-5/8" HES Versatrieve Pkr 9-5/8" HES BWD Sump Packer 7048 7165 RBDMS BFl FEB ] 7 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after oroposed work: Exploratory Development ~ 16. Well Status after proposed work: Oil ~ Gas D WAG D Tubing pressure o o Service D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal . C::;:-þ? -....---:> Signature~~' . Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 2/10/2006 r)i~iGH;~AL Submit Original Only e e MPL-37 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMMARY 12/6/2005 Continue weather standby - Finish RU-CTU 5 and warm equipment up - Thaw injector drain hose. RIH with BOT 2 1/2 GS pulling tool. Problerms RIH (Mung?, wall friction of 1-3/4 inside 2-7/8" tubing? or combination). Swap hole to diesel... Heavy viscious Oil in returns. RIH to 6,882 circ diesel & clean up hole to TT............... Continued on 12/7/05 12/7/2005 **** Job in progress........... Pull X plug RIH to 6822. Circ well w/ diesel. Stack weight @ 6,908'. PU and RBIH to to 7,040'.. POH (no over pull through X nipple).... Pull into lub. Secure well. Standby for wind to die down. Break off well - recover plug.- MU 2" JSN PT surface equip - Wait on trucks and fluids due to rig move on MPU road. RU SLB N2 pumper...RIH @ 22:00 hrs.. pumping 1bpm 1% xskcl w/ 1000 scfm nitrogen. Returns through ASRC test sep. Job in progress......... Continued on 12/8/05 12/8/2005 Job in progress....... Continued from 12/7/05 Fill clean out w/ N2.........RIH and dry tag @ 7270. Start FCO. Pumping 1 bpm 1 % xskcl & 1,000 scfm Nitrogen. Chasing bites to TT. Very heavy Oil w/ suspended solids recovered- Wash to 7608' - Unable to re-enter pkr at 7046- POH cut 100' pipe. RBIH with 2" JSN- Unable to to re-enter pkr at 7032'. POH-add 2 stingers and 2.25" Joust noz. Did not tag/feel packer. Tag fill @ 7,605'. Clean out to 7670.... Job in progress Continued on 12/9/05 12/9/2005 Job in progress continued from 12/8/05 Continue Nitrogen FCO through ARSC test sep. FCO from 7,670' to 7,781' & Chase to surface. (1/2% solids through out CO. Did Not see any heavy solids). FP well to 2,500 with 60/40 meth. RIH with SLB logging tools-unable to get thru pkr at 7041'- RIH with centralizer on tools-got thru pkr but set down in frac sleeve at 7069'-RIH with tools in carrier and tappered noz on btm-pop thru pkr - tag btm at 8093'ctm-PUH and log from 7730' to 6700' at 60 fpm. RBIH for 2nd pass. Log 2nd pass. Roll hole over to diesel. POH LD mem tools. PU 30' of SLB 2" omega guns RIH............ Job in progress........... Continued on 12/10/05 12/10/2005 Job in progress............Continued from 12/9/05 RIH w/ SLB omega perf guns= 30' x 2" loaded at 6 spf... Perf interval 7,660- 7,690 w/ 6 spf. RIH w/ run #2 and perf interval 7575 - 7605' -POH LD gun all shots fired.( #1 gun whp pre fire T/IA 361/360 - 5 min post fire T/IA 375/379 - #2 gun whp pre fire T/lA 284/330 - 5 min post fire T/IA 306/346. Open well to flow back tanks-no flow to surface 0 whp. RIH with Oil Phase Sampler and packer. Job in progress...........Continued on 12/11/05 12/11/2005 Pump 90 bbls produced water @ 180* into ASRC well tester's tank to thaw ice in bottom of tank. 12/11/2005 Job in progress RIH w/ SLB single phase Oil Sampler... Correlate to flag @ 7,100'. Set Baker Inflatible Packer 7,181' (mid element). Start Pumping 400 scfm Nitrogen. Adjust N2 rates- unload diesel/clean out fluid- TFR 214.8 bbls 75% water cut @ 146 bpd rate. Pumping 1000 scfm Nitrogen....... Job in progress........ Continued on 12/12/05 12/12/2005 Job in progress--------- Continue Nitrogen lift on 'OA' sand. TFR 250 bbls w/ avg of 73% water cut. Out of Nitrogen @ 05:30. Job total fluid recovered 250 bbls - avg 73% WC. POH LD pkr and Sampler-lost 3 pkr elements 2.13"od in hole. Conduct weekly BOPE test-good test. RIH with PDS GR/CCL... Log interval 7750- 6700'... POH LD PDS memo logging tools. Good data Job in progress........... Continued on 12/13/05 ~ e e 12/13/2005 Job in progress continued from 12/12/05 Standby/Wait on Nitrogen to be delivered to the slope - RIH with Sampler run 2. Sheared spotting vlv- could not set pkr. POH dragging something with us. POP free at 4900'- LD sampler and pkr. Pkr was partially inflated at top end and los 1 ea 6" and 1 ea 1" element. Was able to disarm timer on sampler. RIH with drift. Tagged and pushed rubber to 7700'. POH.. PU Baker IFP and sampler for run #3.. Job in progress......Continued on 12/14/05 12/14/2005 CTU #5, Sampling; Cont' from WSR 12/13/05... RIH w/ SLB Single Phase Sampler. Correct depth at flag. Packer hung up pulling back up to depth. Packer set 6' low @ 7,187 mid element depth. Open spotting valve. Lift well with N2. Recovered 90 bbls total fluid with final water cut of 5%. Close spotting valve. Catch sample. POOH with packer and sampler. Lost two more pkr. elements. 7 inflatable packer elements left in hole to date. RIH with 30' - SWS 2.0" PJ2006 Omega HMX gun @ 6 spf. Correct depth at flag. Shot 7130' to 7160'. POOH with gun. Gun hung up pulling through 'Y' tools. Lay down gun, all shots fired. RIH with drift BHA w/ 2.25" Joust nozzle to 7600' CTMD with no apparent obstructions. Make up PDS logging tools for flag run. RIH for CT flag run. Job continued on WSR 12/15/05 ... 12/15/2005 CTU #5, Logging for Depth Control; Cont' from WSR 12/14/05... RIH w/ PDS logging tools for flag run. Log from 7400' to 6700' CTMD. Flag pipe @ 7100' (white & green). POH with PDS tools. Good data. Corrected EOP @ flag - 7068.3' (-20' correction to reference log). RU Baker 2-1/8" Retrievable IBP tool string and RIH. At flag, correct depth to center of IBP element. RIH to set IBP center of element at 7181' corrected depth. Top of IBP @ 7174'. POOH. RIH with sampler. Correct depth at flag to sample point depth. RIH, tag and confirm IBP depth - good. PUH and position sample point at 7140'. Begin lifting with N2 at 500 scf/m. Recover 157 bbls of fluid through test separator prior to tool capture set time. Shut down N2 30 minutes prior to sample capture time. POOH to recover sample. RIH and freeze protect well from 2750' with diesel. Rigging down CTU. Well left SI. *** Continued on WSR 12/16/2005 *** **** Note - IBP is still set in well and will need to be pulled at a later date *** 1/8/2006 MIRU CTU# 5. MU BOT fishing string w/ U/D jars, indexing tool, 1 degree bent sub hyd OS. Continued on 01/09/06 WSR. 1/9/2006 RIH w/ BOP fishing string w/ jars, indexing tool, 1 degree bent sub and hyd OS. Tag liner top @ 7053'. Index and pass into liner. Tag fish @ 7181'. Index to latch. Pull 16k#. Wait 30 min's. POOH. Fish in TT @ 6951', jar up 47 times and jar dn 4 times.Attempt to pump off IBP- set down and moved down hole to 6965- PU stop at TT still have IBP -RIH to 6965 - PU pop thru TT - dragging thru 2 7/8 tbg into 3.5 tbg. POH slight drag at surface. Recover mangled IBP- FP well to 2500' - Blow down coil for coil swap- Bleed down - RDMO to DS shop for coil swap. **** Job Complete **** Notify PO of well SI status **** Left in hole 1 ea 6" rubber element 1 ea 1" rubber element 6 ea 1 "x2' metal bands FLUIDS PUMPED BBLS 140 Deisel 140 Meth 14 1 % KCL 400 Gallons N2 Milne Point 2001 Shut In Wells Date Reason for Future Utility Plans & Sw Name Shut-In Well Shut-In ~ Current Mechanical Condition of Wells Possibilitiess Comments MPB-07 Jul-97 A iNo known problems ' I High GOR well, Facilities *can not handle !gas. Possible production after gas expansion project. MPB-08 May-94 E No known problems 3 Futher use as an. injector not required MPB'13 Jan-86 B GL well that was shut in due to high 3 We#house and flowlines removed water cut. Possible channel into water zone. .... MPB-17 Jan-96 E No mechanical Problems. Quick 3 We#house and flowlines removed communication with producer MPB-19 Jul-91 B GL well High water cut producer. 3 Weilhouse and flowlines removed Possible frac into water zone MPC-11 Feb-96 E No known problems " 3 Further use as an injector not required .... while associated producer shut-in MPC-12 / Jan-O0 E Fish in hole, drilling problems 3 Suspended due to drilling problems. 12a MPC-16 Aug-93 A ~,High GOR well, perfs and completion 3 We#house and flowlines removed ..... iabandoned MPC-17 May. O0 D Leak in 9 5/8" casing to surface I Evaluating possible plans for solutio~ t'o- .. problem. .. MPC-20 Apr-O0 B High water cut Well, no mechanical I Evaluating possible plans for solution to problems problem. MPC-21 Feb-02 D Problems with Jet Pump Completion I Evaluating possible plans for sOlution to problem. MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans for solution to block problem. Possible alternative uses for wellbore MPD-02/ Aug-99 B Dead ESP completion, very high water ' I Evaluating Possible Plans. 02a cut well MPE-02 Jun-OS. C No known problems 2 Recomplete tO upper Kup zone MPE-19 Aug-99 C Failed ESP on tubing s. tring 2 Well brought on line in 2002 MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole /M. pL-'IO Feb-99 E !No proof that is supports other wells ' I" Evaluating side track possibilities MPL-17 Apr-O0 B No menchanicai problems, dead ESP I Evaluating side track possibilities MPL-21 0ct-98 E High pressure block - 5000 psi, no I ' Possible use for injection when ~ressure support needed for producers . lowers iM~L~Ta.'~i~:.i ~.Nov-99 C Dead ESP, no other mechanical I Evaluating possible side track plans or issuses recompletions MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible side track plans or ....... for it. . recompietions . . , , ....... ...... *Note - Wells were shut in 100% during 2001 Milne Pt Shut In Wells 2001 .xls Well COmpliance Report File on Left side of folder 198-056-0 MD 15425 Microfilm Roll TVD 07062 MILNE POINT UNIT SB L-37A 50- 029-22864-01 BP EXPLORATION (ALASK A \ TI~.T(-~ Completion Date /98 Completed Status: 1-OIL Current: / - Roll 2 / Name L DGR/CNP/SLD-MD L DGR/CNP/SLD-TVD L DGR/EWR4-MD L DGR/EWR4-TVD R SRVY RPT T 8975 Daily Well Ops/?/q~qo~ Was the well cored? yes Comments: Interval Sent Received T/C/D (f4~AL. 3946-15426 3/5/C~ ' '~A'~a OH ........ ;)4,9; -3)~)9; ...... ~VlNAL 3136-7063 / OH 3/4/99 3/4/99 L,,~AL 3946-15426 OH 3/4/99 3/4/99 / /,~AI. 3136-7063 OH 3/4/99 3/4/99 ~iRY 10619.75-15426. OH 10/1/98 10/1/98 ~ SPERRY MPT/GR/EWR4/CNP OH 2/18/99 2/22/99 Are Dry Ditch Samples Required? yes ~__~And Receiveff?-. yes no Analysis Description Receive_y_O2_~~ .... Sample Set # c,t%, o,.6~ · ,-,% Tuesday, August 01, 2000 Page 1 of 1 0 Ftl I_1_1 ~ G S E I:IL~I ~- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPL-37 A, AK-MM-80148 March 04, 1999 MPL-37 A: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22864-01 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22864-01 2" x 5" MD Neutron & Density Logs: 50-029-22864-01 2" x 5" TVD Neutron & Density Logs: 50-029-22864-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO TltE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Si 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 F! I I--I--I IM ~S S E !:!~/I r' I= S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs February 24, 1999 MPL-37& AK-MM-80148 1 LDWG formatted Mag Tape with verification listing. API#: 50-029-22864-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETrER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Datei.-' BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silveraclo Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company -- __ STATE OF ALASKA '-' ~_~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [--~ Gas I--I Suspended I--I Abandoned ~--] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-56 398-078/398-181 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22864-01 4. Location of well at surface ?-; .... :' "' ' ": ~J ~I 9. Unit or Lease Name 3240' NSL, 4835' WEL, SEC. 8, T13N, R10E, UM ~ ..... "" ~"- '~ ~''~;'~ ' ! ~:~,,,,~.,4~_.~ i' ~, ~F%"~'_..'~... '--, Milne Point Unit Attop of productive interval !~ ! ~~ I 10. Well Number 688' SNL, 2359' WEL, SEC. 18, T13N, R10E, UM ~~ ~~1 MPL-37A At total depth ~ "%! ::i[:~'~ .: ' :- ._/,,~..._¢__<_. ...... ~ 111. Field and Pool 4717' SNL, 2780' WEL, SEC. 13, T13N, R9E, UM .......... . ...... _ Milne Point Unit/Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 48.2', ADL 025514 12. Date Spudded3/16/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Abandl15' Water depth' if °fish°re 16' N°' °f C°mpleti°ns3/20/98 7/20/98 N/A MSL One 17. Total Depth (MD+TVD)i 5425 7062 FTjI18' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set 121' Thickness °f Permafr°st8087 4159 FTI [] Yes [] No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run CGRS/GR/CCL 23. CASlNG~ LINER AND CEMENTING RECORD CASING SE-FrlNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 8212' 12-1/4" 2031 sx PF 'E', 625 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 4 spf 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5#, L-80 6941' MD TVD MD TVD Y-Tool assembly 6915'-6970' 7612'-7627' 4041 '-4045' 7140'-7160' 3919'-3924' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ~t~j,l~~_S_P49fl$. l;.Offllfll~i~i~fi August 10, 1998I Electric Submersible Pump_.~.,-~. -~ Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~ZE ' TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (CORR) Press. 24-HOUR RATE 128. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate Progress Report Facility M Pt L Pad Well MPL-37A Rig Page 4 Date 01 October 98 Date/Time 09:00-12:00 12:00-18:00 18:00-18:15 18:15-06:00 20 Mar 98 06:00-06:30 06:30-16:00 16:00-18:00 18:00-19:00 19:00-02:30 21 Mar 98 02:30-05:00 05:00-06:00 06:00-06:15 06:15-08:00 08:00-14:00 14:00-18:00 18:00-18:15 18:15-20:00 20:00-23:00 23:00-00:00 22 Mar 98 00:00-03:00 03:00-06:00 06:00-06:15 06:15-08:00 08:00-09:00 09:00-11:00 11:00-13:00 13:00-13:30 13:30-14:30 14:30-16:00 16:00-17:00 17:00-21:30 21:30-22:00 22:00-06:00 23 Mar 98 06:00-06:15 06:15-08:00 08:00-09:00 09:00-13:00 13:00-14:00 14:00-16:00 16:00-18:30 18:30-23:30 23:30-00:00 24 Mar 98 00:00-01:00 01:00-02:00 02:00-04:00 04:00-04:30 04:30-06:00 06:00-06:15 06:15-08:30 08:30-10:00 10:00-10:30 10:30-16:00 16:00-17:00 17:00-18:30 Duration 3 hr 6hr 1/4 hr 11-3/4 hr 1/2 hr 9-1/2 hr 2hr lhr 7-1/2 hr 2-1/2 hr lhr 1/4 hr 1-3/4 hr 6 hr 4hr 1/4 hr 1-3/4 hr 3hr lhr 3 hr 3 hr 1/4 hr 1-3/4 hr 1 hr 2hr 2hr 1/2 hr lhr 1-1/2 hr lhr 4-1/2 hr 1/2 hr 8hr 1/4 hr 1-3/4 hr 1 hr 4 hr lhr 2hr 2-1/2 hr 5hr 1/2 hr lhr 1 hr 2hr 1/2 hr 1-1/2 hr 1/4 hr 2-1/4 hr 1-1/2 hr 1/2 hr 5-1/2 hr lhr 1-1/2 hr Activity R.I.H. to 13272.0 ft Drilled to 13833.0 ft Held safety meeting Drilled to 14860.0 ft Held safety meeting Drilled to 15425.0 ft Circulated at 15425.0 ft Rest hole at 15425.0 ft Backreamed to 12620.0 ft R.I.H. to 14600.0 ft Backreamed to 14485.0 ft Held safety meeting Backreamed to 12806.0 ft Pulled out of hole to 663.0 ft Pulled BHA Held safety meeting Ran Drillpipe to 1315.0 ft (3-1/2in OD) Ran Drillpipe in stands to 8162.0 ft Circulated at 8162.0 ft Ran Drillpipe in stands to 14424.0 ft Washed to 14850.0 ft Held safety meeting Washed to 15075.0 ft Circulated at 15075.0 ft Washed to 15425.0 ft Circulated at 15425.0 ft Worked toolstring at 15200.0 ft Circulated at 15425.0 ft Mixed and pumped slurry - 78.000 bbl Pulled Drillpipe in stands to 12609.0 ft Circulated at 12609.0 ft Pulled Drillpipe in stands to 11559.0 ft Circulated at 11559.0 ft Held safety meeting Circulated at 11559.0 ft Ran Drillpipe in stands to 14017.0 ft Circulated at 14017.0 ft Ran Drillpipe in stands to 14640.0 ft Pulled Drillpipe in stands to 14017.0 ft Washed to 14390.0 ft Circulated at 14390.0 ft Rigged up Cement head Mixed and pumped slurry - 36.000 bbl Pulled Drillpipe in stands to 12037.0 ft Circulated at 12037.0 ft Flow check Pulled Drillpipe in stands to 9600.0 ft Held safety meeting Pulled Drillpipe in stands to 1315.0 ft Laid down 1315.0 ft of 3-1/2in OD drill pipe Installed Cement retainer Ran Drillpipe to 8162.0 ft (5in OD) Repaired Electromagnetic brake Functioned Cement retainer Progress Report Facility M Pt L Pad Well MPL-37A Rig (ead:l,)/,~'- ~ Page 5 Date 01 October98 Date/Time 25 Mar 98 26 Mar 98 27 Mar 98 18:30-19:30 19:30-20:00 20:00-20:30 20:30-04:00 04:00-06:00 06:00-06:15 06:15-18:00 18:00-18:15 18:15-06:00 06:00-06:15 06:15-08:30 08:30-10:00 10:00-10:30 10:30-13:00 13:00-14:00 14:00-15:00 15:00-16:00 16:00-18:00 18:00-18:15 18:15-20:30 20:30-02:00 02:00-04:00 04:00-06:00 06:00-07:00 07:00-09:00 09:00-11:00 11:00-13:30 13:30-14:30 14:30-15:30 15:30-18:00 Duration 1 hr 1/2 hr 1/2 hr 7-1/2 hr 2 hr 1/4 hr 11-3/4 hr 1/4 hr 11-3/4 hr 1/4 hr 2-1/4 hr 1-1/2 hr 1/2 hr 2-1/2 hr 1 hr 1 hr lhr 2hr 1/4 hr 2-1/4 hr 5-1/2 hr 2hr 2hr lhr 2hr 2hr 2-1/2 hr 1 hr lhr 2-1/2 hr Activity Mixed and pumped slurry - 20.000 bbl Reverse circulated at 8112.0 ft Serviced Fluid system Laid down 8180.0 ft of 5in OD drill pipe Repaired Electromagnetic brake Held safety meeting Repaired Electromagnetic brake Held safety meeting Repaired Electromagnetic brake Held safety meeting Repaired Electromagnetic brake Ran Drillpipe in stands to 2315.0 ft Circulated at 2315.0 ft Ran Drillpipe in stands to 8087.0 ft Circulated at 8087.0 ft Serviced Top drive Serviced Block line Circulated at 8087.0 ft Held safety meeting Circulated at 8087.0 ft Laid down 5607.0 ft of 5in OD drill pipe Freeze protect well - 150.000 bbl of Diesel Laid down 2480.0 ft of 5in OD drill pipe Removed Wear bushing Rigged down BOP stack Installed Tubing head spool Installed Xmas tree Tested Casing Installed Xmas tree integral components Serviced Fluid system Progress Report Facility M Pt L Pad Well MPL-37/~ Rig Nabors 4ES Page 1 Date 01 October98 Date/Time 18 Jun 98 00:00-01:00 01:00-03:00 03:00-06:00 06:00-12:00 12:00-13:30 13:30-17:30 17:30-20:00 20:00-22:30 22:30-00:30 19 Jun 98 00:30-04:00 04:00-06:00 06:00-06:30 06:30-12:30 12:30-17:30 17:30-21:00 21:00-22:00 22:00-23:00 23:00-01:30 20 Jun 98 01:30-03:30 03:30-06:00 06:00-12:00 12:00-13:00 13:00-15:00 15:00-16:00 16:00-18:00 18:00-19:00 19:00-02:00 21 Jun 98 02:00-03:00 03:00-06:00 06:00-09:00 09:00-10:30 10:30-13:30 13:30-14:30 14:30-22:00 22:00-04:30 22 Jun 98 04:30-06:00 06:00-08:30 08:30-12:30 12:30-13:15 13:15-03:30 23 Jun 98 03:30-04:30 04:30-06:00 06:00-09:30 09:30-14:30 14:30-18:00 18:00-22:30 22:30-23:30 23:30-04:00 24 Jun 98 04:00-06:00 06:00-06:15 06:15-07:00 07:00-11:00 11:00-11:15 11:15-12:00 Duration 1 hr 2hr 3 hr 6hr 1-1/2 hr 4 hr 2-1/2 hr 2-1/2 hr 2hr 3-1/2 hr 2 hr 1/2 hr 6 hr 5 hr 3-1/2 hr lhr lhr 2-1/2 hr 2hr 2-1/2 hr 6 hr lhr 2hr lhr 2hr 1 hr 7hr lhr 3 hr 3hr 1-1/2 hr 3hr 1 hr 7-1/2 hr 6-1/2 hr 1-1/2 hr 2-1/2 hr 4 hr 3/4 hr 14-1/4 hr 1 hr 1-1/2 hr 3-1/2 hr 5hr 3-1/2 hr 4-1/2 hr lhr 4-1/2 hr 2hr 1/4 hr 3/4 hr 4hr 1/4 hr 3/4 hr Activity Rigged down Drillfloor / Derrick Serviced Drillfloor / Derrick Rig moved 55.00 % Rig moved 100.00 % Tested Casing Installed Casing head Rigged up BOP stack Tested BOP stack Installed Tubing handling equipment Ran Tubing to 3060.0 ft (3-1/2in OD) Circulated at 3060.0 ft Held safety meeting Ran Tubing to 8120.0 ft (3-1/2in OD) Circulated at 8120.0 ft Pulled Tubing in stands to 0.0 ft Worked on BOP - Lubricator Test Lubricator unit Perforated from 7612.0 ft to 7627.0 ft Removed Lubricator Ran Tubing in stands to 7390.0 ft Rigged up High pressure lines Tested High pressure lines Injectivity test - 100.000 bbl injected at 6158.0 psi FRAC job - 200.000 bbl injected at 6332.0 psi FRAC job - 100.000 bbl injected at 6300.0 psi FRAC job - 500.000 bbl injected at 4835.0 psi Monitor wellbore pressures Bleed down well Reverse circulated at 7392.0 ft Reverse circulated at 7487.0 ft Monitor wellbore pressures Pulled Tubing in stands to 0.0 ft Made up BHA no. 1 Singled in drill pipe to 7450.0 ft Reverse circulated at 8120.0 ft Reverse circulated at 8110.0 ft Reverse circulated at 8110.0 ft Laid down 8110.0 ft of 3-1/2in OD drill pipe Serviced Block line Rig waited · Service personnel Worked on BOP - Lubricator Rig waited · Equipment Rig waited · Equipment Conducted electric cable operations Conducted electric cable operations R.I.H. to 7263.0 ft Reverse circulated at 7263.0 ft Pulled BHA Installed Hydraulic packer Held safety meeting Installed Packer assembly Ran Tubing in stands to 7220.0 ft Space out tubulars Rigged up Logging/braided cable equipment Facility Date/Time 25 Jun 98 26 Jun 98 27 Jun 98 Progress Report M Pt L Pad Well MPL-37~ Page 2 Rig Nabors 4ES Date 01 October 98 12:00-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-18:15 18:15-18:30 18:30-21:30 21:30-22:30 22:30-23:30 23:30-00:00 00:00-04:00 04:00-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-10:30 10:30-11:30 11:30-12:15 12:15-12:30 12:30-13:00 13:00-15:30 15:30-16:00 16:00-18:00 18:00-18:15 18:15-21:00 21:00-01:00 01:00-02:00 02:00-02:30 02:30-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-08:15 08:15-08:45 08:45-11:30 11:30-12:30 12:30-13:15 13:15-13:30 13:30-14:00 14:00-21:30 21:30-23:00 23:00-05:00 05:00-05:15 05:15-05:30 05:30-06:00 06:00-10:30 10:30-13:00 13:00-14:30 14:30-15:00 15:00-18:30 18:30-20:00 Duration 3hr 1 hr 1 hr lhr 1/4 hr 1/4 hr 3hr lhr 1 hr 1/2 hr 4 hr 1-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 3-1/2 hr 1 hr 3/4 hr 1/4 hr 1/2 hr 2-1/2 hr 1/2 hr 2hr 1/4 hr 2-3/4 hr 4hr lhr 1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 1/2 hr lhr 3/4 hr 1/2 hr 2-3/4 hr lhr 3/4 hr 1/4 hr 1/2 hr 7-1/2 hr 1-1/2 hr 6hr 1/4hr 1/4 hr 1/2 hr 4-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr Activity Conducted electric cable operations Rigged down Logging/braided cable equipment Reverse circulated at 7175.0 ft Circulated at 7175.0 ft Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Circulated at 7165.0 ft Functioned Packer assembly Pulled Tubing in stands to 0.0 ft Serviced Packer assembly Rigged up sub-surface equipment - Packer assembly Held safety meeting Serviced Drillfloor / Derrick Rigged up sub-surface equipment - Packer assembly Ran Tubing in stands to 7190.0 ft Circulated at 7165.0 ft Circulated at 7165.0 ft Flow check Laid down 219.0 ft of Tubing Pulled Tubing in stands to 0.0 ft Rigged up Completion string handling equipment Rigged up sub-surface equipment - Other sub-surface equipment Held safety meeting Installed Other sub-surface equipment Ran Tubing in stands to 7159.0 ft Space out tubulars Rigged up Circulating head Circulated at 7159.0 ft Circulated at 7041.0 ft Reverse circulated at 7041.0 ft Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test - 172.000 bbl injected at 5232.0 psi FRAC job - 261.000 bbl injected at 2888.0 psi Monitor pressures FRAC job - 644.000 bbl injected at 2943.0 psi Reverse circulated at 7041.0 ft Injectivity test - 0.000 bbl injected at 1990.0 psi Rigged down High pressure lines Reverse circulated at 7041.0 ft Pulled Tubing in stands to 7041.0 ft Flow check Pulled Tubing in stands to 6566.0 ft Ran Tubing in stands to 7041.0 ft Reverse circulated at 7041.0 ft Reverse circulated at 7041.0 ft (cont...) Flow check Circulated at 7041.0 ft Flow check Pulled Tubing in stands to 155.0 ft Retrieved Completion string sub-assemblies Progress Report Facility M Pt L Pad Well MPL-37~q Page 3 Rig Nabors 4ES Date 01 October 98 Date/Time 28 Jun 98 29 Jun 98 30 Jun 98 20:00-20:15 20:15-20:30 20:30-22:00 22:00-22:15 22:15-22:30 22:30-00:00 00:00-02:30 02:30-04:30 04:30-05:00 05:00-06:00 06:00-06:15 06:15-06:30 06:30-09:00 09:00-11:30 11:30-13:30 13:30-15:30 15:30-16:30 16:30-18:00 18:00-19:00 19:00-20:00 20:00-20:30 20:30-00:30 00:30-02:00 02:00-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-08:45 08:45-09:30 09:30-12:00 12:00-13:00 13:00-15:30 15:30-17:00 17:00-19:30 19:30-20:30 20:30-22:30 22:30-01:00 01:00-01:30 01:30-02:30 02:30-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-10:30 10:30-11:30 11:30-14:00 14:00-14:45 14:45-15:00 15:00-15:30 15:30-16:00 16:00-18:00 18:00-19:30 Duration 1/4 hr 1/4 hr 1-1/2 hr 1/4 hr 1/4 hr 1~1/2 hr 2-1/2 hr 2hr 1/2 hr lhr 1/4 hr 1/4 hr 2-1/2 hr 2~1/2 hr 2hr 2hr lhr 1-1/2 hr lhr lhr 1/2 hr 4 hr 1-1/2 hr 2hr 1/2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 2-1/4 hr 3/4 hr 2-1/2 hr lhr 2-1/2 hr 1-1/2 hr 2-1/2 hr lhr 2hr 2-1/2 hr 1/2 hr lhr 2-1/2 hr 1/2 hr 1/2 hr 1/4 hr 4-1/4 hr lhr 2-1/2 hr 3/4 hr 1/4 hr 1/2 hr 1/2 hr 2hr 1-1/2 hr Activity Retrieved Wear bushing Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Rigged up sub-surface equipment - Completion string sub-assemblies Ran Tubing in stands to 7046.0 ft Functioned Completion string sub-assemblies Pulled Tubing in stands to 6951.0 ft Serviced Block line Held safety meeting Serviced Drillfloor / Derrick Pulled Tubing in stands to 0.0 ft Rig waited · Equipment Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rig waited · Equipment Made up BHA no. 8 R.I.H. to 7046.0 ft Circulated at 7046.0 ft Reverse circulated at 7034.0 ft Fished at 7046.0 ft Held safety meeting Serviced Drillfloor / Derrick Pulled out of hole to 348.0 ft Pulled BHA Rig waited · Equipment Made up BHA no. 9 R.I.H. to 7011.0 ft Fished at 7045.5 ft Pulled out of hole to 348.0 ft Pulled BHA Made up BHA no. 10 R.I.H. to 7030.0 ft Washed to 7045.0 ft Fished at 7047.0 ft Pulled out of hole to 307.0 ft Pulled BHA Rig waited · Assessed situation Rig waited · Assessed situation (cont...) Rig waited · Equipment Made up BHA no. 11 R.I.H. to 7040.0 ft Washed to 7050.0 ft Singled in drill pipe to 7053.0 ft Washed to 7053.0 ft Pulled out of hole to 7045.0 ft Reverse circulated at 7045.0 ft Singled in drill pipe to 7192.0 ft Progress Report Facility M Pt L Pad Well MPL-37tq Page 4 Rig Nabors 4ES Date 01 October 98 Date/Time 01 Jul 98 02 Jul 98 03 Jul 98 19:30-20:00 20:00-00:00 00:00-01:30 01:30-05:00 05:00-06:00 06:00-06:15 06:15-06:30 06:30-07:00 07:00-08:00 08:00-11:30 11:30-13:00 13:00-14:00 14:00-20:00 20:00-20:30 20:30-23:00 23:00-23:15 23:15-00:00 00:00-02:00 02:00-02:30 02:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-07:15 07:15-08:00 08:00-08:30 08:30-09:30 09:30-10:00 10:00-11:30 11:30-14:30 14:30-17:00 17:00-20:30 20:30-22:00 22:00-22:30 22:30-00:00 00:00-01:00 01:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-06:15 06:15-06:30 06:30-10:00 10:00-11:00 11:00-13:00 13:00-13:30 13:30-14:00 14:00-14:15 14:15-14:45 14:45-15:00 15:00-16:00 16:00-16:45 16:45-17:00 Duration 1/2 hr 4 hr 1-1/2 hr 3-1/2 hr lhr 1/4 hr 1/4 hr 1/2 hr lhr 3-1/2 hr 1-1/2 hr lhr 6hr 1/2 hr 2-1/2 hr 1/4 hr 3/4 hr 2hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 3/4 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 3hr 2-1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1 hr 2hr 1 hr 1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 3-1/2 hr 1 hr 2 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 1/4 hr lhr 3/4 hr 1/4hr Activity Pulled out of hole to 7045.0 ft Reverse circulated at 7045.0 ft Flow check Pulled out of hole to 337.0 ft Pulled BHA Held safety meeting Serviced Drillfloor / Derrick Rig waited: Equipment Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rig waited: Equipment Made up BHA no. 12 R.I.H. to 7034.0 ft Washed to 7047.0 ft Functioned Other sub-surface equipment Reverse circulated at 7045.0 ft Laid down 63.0 ft of 3-1/2in OD drill pipe Circulated at 7040.0 ft R.I.H. to 7047.0 ft Functioned downhole tools at 7047.0 ft Functioned downhole tools at 7047.0 ft (cont...) Flow check Laid down 95.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 4609.0 ft Serviced Block line Pulled out of hole to 11.0 ft Pulled BHA Made up BHA no. 13 R.I.H. to 7045.0 ft Fished at 7045.0 ft Pulled out of hole to 336.0 ft Pulled BHA Ran Tubing in stands to 950.0 ft Laid down 950.0 ft of Tubing Made up BHA no. 13 R.I.H. to 7045.0 ft Functioned downhole tools at 7045.0 ft Tested Other sub-surface equipment - Via annulus and string Laid down 3325.0 ft of 3-1/2in OD drill pipe Held safety meeting Serviced Drillfloor / Laid down 2790.0 ft Circulated at 2216.0 Laid down 2779.0 ft Pulled BHA Derrick of 3-1/2in OD drill pipe of 3-1/2in OD drill pipe Rigged down Tubing handling equipment Retrieved Wear bushing Installed Tubing hanger Installed Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Facility M Pt L Pad Progress Report Well MPL-37/} Rig Nabors 4ES Page Date 5 01 October 98 Date/Time 17:00-17:15 17:15-17:30 17:30-18:00 Duration 1/4 hr 1/4 hr 1/2 hr Activity Retrieved Hanger plug Installed Hanger plug Rigged down High pressure lines Progress Report Facility M Pt L Pad Well MPL-37/4 Rig Nabors 4ES Page 1 Date 01 October 98 Date/Time 15 Jul 98 13:00-18:00 18:00-20:00 20:00-21:00 21:00-23:30 23:30-03:00 16 Jul 98 03:00-04:00 04:00-06:00 06:00-07:00 07:00-11:00 11:00-14:00 14:00-15:00 15:00-16:30 16:30-17:00 17:00-20:00 20:00-20:30 20:30-21:30 21:30-00:30 17 Jul 98 00:30-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-11:00 11:00-11:30 11:30-13:30 13:30-17:00 17:00-18:00 18:00-21:30 21:30-01:00 18 Jul 98 01:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-13:00 13:00-18:00 18:00-22:30 22:30-06:00 19 Jul 98 06:00-06:30 06:30-08:30 08:30-11:30 11:30-13:00 13:00-16:30 16:30-17:30 17:30-18:00 18:00-19:00 19:00-06:00 20 Jul 98 06:00-06:30 06:30-11:00 11:00-17:00 17:00-18:00 Duration 5hr 2 hr lhr 2-1/2 hr 3-1/2 hr lhr 2 hr 1 hr 4 hr 3hr 1 hr 1-1/2 hr 1/2 hr 3hr 1/2 hr lhr 3hr lhr 2hr 1 hr 1-1/2 hr 1/2 hr lhr lhr 2-1/2 hr 1/2 hr 2hr 3-1/2 hr 1 hr 3-1/2 hr 3-1/2 hr 3 hr lhr 1 hr 1/2 hr lhr 1/2 hr 5hr 5 hr 4-1/2 hr 7-1/2 hr 1/2 hr 2 hr 3hr 1-1/2 hr 3-1/2 hr lhr 1/2 hr lhr llhr 1/2 hr 4-1/2 hr 6 hr lhr Activity Rig moved 100.00 % Rigged up High pressure lines Removed Xmas tree Rigged up BOP stack Tested BOP stack Made up BHA no. 1 Singled in drill pipe to 2200.0 ft Circulated at 2200.0 ft R.I.H. to 6056.0 ft Pulled out of hole to 35.0 ft Worked on BOP - Bottom ram Tested Pipe ram Made up BHA no. 2 R.I.H. to 7018.0 ft Worked toolstring at 7045.0 ft Reverse circulated at 7045.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 3 R.I.H. to 7047.0 ft Worked toolstring at 7208.0 ft Pulled out of hole to 5200.0 ft Held safety meeting Pulled out of hole to 3000.0 ft Serviced Block line Pulled out of hole to 0.0 ft Made up BHA no. 4 R.I.H. to 7241.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 5 R.I.H. to 7045.0 ft Conducted electric cable operations Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 6 R.I.H. to 2000.0 ft Held safety meeting R.I.H. to 7675.0 ft Laid down 630.0 ft of 3-1/2in OD drill pipe Circulated at 7045.0 ft Laid down 7045.0 ft of 3-1/2in OD drill pipe Ran Tubing to 0.0 ft (2-7/8in OD) Rigged up sub-surface equipment - ESP Installed Pressure gauge Ran Tubing to 1690.0 ft (2-7/8in OD) Serviced ESP Ran Tubing to 2980.0 ft (2-7/8in OD) Serviced ESP Conducted slickline operations on Slickline equipment - Setting run Ran Tubing to 3447.0 ft (2-7/8in OD) Rigged up Completion string handling equipment Ran Tubing in stands to 5635.0 ft Held safety meeting Ran Tubing in stands to 6941.0 ft Installed Tubing hanger Removed BOP stack Progress Report Facility M Pt L Pad Well MPL-37 Jt Rig Nabors 4ES Page 2 Date 01 October 98 Date/Time 18:00-19:30 19:30-20:00 20:00-22:00 22:00-00:00 Duration 1-1/2 hr 1/2 hr 2hr 2hr Activity Installed Xmas tree Tested Xmas tree Freeze protect well - 150.000 bbl of Diesel Removed High pressure lines Milne Point Unit, Alaska TO: Bixby / March FROM: Thackeray Well Name: IMP L-37 Main Category: IDRLG COMPL Sub Category: IEline Perf Operation Date: 16/19-20/98 Date: 16-20-98 Objective: E-line convey perforate the Schrader Bluff "OA" sands. Sequence of Events: 6/19/98 22oo 2245 2305 2320 2355 RU Atlas. MU Tools and guns on rollers PJSM P/T Lubricator to 500 psi Rih with gun and GR on rollers Stalled out at 6135' (78 degrees) Worked over hump and resumed rolling 6/20/98 o000 0040 0100 0105 0110 Make correlation pass 7800 - 7450' to tie into MWD log 3/13/98 Make depth correction and drop back down to 7950' Make another pass to confirm on depth (GR scale on MWD didn't have much character and was difficult to correlate to) Confirmed correlation and positioned gun Perforated "OA" sand from 7612-7627' with 4 1/2" guns loaded 4 spf with "Big Hole" charges at 0-180 degree phasing POOH RD Atlas Results: Perforated the Schrader Bluff "OA" sand from 7612 - 7627 (15') with 4 1,~,, gun with 4 Big Hole spf at 0-180 degree phasing. Tie in log/date: Sperry MWD 3/13/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter [7612 11~ 114 ~/2 Shot Density Orientation Phasing BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: FROM: Jim Spearman / Ricardo Solares Jim Fox DATE: 06/20/98 -- RE: MPU L-37 '©A' SAND DATA FRAC, SCOUR, AND FRAC SERVICE CO'S.' Dowell, Halliburton, Nabors, and Peak I I JOB SUMMARY 60.1 M# lbs. of 12-20 Ottawa sand proppant coated with Halliburton PropLok resin was placed behind pipe in the OA Sand. The frac design was 70 M#. This was cut short when the PropLok resin ran out prematurely. There were some metering inaccuracies and the PropLok was pumped at an ave. concentration of 0.44 gal. / 100# rather than the 0.375 gal. / 100# as per design. Flush was called when the densimeter started to decline and then underflushed by 10 bbls. It was later realized that the last of the PropLok coated proppant was 16 bbls prior to when flush was called putting potentially 10 bbl. of uncoated 8 ppg slurry into the formation. Pump rate at the end of the displacement was slowed in an attempt to induce a screen out. The last 13 bbl of displacement were pumped at under 9 bpm and it is believed that at this rate in 9 5/8" casing that the velocity would not suspend the proppant and the uncoated sand was not carried into the perforations. This is supported by the fact that upon cleanout proppant was tagged just 20' below the tubing tail. The fracture did not show indication of closure as the rate was reduced even at 3 and 4 bpm. In light of this the technique of slowing down to induce screenout ( when slurry drops out into casing ) seems to have little upside and more potential for downside. The 100 bbl. injectivity test indicated that there was a moderate amount (330 psi) NWFP. It did not appear to decline any during the 200 bbl. data frac. A scour consisting of: 25 bbl. gel pad, 50 bbl I ppg slurry (1900 # of sand), and 25 bbl. gel sweep was over displaced by 5 bbls. into the formation in an unsuccessful attempt to reduce the NWFP. The treating pressure however was approx. 200 psi lower than the injectivity and data frac (i.e. the treating pressure was 200 lower but so was the ISIP). Notes: · HEC gel loading was increased to 80 ppt on this frac due to suspicions on the last well (H-08) that sand may be falling out in laminar flow of the casing (7"). In 9 5/8' the velocity would be that much less. · The resin was not dyed as in some wells in the past as the dye was suspected of contributing to reduction of resin coating of proppant. · 12-20 Ottawa sand was used due to it's ability to coat with resin better than Carbolite, it's angularity aides in not being produced back into the wellbore, and is lower cost. · Due to breakup all gel was premixed on A Pad in 100 bbl. loads, transported to frac tanks on site · During the injectivity test and data frac the gel was circulated to the end of the tubing, bullheaded at 2 bpm (matrix rate) to the perfs and shut in for a couple minutes before coming up to rate. The scour and frac were bullheaded from the start. · With gel temperatures of 80 deg., relatively warm proppant temperatures, and time constraints it was decided to not heat the gel. This also makes for more consistent gel temperatures. · Friction pressure in the tubing was higher than usual in this well due to the tubing length and the use of the PH6 tubing with a slightly smaller ID (2.75" as compared to regular 9.3 ppf tbg. w/2.992"). 07/07/98 2:35 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL TIMEI RATEBPM ANNP WHP STAGE PSIG PSIG BBL PUMPING SUMMARY COMMENTS CUM BBL INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP psi ISIP, NWFP Treat grad, BPM Pumped bpm psi friction, psi psi/ft max. 100 & 5 27.5 1428 1100 330 0.71 bbl. wtr DATA FRAC Bbls Bbls gel to Time gel on Final lAP ISIP, psi NWFP Treat grad, Pumped Perfs perfs STP, psi friction, psi _ psi/ft 200 200 & 5 wtr. 12. min. 1415 1087 330 0.71 SCOUR Rate, Slurry Pumped Sand Final lAP psi ISIP, NWFP Treat grad, BPM pumped psi friction, psi psi/ft 20 50 bbl. @ 1 ppg 1900 lbs, 1220 901 320 0.66 FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left in Job was lbs. lbs. pipe, M# lbs. M# hole? /size /size flush 63,780 60,150 not appl. 70,000 4780 not appl. 12/20 DATE/TIME OPERATIONS SUMMARY 06/13/98 1200 Pre-job safety meeting 1245 Pressure test surface equipment to 7800 psi 1255 Start circulatin9 9el down tubing for injectivity test. 1318 Start displacing gel for injectivity test. 1322 Slow rate down to 20 bpm. 1323 S/D pumps and monitor pressure falloff. 1400 Start circulatin9 in gel for data frac. 1422 Start displacing gel for data frae. 1434 S/D pumps and monitor pressure falloff. 1538 Start pumping scour. 1547 S/D pumps and monitor pressure falloff. 1810 Start pumping pad for frac. 1840 Wellbore screened out. S/D pump and prepare to reverse out. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 06/20/98 INJECTIVITY TEST DISPLACEMENT = ?2.2 BBL$ 1255 0 0 0 0 0 With the choke open start circ. 80 # gel to the end of the tubing. Returns going to the rig pits 1256 8 145 1370 8 8 At rate. 1300 8.2 148 1631 35 35 1302 8 / 2 148 1631 52 52 Slow down to close choke. 1303 . 1.9 1086 1236 53 53 1305 1.9 1221 2290 58 58 1308 2.0 1077 2198 63 63 1312 2 / 0 1112 2253 72.3 72.3 Gel at perfs. S/D pumps.Allow press to bleed off. 1318 0 / max. 674 775 72.3 72.3 Start injectivity test. 1319 17 1544 4254 83 83 1320 23.8 1827 4680 100 / 0 100 Switch to seawater for flush. 1321 23.3 1560 4895 28 128 1322 20.0 1452 5339 56 156 Problem with pumps maintainig max. rate. Slow down to 20 bpm slightly earlier than design 1323.3 19.2 1428 6158 78.2 178.2 With 6 bbls. overdisplacement S/D pumps and I monitor pressure falloff. ISIP - 1100 psi, NWFP i = 328 psig 1325 . 0 I 901 1022 1330 i 0 798 917 ; I 683 793 1340 ~ 0 I 1350 0 1610 715 PUMPING SUMMARY TIME I RATE ANNPI WHP STAGE CUM BPM I PSIG PSIG BBL BBL COMMENTS DATA FRAC 1400 0 / 8 0 88 0 178.2 Start circulating gel down to EOT. 1402 8.0 150 1402 20 198 1404 8.0 147 1503 33 211 1406.5 8 / 2 145 900 52 230 Slow rate to 2 bpm and close in choke. 1409 2.0 1190 2134 57 235 1413 2.0 1232 2230 65 243 ,1416.5 2 / 0 1185 2203 72 250.1 Gel at perfs. S/D pumps and allow pressrure to bleed off 1422 0 / 20 840 944 72 250.1 Start data frac. Bring pumps up to 20 bpm. 1424 20 1467 263 20 270 At design rate. 1426 20.1 1426 4442 126 304 1428 20.1 1441 4419 164 342 1429.5 20.1 1456 4451 200 378 Switch to seawater and go to flush. 1432 19.7 1430 5499 45 423 1434 20 / 0 1415 6332 78 456.0 With 5 bbl. overdisplacement S/D pumps and monitor press, falloff. ISIP = 1087 NWFP = 328 1435 0 910 1027 144O 0 859 972 1445 0 828 940 1450 0 804 912 1500 0 762 866 1510 0 725 830 152O 0 696 798 1530 0 668 770 SCOUR 1538 0 / 20 646 747 0 456 Start bullheading gel pad for scour 1539 20 1249 6355 14 470 At design rate. 1540.5 19.9 1196 5119 44 500 1542 I 19.9 1203 4002 72/0 528 Gel on perfs. 1543I 20.1 1273 4140 25 / 0 553 Sand on perfs. 1546 [ 19.9 1247 5362 50 / 0 603 Sand through perfs. 1547 I 19.9 1220 6268 25 633 Overdisplace by 5 bbl. S/D pumps. Monitor pressure falloff, ISIP = 90, NWFP = 321 1550 I 0 839 953 1600 t 0 787 903 ,1607 0 769 880 ~ , PUMPING SUMMARY TIMEI RATE ANNP WHP I STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 1809.5 0 / 20 676 876 0 0 Start pad. 1811 20 1157 6121 21 21 At design rate. 1812 20.4 1106 5265 42 42 88 deg pod temp. 1813 20.2 1068 4153 62 62 84 deg. pod temp. 1814 20.1 1049 4080 72 72 1816 20.3 1139 3993 120 1818 20.1 1137 4025 156 1 PPG on perfs 1820 20.1 1135 4016 200 1821.2 19.9 1126 4034 227 2 ppg on perfs. 1822.5 20.1 1126 4190 251 3 ppg on perfs 1823.7 20.1 1132 4345 274 4 ppg on perfs. _ 1825 19.9 1141 4455 300 1826 20.2 1143 4620 322 5 ppg on perfs. 1828.3 20.2 1150 4799 369 6 ppg on perfs. 1830 20.2 1163 4858 400 1832 20.2 1139 4835 441 7 ppg on perfs. 1833.5 19.7 1108 4748 470 Resin tub ran dry w/o warning, abort remainder. 1834 19.7 1106 4744 480 1835.5 19.4 1143 5290 515 1837 14.6 1101 3888 539 Start slowing down rate in an attempt to induce screen out 1838 8.2 1018 2533 551 Continue slowing down rate. 1839 4.1 963 1823 556 1839.5 3 ! 0 965 1361 558.1 S/D pumps. Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 880 Bbls FRAC: 558 Bbls 1438 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME ll not applicable PETREDAT WINDOW FLUID ADDITIVES 80 ppt. HEC gel: filtered seawater for make up water (no KCI added) 3.4 # / bbl Dowell HEC gel 2 gal/1000 F-75N (surfactant) run only in Injectivity Test and Data Frac Halliburton surfactant - run through frac Fluid QC was more complicated that usual in that the gel had to be mixed in 100 bbl. batches (due to breakup gel is being built by Baroid on A Pad). Viscosities when mixed varied f/168 to 153 at temperatures of approx. 80 deg. F. With a target pH of 6.5 citric acid was used to achieve a range of 5.6 to 6.9. Turbidity: gel - batch #4 - 193 ntu, gel batch no. 9 - 207 ntu, filtered seawater - 3.7 ntu, - 2.8 ntu Milne Point Unit, Alaska TO: MPU Telex Group FROM: Kirby Walker Well Name: IMPL-37 Main Category: IPERF Sub Category: IE-LINE Operation Date: 16/23/98 Date: I June 23, 1998 Objective' To perforate the Schrader Bluff 'N Sand' from 7140' - 7,160' using Schlumberger e-line unit. Sequence of Events: 0130 0400 O9OO O93O 1100 1245 1430 1540 1550 1555 1600 SWS arrive on location Noticed that gun were 4 spf; 12 spf needed for gravel packing N sand. Sent for other guns. 12 spf guns arrived on location RIH w/CCL + gun assembly Realized that no CCL log exists to tie-in with. Have Gun GR sent from Deadhorse. On surface with CCL and gun assembly RIH w/Gun GR + gun assembly On bottom Tie-in to depth. Fire guns - positive indication of guns firing. POOH Results' Schrader Bluff 'N Sand' was perforated from 7,140'-7,160' (3,918'-3,924' TVD) using Schlumberger's gun configuration noted below. Tie in log/date MWD log / 4-28-98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density 7,140 (3,918)I [ 7,160 (3,924)!1 4.5 J] 12 Orientation Phasing II N/A J[ 45/135 Page 1 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Bill Hill FROM: Kirby Walker DATE: ~ 25, 1998 RE' L-37 (N) DataFRAC AND FRAC SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors JOB SUMMARY Halliburton's Pre-packed screen (30') and 60' of blank pipe was run on rig 4ES to cover the Schrader Bluff N Sand. A 100 bbl injectivity test was circulated to the MPT tool where rate was decreased to allow for the choke to be closed. Once gel was on perfs, pumps were shutdown before bringing rate to 20 BPM to complete the test. For the last 20 BBL rate was dropped to 12 BPM. ISIP was recorded after shutdown and pressure was recorded for 5 minutes before the DataFRAC was started. The 200 bbl DataFRAC was also circulated down the tubing, the choke closed, and the fluid was injected at 2 BPM to the perfs where pumps were shutdown. Rate was regained at 12 BPM to inject the entire 200 BBL of 60# HEC plus a 5 BBL seawater over-displacement. Pumps were shutdown and pressure monitored and sent to Anchorage for analysis. A leakoff of 0.11 ft/min0.5 and the job redesigned. 64,400# of 16/20 CarboLite was planned to be pumped. After 8 PPA hit zone and there was no pressure build it was decided to increase proppant concentration to 9 PPA and then 10 PPA. A total of 89,388# of proppant was pumped and displaced. With 25 BBL of slurry left in the workstring rate was dropped to 2 BPM. The choke was not able to be opened until just prior to shutting down the pumps. The re-stress test showed that 40' feet of the blank was covered. I NJ ECTIVITY TEST Design Rate, Bbls Max Rate, Final STP psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft max 100 20 5163 2649 100 0.675 DATA FRAC Bbls ISIP Closure Closure Time Leakoff NWB friction, Treat grad, Pumped psi Pressure observed psi psi/ft 200 2711 2663 2.6 0.11 79 0.67 Page 2 FRAC Sand Prop Prop Proppant Prop in Tresaver pumped, behind pipe, left in csg, size/type Blank, M# rubber left in Job was M# M# M# hole? flushed 89,388 81,569 4,347 16/20 3,472# N/A CarboLite Ft of Estimated Final ISIP, psi ISIP Incr % PAD TSO, TSO, sand in sand top STP, over (pad/slurry) design, min Nolte Pipe psi datafrac Plot none N/A 1428 802 -33 26.9 15 N/A Comments TIME OPERATIONS SUMMARY 0630 Safety Meeting 0715 Pressure Test treating lines - 7,988 psi 0818 DataFRAC 1130 FRAC TIME I RATE I BPM PUMPING SUMMARY ANNP WHP STAGE CUM PSIG PSlG BBL BBL COMMENTS INJECTIVITY TEST DISPLACEMENT = 61.4 BBLS 0734 3.25 13 500 10 - Determine circulating pressure, seawater 0739 7.1 37 1941 100 10 Circulate HEC to packer HEC 0746 2.21 29 820 54 Slow rate 0749 2.5 33 870 60 Close choke 0752 - 938 1085 66.8 Shutdown 0757 20 1242 4294 66.8 Start Injectivity Test 0800 20 1177 4307 61.8 100 Displace gel seawater 0802 12 939 3076 151 Slow rate to 12 BPM 0803 - 937 3200 171 Shutdown ISIP - 2649 psi NWBF- 100 psi Grad. - 0.675 0813 Bleed off annulus - open choke Page 3 DATA FRAC DISPLACEMENT = 61.4 BBLS 1 0818 7.65 I 29 2069 200 Circulate HEC to packer 0825 2 26 1254 50 Slow rate to shut choke 0828 0 681 805 57 Shutdown 0832 12 952 2888 57 Start DataFRAC 0843 12 901 2765 61 200 Start seawater displacement 08 - 261 Shutdown ISIP - 2629 psi NWBF - 79 psi Grad. - 0.670 FRAC DISPLACEMENT = 40 BBLS 1130 12 1002 3401 129 Start PAD 1135 12 881 2719 54.9 Pad on Zone 1141 12 903 2646 52 129 Start 1 PPA 1145 12 892 2586 24 181 Start 2 PPA 1146 12 890 2591 183.5 1 PPA on Zone 1148 12 894 2591 24 205 Start 3 PPA 1150 12 886 2614 47 229 Start 4 PPA 1150 12 886 2636 236 2 PPA on Zone 1152 12 r 886 2705 259 3 PPA on zone 1153 12 886 2769 47 276 start 5 PPA 1154 12 886 2792 283 4 PPA on Zone 1157 I 12 879 2965 47 323 Start 6 PPA 1158 I 12 879 2989 331 5 PPA on Zone 1201 t 12 883 2989 71 370 Start 7 PPA 1202 . 12 881 2998 378 6 PPA on Zone 1206 12 879 2893 425 7 PPA on Zone 1207 12 883 2920 441 Start 8 PPA 1212 [ 12 879 2929 496 8 PPA on Zone 1215 I 12 877 2943 538 Increase PPA to 9 1217 I 12 877 2934 550 Increase PPAto 10 1220 12 875 3048 593 9 PPA on Zone 1221 12 881 3108 605 10 PPA on Zone 1221 12 881 3108 608 Cut Sand 1223 12 883 3241 630 Switch to source water 1223 I 2 830 1533 628 Slow Rate 1225 . - 817 1506 644 Shutdown 1233 I Bleedoff annulus - Reverse out 2 tubing volumes 1314 , 1.19 661 1900 Re-stress gravel pack Page 4 FLUIDS PUMPED DOWNHOLE INJ TEST 171 BBLs DATA FRAC: 261 BBLs FRAC: 605 BBLs GEL QUALITY CONTROL CHECK seawater HEC HEC HEC PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.2 66 6.0 96 4.41 N/A N/A FLUID ADDITIVES J-134 (enzyme breaker) - 2#/1000gal F-75N (surfactant) - 2 gal/1000 gal Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPL-37/~ Your Ref: 500292286400 Alaska State Plane Zone 4 Milne Point L Pad Measured Depth (ft) 10617.75 10653.00 10715.27 10811.34 10907.70 11001.68 11097.71 11190.38 11288.04 11383.51 11478.75 11573.67 11669.41 11765.21 11860.63 11955.40 12052.86 12147.00 12243.37 12338.39 12432.06 12525.11 12617.31 12710.80 12802.68 12896.45 12990.20 13082.53 13173.77 13266.76 Incl. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) 76.780 221.220 4603.39 4650.09 6649.81 S 4886.47 W 76.300 221.020 4611.59 4658.29 6675.63 S 4909.01 W 74.110 219.770 4627.49 4674.19 6721.48 S 4948.03 W 73.560 219.830 4654.24 4700.94 6792.37 S 5007.09 W 72.630 219.800 4682.26 4728.96 6863.19 S 5066.12 W 72.250 219.740 4710.61 4757.31 6932.06 S 5123.44 W 71.200 222.360 4740.73 4787.43 7000.82 S 5183.31 W 71.930 225.580 4770.04 4816.74 7064.08 S 5244.34 W 71.930 228.340 4800.34 4847.04 7127.44 S 5312.19 W 71.790 230.350 4830.07 4876.77 7186.54 S 5381.02 W 72.240 232.570 4859.48 4906.18 7242.97 S 5451.87 W 72.670 235,690 4888.10 4934.80 7296.00 S 5525.20 W 72.230 237.810 4916.97 4963.67 7346.04 S 5601.53 W 72.650 241.770 4945.88 4992.58 7391.99 S 5680.45 W 72.260 246.310 4974.66 5021.36 7431.80 S 5762.22 W 72.070 247.330 5003.69 5050.39 7467.32 S 5845.15 W 71.540 250.710 5034.13 5080.83 7500.46 S 5931.58 W 71.440 254.140 5064.02 5110.72 7527.41 S 6016.67 W 71.540 256.630 5094.62 5141.32 7550.47 S 6105.09 W 71.470 259.440 5124.77 5171.47 7569.15 S 6193.23 w 71.050 260.750 5154.86 5201.56 7584.41 S 6280.61 W 70,630 260.860 5185.40 5232.10 7598.45 S 6367.38 W 69.890 259.750 5216.54 5263.24 7613.07 S 6452.92 W 69.430 258.780 5249.04 5295.74 7629.39 S 6539.04 W 68.850 258.880 5281.76 5328.46 7646.03 S 6623.28 W 68.330 257.640 5315.99 5362.69 7663.79 S 6708.75 W 67.700 257.930 5351.09 5397.79 7682.18 S 6793.71 W 66.570 259.770 5386.96 5433.66 7698.64 S 6877.17 W 65.960 259.260 5423.69 5470.39 7713.83 S 6959.30 W 65.840 257.480 5461.66 5508.36 7730.95 S 7042.44 W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 6024751.79 N 540199.86 E 8117.32 6024725.83 N 540177.47 E 1.469 8151.44 6024679.75 N 540138.74 E 4,017 8211.28 6024608.50 N 540080.10 E 0.576 8302.88 6024537.33 N 540021.50 E 0.966 8394.42 6024468.11 N 539964.60 E 0.409 8483.37 6024398.99 N 539905.15 E 2.812 8574.10 6024335.36 N 539844.50 E 3.389 8661.90 6024271.59 N 539777.04 E 2.687 8754.74 6024212.07 N 539708.57 E 2.006 8845.36 6024155.21N 539638.07 E 2.267 8935.62 6024101.75 N 539565.06 E 3.167 9025.35 6024051.24 N 539489.03 E 2.161 9115.22 6024004.81 N 539410.39 E 3.965 9204.15 6023964.50 N 539328.86 E 4.555 9290.96 6023928,49 N 539246.15 E 1.044 9375.66 6023894.82 N 539159.92 E 3.339 9461.29 6023867.35 N 539075.00 E 3.457 9541.68 6023843.76 N 538986.72 E 2.452 9621.83 6023824.55 N 538898.69 E 2.805 9698.77 6023808.76 N 538811.40 E 1.398 9772.81 6023794.19 N 538724.73 E 0.465 9845.57 6023779.06 N 538639.27 E 1.389 9917.83 6023762.21 N 538553.25 E 1.090 9991.69 6023745.07 N 538469.12 E 0.639 10064.38 6023726.79 N 538383.76 E 1.350 10138.75 6023707.88 N 538298.91 E 0.731 10213.18 6023690.92 N 538215.55 E 2.207 10285.19 6023675.22 N 538133.51 E 0.842 10355.37 6023657.61N 538050.48 E 1.752 10427.60 Comment Tie-On Survey Window Point Continued... 2 April, 1998- 18:43 ,1 - DrillQuest Milne Point Unit Measured Depth (rt) Incl. 13360.72 13453.38 13547.35 13642.11 13735.73 13831.22 13924.41 14016.78 14110.14 14200.86 14294.82 14387.56 14482.49 14576.43 14667.13 14758.64 14852.32 14946.37 15040.00 15132.66 15225.95 15318.63 15426.OO Azim, Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 65.140 258.250 5500.64 5547.34 7748.92 S 7126.02 VV 63.290 260.350 5540.95 5587.65 7764.42 S 7207.99 W 60.950 259.580 5584.89 5631.59 7778.89 S 7289.78 W 57.660 258.570 5633.26 5679.96 7794.31 S 7369.77 W 55.270 259.210 5684.97 5731.67 7809.36 S 7446.34 W 53.620 260.040 5740.50 5787.20 7823.35 S 7522.75 W 51.730 259.870 5797.00 5843.70 7836.28 S 7595.72 W 50.820 259.790 5854.78 5901.48 7849.00 S 7666.65 W 47.750 260.700 5915.68 5962.38 7861.00 S 7736.38 W 44.220 259.820 5978.70 6025.40 7872.02 S 7800.67 W 41.200 260.220 6047.74 6094.44 7883.07 S 7863.43 W 38.640 260.870 6118.86 6165.56 7892.86 S 7922.13 VV 36.070 262.870 6194.31 6241.01 7901.03 S 7979.13 VV 32.820 264.790 6271.77 6318.47 7906.77 S 8031.94 W 30.950 263.460 6348.79 6395.49 7911.66 S 8079.59 W 30.370 262.700 6427.50 6474.20 7917.28 S 8125.92 W 29.250 262.630 6508.79 6555.49 7923.23 S 8172.11 VV 28.990 262.560 6590.95 6637.65 7929.13 S 8217.49 W 28.520 263.290 6673.03 6719.73 7934.68 S 8262.19 W 27.800 262.710 6754.72 6801.42 7940.00 S 8305.59 W 27.420 262.750 6837.39 6884.09 7945.47 S 8348.48 W 26.680 262.470 6919.93 6966.63 7950.89 S 8390.28 W 26.680 262.470 7015.87 7062.57 7957.21 S 8438.07 VV Survey Report for MPL-37/~ Your Ref: 500292286400 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 6023639.13 N 537967.01E 1.054 10500.74 6023623.13 N 537885.14 E 2.855 10571.01 6023608.17 N 537803.44 E 2.593 10640.43 6023592.26 N 537723.54 E 3.591 10709.22 6023576.75 N 537647.06 E 2.616 10775.24 6023562.29 N 537570.74 E 1.867 10840.44 6023548.93 N 537497.85 E 2.033 10902.39 6023535.77 N '537427.00 E 0.987 10962.72 6023523.35 N 537357.34 E 3.370 11021.69 6023511.94 N 537293.12 E 3.953 11076.02 6023500.51 N 537230.43 E 3.227 11129.26 6023490.37 N 537171.79 E 2.797 11178.68 6023481.85 N 537114.84 E 2.994 11225.76 6023475.79 N 537062.06 E 3.647 11268.12 6023470.61 N 537014.44 E 2.202 11306.15 6023464.71 N 536968.15 E 0.762 11343.71 6023458.48 N 536922.00 E 1.196 11381.39 6023452.31N 536876.65 E 0.279 11418.46 6023446.49 N 536831.99 E 0.627 11454.78 6023440.90 N 536788.62 E 0.831 11490.01 6023435.17 N 536745.76 E 0.408 11524.97 6023429.50 N 536704.00 E 0.810 11559.10 6023422.89 N 536656.24 E 0.000 11598.20 Comment Projected Survey Alaska State Plane Zone 4 Milne Point L Pad Continued... 2 April, 1998 - 18:43 - 2 - DrillQuest Milne Point Unit Sperry-Sun Drilling Services Survey Report for MPL-371~ Your Ref: 500292286400 Alaska State Plane Zone 4 Milne Point L Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth o~ 226.680° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15426.00ft., The Bottom Hole Displacement is 11598.20ft., in the Direction of 226.680° (True). 2 April, 1998 - 18:43 - 3 - DrillQuest STATE OF ALASKA -.. ALASKA 0IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3240' NSL, 4835' WEL, SEC. 8, T13N, R10E, UM At top of productive interval N/A At effective depth 643' SNL, 2326' WEL, SEC. 18, T13N, RIOE, UM At total depth 4717' SNL, 2780' WEL, SEC. 13, T13N, R9E, UM J5. Type of well: [] Development [] Exploratory [] Stratigraphic [~]Service 6. Datum Elevation (DF or KB) KBE = 48' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-37A 9. Permit Number 98-56 / 398-078 10. APl Number 50-029-22864-01 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 15425 feet true vertical 7062 feet Effective depth: measured 7045 feet true vertical 3891 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) EZSV cement retainer at 8162' VTL Packer at 7045' Cemented MD TVD 80' 20" 250 sx Arcticset ! (Approx.) 112' 112' 8181' 9-5/8" 2031 sx PF 'E', 625 sx Class 'G' 8212' 4189' Perforation depth: measured 7140'-7160', 7612'-7627' true vertical 3919'-3924', 4041'-4045' ORIGINAL RECEIVED Tubing (size, grade, and measured depth) None ,JUL 08 1998 Packers and SSSV (type and measured depth) Gravel pack VTL top packer at 7045'; Gravel pac~Jtl~j~cC~lB~.t01~$~fllissi0fl Anchorage 13. Attachments [~ Description summary of proposal I--I Detailed operations program [] BOP sketch 4. Estimated date for commencing operation July 2, 1998 16. If proposal was verbally approved Blair Wondzell V/ Name of approver Contact Engineer Name/Number: Omar Nur, 564-5627 7/2/98 Date approved 15. Status of well classifications as: [] Oil I--] Gas L-] Suspended Service Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify tlTa~ th_C)oregoing is, Ar~and correct to the best of my knowledge Signed ChuckM~~'~ Title Senior Drilling Engineer Date~-7-"C~ ('/" ] Commission Use Only iConditions~O~l~'l~roval: Notify Commission's'b~representative may witness I Approval No. J ,r~,4~ .,.~ . Plug integrity BOP Test Location clearance J ~9¥~e\9'X~/ Mechanical Integrity Test Subsequen. t form required 10- I R,\L~ gfiginal s,gn~a ~ [App e,~~d by o}der of the Commission David W. Johnston Commissioner Date Form 10-403 Rev. 06/15/88 Submit~n Alas hare. d ri Il ing DATE: TO: ATTN: REFERENCE: SUBJECT: July 7, 1998 Alaska Oil & Gas Conservation Commission Blair Wondzell MPL-37A, Permit #98-56 Operation Shutdown As per verbal approval by Blair Wondzell to Omar Nur on July 2, 1998, BPX(A) has temporarily suspended completion operations on well MPL-37A. Difficulties were encountered in this well when a shifting tool was left in the hole. This fish lodged in a frac-pack packer and could not be retrieved. The well currently stands suspended with a packer plug set in the packer above perforated intervals in the Schrader Bluff "OA" and "N" sands, freeze protection down to 2100' TVD, and a X-mas tree with back pressure valve installed. Current plans are to fabricate specialized fishing tools and move back on the well to retrieve the fish. Once this is accomplished an ESP completion string will be run and the well placed on production. If you require further information, please contact me at 564-5061. Cordially, Chuck Mall~ Senior Drilling Engineer Shared Services Drilling RECEIVED dUE 08 1998 Ne;Ica Oil & Gas Cons. Commission Anchorage MPL-37A Suuspension Status as of 7/7/98 Packer plug ~ VTL Packer 'N' sand perorations 'OA' sand perorations 9-5/8" float shoe Shifting tool (fish) X-profile Sump packer 9-5/8" Cemen retainer ECEiVED JUL 08 1998 ~ 011 & Gas Cons. Commission ~Abandonrnent Anchorage plugs STATE OF ALASKA '-~-' ALASKA- OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: J~Abandon [--J Suspend [] Plugging r-JTirne Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to SB Producer ;2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 3240' NSL, 4835' WEL, SEC, 8, T13N, R10E, UM At top of productive interval N/A At effective depth 4719' SNL, 2852' WEL, SEC. 13, T13N, R9E, UM At total depth 4719' SNL, 2852' WEL, SEC. 13, T13N, RgE, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) Plan KBE = 47.1' 11, 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-37A 9. Permit Number 98-56 10. APl Number 50-029-22864-01 Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 15425 feet true vertical 7032 feet Effective depth: measured 15425 feet true vertical 7032 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 20" 8181' 9-5/8" Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A Plugs (measured) Junk (measured) Cemented MD 'I'VD 250 sx Arcticset I (Approx.) 112' 112' 2031 sx PF 'E', 625 sx Class 'G' 8212' 4189' RECEIVED MAR 24 lgg8 AJaska 0il & Gas 0ons. Commission Anchorage 3. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation March 23, 1998 16. If proposal was verbally approved Bob Crandall & Chuck Sheve Name of approver contact Engfneer Name/Number: Chfp Alvord, 564-4089 3/20/98 Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Kathy Carnpoarnor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip/Uvord ~~~ Title Engineering Supe.rvisor / Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity f BOP Test ~ Location clearance~ Mechanical Integrity Test__ Subsequent form required l O-JJO ~' di'igiflS, l bigrl~u o~, Approved by order of the Commission David W. Johnston Commissioner Approved Cop)- _Returned Form 10-403 Rev. 06/15/88 I Approval NO,._~ ? Sub'it In ']~Jplia~te Shared Services Drilling APPLICATION FOR SUNDRY SUMMARY OF PROCEDURE WELL # MPL-37A Milne Point well MPL-37A was drilled by Nabors Rig #22E to a depth of 15425'MD. LWD logs revealed the Kuparuk Sands were non-commercial. Therefore, the Kuparuk Sands are to be abandoned by placing a cement plug from TD to 750 feet above the top hydrocarbon bearing sand at 15074'MD. This will place the calculated Top of Cement at 14316'MD. A hole washout of 30% will be utilized in determining volume. A 9-518", 40# EZSV will than be placed 50' above the 9-5/8" casing shoe. Squeeze 15 bbi cement below EZSV and lay 50' cement plug on top of EZSV. The 9-5/8" cased wellbore will than be used as Schrader Bluff production well. 9-5/8", 40#, L-80, BTC casing was set at 8212' MD during drilling of MPL-37A. le PU 5" muleshoe. RIH to TD at MD. Circulate and condition wellbore. Spot a 65 BBL balanced cement plug. Slowly pull 20 stands above the calculated top of the cement plug. CBU. POOH. NOTE: Calculated Top of Cement is 14316'MD. Which is 750 feet above the highest hydrocarbon bearing sand at 15074'MD. NOTE: Volume based on 8-1/2" hole from TD to 750 feet above Kuparuk "C" Sand. Premium G + .2 % CFR-3 + HR-5 retarder as required. WT: 15.8 PPG YIELD: 1.15 FT3/SK . PU 9-5/8", 409 EZSV, RIH and set same at 8162' MD. Pump 15 bbl cement down through the EZSV. Unsting and leave 50' cement on top of EZSV. Calculated TOC inside casing will be 8112' MD. Deepest possible perf will be 7800' MD. POOH to 8000' MD CBU. 3. Displace well with seawater. POOH LDDP. Stop at base of permafrost and freeze protect well with diesel. Finish POOH LDDP. Test casing to 3500 psig. 5. ND BOPE, NU and test tree. RDMO Nabors 22E drilling to drill next well. RECEIVED MAR 24 1998 Alaska Oil & Ga~ Con~. Commission Anchorage harod ervices rilling March 24, 1998 ADDITIONAL SUMMARY OF PROCEDURES WELL# M P L-37A MPL-37A was drilled by Nabors 22E to a secondary target of 15425' MD in order to test the Kuparuk sands. The Kuparuk sands were wet and the decision was made to abandon the Kuparuk target and plug back the wellbore to the 9-5/8' surface casing in order to convert the well's utility to a Schrader Bluff producer. A cement plug was set from the TD of 15425'MD to approximately 750'MD above the top of the Kuparuk sands at 15074' leaving a calculated cement top of 14316'MD. After pulling out of the hole and circulating above the cement top the well attempted to flow. The drilling fluid was weighted from 10.2ppg to 11.0ppg in order to contain the flow. The drillstring was then run back in the hole to tag the top of cement which was found at 14640'MD, having dropped 324' from the calculated top of 14316'MD. A second 500'MD cement plug (Premium 'G' cement = 175sx, 35 bbl, 15.Sppg) was set on top (estimated TOC is 13,877'MD) of the initial plug to ensure proper isolation of the Kuparuk sands. · As per phone conversation Chip Aivord had with Blair Wondzell on evening of 03/23/98. · Additional attachment, as per conversation Kathy Campoamor had with Blair Wondzell on morning of 03/24/98. RECEIVED ~ch0mge TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE' (907) 279-1433 FAX: ,;907) 276-7542 March 19. t998 Paul Prince Drilling Superintendent BP Exploration (Alaska.), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit *IPL-37A BP Exploration (Alaska), Inc. Permit No. 98-56 Sur. Loc. 3240'NSL. 4835'WEL. SEC. 08. Ti3N. RiOE. UM Btmnhole Loc. 555'NSL. 2802' WEL. SEC 13. T13N. R09E. UM Dear Mr. Prince: Enclosed is the approved application for permit to rcddll the above rcfcrcnccd well. The permit to redrill docs not excmpt you from obtain ing additional permits rcquired bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25. 035. Sufficient notice (approximately 24 hours) must be gi-::cn to allow a representative of the Commission to witness a tcst of BOPE installcd prior to drilling new hole. Notice max' be given leum field inspccl'or on thc North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game. Habitat Section ~v/o cncl. Department of Environmental Conscrvation xv/o encl. STATE OF ALASKA ...... ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20/~C 25.OO5 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil []Re-Entry [-IDeepenI •Service •Developmen. tGas E] single Zone r'-lMultipleZone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 47.1' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025514 4. Location of well at surface 7. Unit or Property Name I11. Type Bond (See 20 AAC 25.025) 3240' NSL, 4835' WEL, SEC. 8, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 593' NSL, 2598' WEL, SEC. 13, T13N, R9E, UM MPL-37A At total depth 9. ApProximate spud date Amount $200,000.00 555' NSL, 2802' WEL, SEC. 13, T13N, R9E, UM 03/17/98 12. Distance to nearest property lineJ 13. Distance to nearest well 14. Number of acres in property 15. Proposed dePth (MD'~nd TVD) ADL 025515, 2802' ..J. No Close Approach 2560 15367' MD / 7007' TVD 16. To be completed for deviated wells 1'7. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 11000' MD Maximum HoleAngle 78-62° Maximum surface 2675 psig, Attotaldep.th0WD) 6700'/3345 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity .o..f Cement "Hole Casing Weight Grade Coupling Length M~ -I-VD MD TVD (include stage data) 8-:1/2" 7" 26# L-80 BTC-Mod 15337' 30' 30' 15367 7007 227 sx Class 'G' .... ,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 16575 feet Plugs (measured) true vertical 7124 feet Effective depth: measured 16575 feet Junk (measured) true vertical 7124 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 8181' 9-5/8" 2031 sx PF 'E', 625 sx Class 'G' 8212' 4189' Intermediate Production Liner R£C£1VED Perforation depth: measured MAR 7 8 true vertical ~ 01/& Gas Cons. 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch /'l/iCh0~:~ivertei-Sk;;tch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ,, Contact Engineer Name/Number: Chip,~ord, 564-4~ Prepared By Name/Numbec Kathy Carnpoamor, 564-5122 21.1 hereby certify that the f(~r/Cgoj~nc~t~/'and//Il correct to the best of my knowledge Signed ~~. ~,, |[ f~ Chip AIvord ,~1~ 4-- Title Engineering Supervisor Date / Commission Use Only , Permit Numberi AP, Numbe I A lri a' ¢ See cover letter ~ ~' .~,~z"'~ 50- (~ ~_. ¢ -- ~ ~-- ~"~' zTz -dl / for other requirements Conditions of Approval: Samples Required [] Yes J~ No Mud Log Requii'ed [] Yes ]~] No Hydrogen Sulfide Measures []Yes ~ No Directional Survey Required 'J~Yes [] No Required...~_~kingPress~reforBOPE J--12M; J--J3M; J~'J5M; J--Jl0M; J--J15M Other: J '~'~"r ~...~ ~ ?'.,-~'~ ,.;;"iO'"t'rTs. J 'b--~.~rle"-~"B~'"" by order of ' Approved By ;~:,.~-,Vid W. d0hrlst011C°mmissi°ner the commission Date ............. ~hml In Tr!nlir'~t~ Shared Services Drilling Contact: I Well Name: James E. Robertson J MPL-37A Well Plan Summary IType of Well (producer or injector): IKUPARUK PRODUCER 564-5159 Surface Location: 3240 FSL, 4835 FEL, S08 T13N R10E UM Target Location: 593 FSL, 2598 FEL, S13 T13N R09E UM Bottom Hole Location: 555 FSL, 2802 FEL, S13 T13N R09E UM J AFE Number: J337115 J Estimated Start Date: I 17 Mar 98 I J Rig: J Nabors22E Operating days to complete: IUD: 115367' J I TVD: J 7007' I I Well Design: J Kupurak Producer Formation Markers: J6.0 J KBE: J47.1 ft Formation Tops MD TVDSS Top Seabee 8059 4090 Top of HRZ 14228 6000 Base of HRZ 14436 6130 Top KLB 14521 6230 Top of Kuparuk 'C' 14847 6510 Top of Kuparuk 'B' 14847 6510 Top of Kuparuk 'A' 14946 6595 Top of Kuparuk 'A3' 14951 6600 Target Top of Miluveach 15067 6700 Base of Kuparuk TD 15367 7007 TD at 300' MD past base of Kuparuk Casing/Tubing Program: Hole ~;ize Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 8-1/2" 7" 26# LB0 BTC-MOD 15337' 30'/30' 15367' / 7007' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at +6700' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 3345 psi (9.6 ppg EMW), is 2675 psi, well below the internal yield pressure rating of the 7" casing. Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 10.2 50 20 10 20 9.5 4-6 Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. Also well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 111000'MD IMaximum Hole Angle: Close Approach Well: 78.62° NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on L-Pad have been permitted for annular injection. . . o , MP L-37A Proposed Summary of Operations POOH after TD Milne Pt. Well# MP. PU 5" muleshoe. RIH on 5" drillpipe to TD at 16,575' md (ESTIMATED TOP KUPARUK SANDS ].,,,6.;,! .2,_.2' ,.M,?):..~i,[c~.!,,.a,,!,? a~_~i~t,!,,.on hole for cement plug. Spot 70 bbl balanced cement plug. sL~'E~i!i~:i~i!'!!~i~'!~f....iii~:.~ii~,[~. At 15 stands above the plug rig up and circulate slowly down the drillpipe 1 drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. NOTE: Volume based on 8-1/2" hole from TD at 16,575' md to 300' above KUPARUK SAND at 16,122' md + 30%. EST TOC after plug set is 15,822' md. PREMIUM G + 0.20% HALAD 344 + 0.20% CFR3 + HR5 AS NECESSARY WT: 15.8 PPG YIELD: 1.15 FT3/SK Continue P(30,~ to XXXX' md. Spot 45 bbl high visc mud pill~weight of pill at current mud weight). Baro,~~cipe for high visc pill. Continue POOH to'~xxx' md. Spot 30 bbl balanced cement plu . At 15 stands ab-"~ve the plug rig up and circulate slowly down th'~rillpipe I drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. POOH LD rhuleshoe. Volume based on 500' of 8-1/2" open hole +30% excess. PREMIUM G + .8% CFR3 + 0.25% LAP1 + Retarder as needed WT: 17 PPG YIELD: 0.99 FT3/SK Test BOPE. MU bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH to 10000' md. Begin wash and ream until tag cement. Drill cement to KOP @ 11000' md. NOTE: ~~!;1~ . ~ ~. Indicate on morning report "TAG WEIGHT". 6. Circulate and condition mud at 11000' md before begin sidetrack. Drill 8.5" hole to TD as per directional plan. Run and Cement 7" Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) POST DRILL AND CASE: 1. Complete well with 2-7/8" tubing and an ESP. 2. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: See the latest Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on L pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Close Approach: There are no close approach problems with MP L-37A. 2. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface hole and production hole. Total returns have been lost while cementing the 7" Iongstring. If losses occur while cementing maintain rate and pump job as per plan. Several wells drilled on Milne Point 'L' Pad have experienced the breathing phenomena. Ordinarily if this is going to occur it occurs between just above the HRZ and the top of the Kuparuk 'D'. In the past the breathing phenomena has been "managed" by initially treating in flow as a well control incident. The well has been circulated through the choke and if no hydrocarbon is detected the assumption is that the well is breathing. The breathing has been managed by closely tracking fluid volumes and allowing mud to flow back in a controlled manner without having to weight up. Do not be surprised if the well flows back for several hours after bumping the plug on the 7" job. Have the LCM materials on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. 3. Stuck Pipe Potential: Review the Milne Point 'L' Pad pad data sheet. There were a couple of stuck pipe incidents on L pad several years ago. The transition between the HRZ/MK-19 and the Kuparuk 'D' has been the primary area of stuck pipe incidents in the past. Keep up with the Torque and Drag schedules and monitor them especially through this area. If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 4. Formation Pressure: THE KUPARUK IS EXPECTED TO BE NORMALLY PRESSURED. The expected pore pressure for this well is 9.6 ppg EMW (3345 psi @ 6700' TVDSS) in the KUPARUK sands. 5. Cement The 8-1/2" hole will be cemented in a single stage to bring cement 1000' md above the top of the Kuparuk 'C' Sands. MP L-37 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. SPACER: 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 227 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 20 joints of 7" casing (40). This will cover +300' above the KUPARUK 'C' Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: . Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. weLL ......... Field ........ : Milne Potn~ Compu~a~cn.,: Mini~ Curvature An~drlll Schlumbarser Alaska District kill £aeC 80th Avenue As~Chorage, AK 995L8 (907) 349-45L1 Fax DI~LECTIONAL WELL PLAN for SHAPED SERVICES Surface Let,.: 70.49673595 N Sur face 149.63164525 W Legal ~scripCion Surface ...... : 3240 FSL 4835 FEi S~8 T13N R1OE ~ STATION I DEhrT! FI CATION LOCATIONS - ALAS~ Zone: 4 X-Coord ¥-Coord 5~5045,94 60~1~31.09 53996~.2~ 602~469.6~ $3~B70.00 6023460.~0 5~6665.97 6023421.06 SURVEY CU~V~ 3/100 PROPOSED WELL PRDFILE · ~=A~93RED IHCLF/ DIi~'~I~ION V~I~-OEP~S SECTZO~ DEPTH A/qGLE ~I~H ~ ~-S~ DEPOT 10999.~4 75,33 219.73 ~7~4.46 46~7.36 6~00.~6 11~OO.~0 75.3~ 219.72 4744.67 4~97.~7 6300.90 11100,00 74.48 2~.7~ %770.72 4723.6~ 6376.62 LL~00,GO 73.68 225,7~ 4798.16 475~.86 6455.86 113~.00 72.91 228.74 4826.91 4779.B1 6535.99 Prepared ..... : L3 Mar 1998 Vert aec= az.: 259.54 KB elevatios.: 47.10 ft Magnetic Dcln: .27,772 {E} Sca~e Factor,: 0.9999023~ Convergemce..: +0.~722000 ANADRILL AKA~DPC APPROVED FOR PERMITTING ONLY PLAN m~m~mme~m~=~m · ', C~6~D=/~%%-~S~P~ ALaSkA Zone 4 ~oo~ ~L/ ~L~H~ x Y ~c~ ioo 6931.14 S 5L29.25 W 539961.2B 6024469,69 ~ <TIE 6~31,78 S ~5127.78 W 5~9960.75 6024469,04 LOTR 0,64 7004.40 S 5191.39 W 539897,60 6024396.05 106R 3.00 7073.33 S 5258.42 W 539B30.99 6024326.72 lOSR 3.GO 7138.37 S 532B,7[ W 539761.10 6~2426i.~G 504R 3.00 11400.00 72.~9 231.79 485G.9O 4809.80 6619.19 7199.35 S 5402,O6 W 53968B.13 602%199.~5 103R 3.00 11500.00 7L.52 234.87 48BB.04 4840.9{ 6704,43 7256.09 ~ 5qTB,27 W 539612.27 6024142.65 102R 3.00 11600.00 70.~0 237.97 %920,26 4B73.~6 6991.48 7308.45 S 5659.13 N 539533.74 6024089,8[ IOIR 3.00 iL700.00 70,33 241.09 4953.45 4906.35 6880,11 7356.2B S 5638.42 W 539452.75 60~40~[.50 S00R 3.00 11800.00 69.82 244.2~ 4987.54 4940.~4 6970.06 7399.45 S 572[.92 ~ 539369.52 6023997.83 99R 3.00 119OO.D0 69,36 247.40 5022.¢2 4975.32 7061,O9 7437,64 S 5807.40 W 539284.28 6023958,93 9BR 3.00 ,- '' ............. ,, · '- .' ,' , -' .' .";9 r ,: MPL-3?A (Pg) 13 Mar 199E P~9~ 2 PRD?OSED WJ~r,L PROFILE STATION bL~AS~ iDEntIFICATION DEPTH 12000.00 68.96 [2100.00 6g.6~ 12200.00 68,34 ~;D ~/i00 CILRVE i2279.~4 68.16 CURVE 3710D 13379.~2 68.16 13%00.O0 67.54 [3500,00 64,64 %3600.00 61.54 13700.00 58.54 13800.00 ~5.54 13900.00 52.54 1%OO0.00 49.54 14100.00 R6.54 14200.D0 43,54 14300.00 40.54 E~ 3/100 TAEGET (L-989] 14400, OD 37.54 ~4500,00 34 .~4 ~4600,00 31,54 1465~. 30 30. O0 1495~.30 30.(]0 EST II. TED '[~4bV TD / '~" c~ZS[NO FT DIRECT/ON VERTICAL-DEPT~S AZI>~UTH TVD SUB-SEA 250,58 5058.00 5010.90 253.78 5094.19 5047.09 256.99 5130.88 5083.~8 2~9.54 516~.24 5113.1~ 259.54 5569.%1 55~.~ 6ECTION DEPART Q152.95 7245.39 7~37.16 7411,94 8432.78 2S9.54 5575.25 5630,L5 8652.03 259.5~ 5617.85 5570.75 85~3.40 259.5~ 5663.L9 5656.09 8632.52 259.54 5713.12 5666.02 ~719,%5 259.54 5767.5~ 5720.42 8803,04 ,. 259.&4 5826.24 $779.L4 B8B3.97 259.54 5~89.11 S842.Q~ 896~,72 259.64 5955.97 59OB.B? 9036.07 259,54 6026.62 ~979.52 ~106,82 259.54 6~00,$8 6053.78 B~73.70 COORDIIIA?£S -FROM 7~71.35 S 5894.63 7499.88 S 5983.37 7523.35 8 60~3.37 7538.32 S 6145.43 7723.67 S 7~49.~1 ALASKA Zone 4 X mmm~mfA.m mmm.~mmmmm 539~97.26 6023924.90 539~00.~1 6023895.83 539018.86 602387~.92 538946,90 6023856,41 537944,06 60~366~.00 mmm~ TO0~ ~/ ~00 99R 3.00 96R 3.00 95R 3.00 HS 3.00 L,S O.OO 7727.16 S 7168.43 W 537925.16 6023661.40 L~S ~.00 7743.75 S 7258.29 W 537~35.42 6023644.27 LS 3.(]0 7959.92 S ?345,93 ~ $37747.88 6023627.56 LS 3.00 7775.6~ S 7451,12 W ~37662,80 6025611.32 7790.88 6 751~.62 9805.57 $ 7593.20 78 ].9.~8 S 7669.66 7833.18 S 774~.97 7846.02 S 7612.35 259.54 6178.55 6131,45 9236.76 7869.61 259.54 6259.40 6212,30 9295.58 7880.2] 259.5~ 6343.22 6296.12 9350.10 7890.[8 259.54 6387,29 6340.19 9576.34 9894,95 259.54 6647.10 ~'6o.oo 9526.~¢ V922,~S 537600 91 6023580.42 53742~.~5 6025565.85 637~51 53 60~551.91 537216 27 6023526.D9 7940.13 W 537154 42 602351¢.29 ?997.98 W 5~7096.6~ 6023603.26 807L.59 ~ 5~7043 1(] 6023493.~4 8077.39 ~ 537017.t3 6023458.~2 8224.90 W 536870 OO 6023460.00 3,00 3.0D 3.00 3.00 3.00 15066.?7 30.00 259.54 6747.10 6700.00 9564.06 15366,77 30.00 259.54 700~.91 6959.81 9734.08 LB 3.00 LS 3,00 LS 3.00 MS NS 0.00 7932,66 S 9281,67 W 5368~3,29 6023449,18 KS O.O0 7959.89 S 8429.18 W 536665.97 6023421,06 0,00 ANADRILL AKA-DPC A.PPROVED FOR PERM. TT NG ONLY (Anadrill (c)98 MPL37207 3.2b.5 9:19 AM P) ,-' ...... :~:' ....... ........ '7 .....: ........... l .... ~ ................................................................................................ ...... SHARED S'EF:i~'"'iC'ES .... Dfl]~LZNG .... >,:.=z,r',<.3, r ~Oen~.Zftcation MD B. K8 SECT)~ INCLti Al liE-iN SURVEY 10999 47.44 6300 75.33 K0P / CuRv£ 3/t00 I~000 4245 63,01 75.33 £) ENO 3/100 CURVE ~P279 5:~60 7412 68.16 AKA-DPC D) CL~VE 3/tOO F] IARE,¢_ f O) 1'0 / 7' £ASI:NG 1495!66479526 30.00 ~ ...... ,5~, ~oo,~,~ 30.00 i ~g~ ~RM~TT~NG ~ ONLY ,4nadrJ l l S~hlu/~ber'ger' gPL-37A (PT) VERTICAL SECTION VIEW Section at' 259.54 'rYO 5c8]e,' ~ incl~ = 500 feet Oep Scale · ~, inch = 500 feet IOra~n · ~-3 Ilar ~998 .0C, Section Departure ' ~'""<C:~ ~U~O~-~.~ .~ ~ ~ ~ ~ ........ ". -- m ..... SH' kRED SERV"'[CES 'D 'T_LLZklG ......... .... - - - - ' .......... ._ .:.~: . · - i i i II I Il , II II I.. , , il - , Anadr~']/ Schlumberger gPL-37A VERTICAL SECTION VlElq : ' - --- --'' - ..... Section at' 259.54 iL~' ~Dep Scale,: ! inch 1200 feet ~ O~L~ . ~ ......... ~ ~ _.'~I, -~ . ~ Hacker Identification MD B~ SECTN INCLN A} TIE-IN 5~VEY ~0~9~ ~74~ 630~ 75.3~ B} K~ / C~VE 3/100 ~t000 ~7~5 6301 75.~ ) ..... C] E~ 3/100 CURVE 12279 5t60 74t~ .... D) CURVE 3/~00 13379 5569 8~33 E) END 3/~00 ~4651 83B~ 9378 F) TAROT [L-~B) ~4951 6647 ~26 ............. } ......... } 6} lO / 7' BASING PT ~5367 7~O~ 9734 30.0( o- % ...... ~ , ~0 .... ~ ..... ~ ...... -~ ~ ...... i' I ~ ,:, .'.,, 'L,2 ':'_.. '" L,:_, , - .... 3000- et( ~nt) · . Section Departure .I . _ _ ~ II ~ . I .il I I. __ I I II I I II , 10200 S£h~umberger RPL-37A PLAN VZEX __ SHARED SERVICES DRILLING '7-"" .... AKA-DPC ' ,~ ANADR1LL ~ I SURE ..... : 11594 teet at Az~rnuLh 226.64 , ,ooo .~ ~in~ .~oo ¢,~t ':OR · = 1, : i i i i i , -- ~E-I¢~ S~VEY 10999 693t S 5i~7 ~ 0P / 0URI'E 3/~00 ~J000 8932 S 5t28 ~ )~ 3/]00 CURVE ~2~79 7538 S 6i~5 ~ . . ............. . .... / . ~ ............. ~¢ · ...... , .... , ..,. ,. , / ,, ..... ~~ ........ , ........ ..... / .... ............ ......... ......... ...................... ~ ......... -- _ , ~ ..... ~ ..... ~ ....... ~ ::~ ........... "~' .......... L 7750 8250 75O _ .~'.:'.' ~g ~'-' ~::.'~ , , ~. ,'~.'J ,'&~ .'~'~ ~ '~-~'~ ~ ---'~'3~" <- WESI il l~l~,~A'~'i'~'/%"~g:~ ~ ~i .... ......... "'- - ' .... "-' ----- -- "" ...... ' '='-'" --'~' -= - DATE I CHECK NO. F! 13 4 3 7 9 o~/~/.~ I VENDOR ALASKAST 14 QO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 021798 C~021798]) 100. O0 100. O0 HANDLING INST: s/h' kathy campoamor x 5122 'HE AnACHEO CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. · WELL PERMIT CHECKLIST COMPANY _,/~,/~ WELL NAME ./~..,'g)Z -- ,?.~../~. FIELD & POOL __. ~".,~_.~'",,~'~ INIT CLASS ,~¢_./ ./',.. <:::3, "*/ GEOL AREA PROGRAM: exp [] dev~!~redrll~serv [] wellbore sec [-: ann. disposal para req ~,~/~ UNIT# ~/'/'~', '~.2._.~~' ON/OFF SHORE 4~ ADMINISTRATION ENGINEERING APPR DATE 1. Permit fee attached ...................... Y N 2. Lease number appropriate ................... Y N 3. Unique well name and number .................. Y N 4. Well located in a defined pool ......... ' ......... Y N 5. Well located proper distance from drilling unit boundary .... Y N 6. Well located proper distance from other wells .......... Y N 7. Sufficient acreage available in drilling unit ........ Y N 8. If deviated, is wellbore plat included ............ Y N 9. Operator only affected party ............... Y N 10. Operator has appropriate bond in force ............. Y N 11. Permit can be issued without conservation order ....... Y N 12. Permit can be issued without administrative approval ..... Y N 13. Can permit be approved before 15-day wait .......... Y N 14. Conductor string provided ................... (~ 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & sud csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... Y N 19. Casing designs adequate for C, T, B & permafrost ...... (~ N 20. Adequate tankage or reserve pit ................. (~N i;;;>l ~ 21. If a re-drill, has a 10-403 for abandonment been approved... Y N t, I~ ~,~ 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it rneet regulations ......... ~ ___~L~' 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate: test to '~"~""'~ psig. <~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ I~ N i~, -~' 28. Work will occur without operation shutdown ........... (...Y2 N 29. Is presence of H2S gas probable ................. Y (~) GEOLOGY DATE,,' 30. Permit can be issued w/o hydrogen sulfide measures ..... ., Y N./ ' 31 Data presented on potential overpressure zones . . .,,~,.,~/ Y.,,~ 32 Seismic analysis of shallow gas zones ........ .,,/.-.'~ f /,N N 33. Seabed condition survey (if off-shore) ............ .~' Y N 34. Contact name/phone for we.eklyprogress reports ..... ~'. Y N lexploratory only] REMARKS GEOLOGY: R P C,/,,~_____~ .... ENGINEERING: BEW /-- .2 JDH~ COMMISSION' Comments/Instructions: iJ(')VVIIF /,, ~,P(')RM~;\,'t~¢,l,h.:q r~,,,, (~,/"; Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically- organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Feb 22 01:53:27 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/02/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 500~8G~01 BP EXPLO~TION (~S~) , INC. SPERRY-S~ DRILLING SERVICES 22-FEB-99 MWD RUN 2 MWD RUN 3 MWD RUN 4 AK-MM-80148 A/<-MM-80148 A_K-MM-80148 PIEPER PIEPER PIEPER LOCKWOOD JAYE JAYE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 5 AK-MM-80148 FERGUSON WILSON 8 13N 10E FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3240 4835 .00 46.70 17.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 8210.0 8.500 15426.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN #1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2&3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECT~RS, AND ELECTROMAGNETIC WAVE RESISTIVITY PH_ASE-4 (EWR4) 4. MWD RUN #4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PI{ASE - 4 (EWR4) , COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER THE PHONE CONVERSATION BETWEEN D. DOUGLAS OF BP EXPLORATION (ALASKA), INC. AND A TURKER OF SPERRY- SUN DRILLING SERVICES ON 02/12/99. THIS DATA IS CONSIDERED PDC. 6. MWD RUNS 2-5 REPRESENT WELL MPL-37 A WITH API#: 50-029-22864-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15426'MD, 7063'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBDC = SMOOTHED BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 1000-1200 PPM CHLORIDES MUD WEIGHT: 8.3 - 10.2 PPG FORSIATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 g/cc MATRIX DENSITY: 2.65 g/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP FCNT NCNT NPHI PEF DRHO RHOB $ START DEPTH 3892.5 3892 5 3892 5 3892 5 3892 5 3900 5 3948 5 8200 0 8200 0 8200 0 8221 5 8221 5 8221 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MW~ MWD MWD MWD STOP DEPTH 15349.5 15349.5 15349.5 15349.5 ' 15349.5 15376.0 15425.5 15357.0 15357.0 15357.0 15365.5 15365.5 15365.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 3947.0 6660.0 3 3947.0 8250.0 4 8250.0 10653.0 5 10653.0 15426.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 3892.5 15425.5 9659 ROP 1.0291 4774.22 286.721 GR 13.583 259.951 80.8026 RPX 1.1036 33.347 3.77858 RPS 0.142 42.96 4.09411 RPM 0.115 2000 4.33331 RPD 0.3511 2000 8.42576 FET 0.063 74.233 1.33119 NPHI 20.4491 81.7622 47.504 NCNT 2152 3692.92 2654.89 FCNT 402 849.543 554.916 RHOB 1.149 3.1135 2.35459 DRHO -0.588 0.5392 0.0764262 PEF 0.709 6.2558 2.10824 First Last Nsam Reading Reading 23067 3892.5 15425.5 22955 3948.5 15425.5 22952 3900.5 15376 22915 3892.5 15349.5 22915 3892.5 15349.5 22915 3892.5 15349.5 22915 3892.5 15349.5 22915 3892.5 15349.5 14315 8200 15357 14315 8200 15357 14315 8200 15357 14289 8221.5 15365.5 14289 8221.5 15365.5 14289 8221.5 15365.5 First..Reading For Entire File .......... 3892.5 Last Reading For Entire File ........... 15425.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3892.5 6605.5 RPD 3892.5 6605.5 RPM 3892.5 6605.5 RPS 3892.5 6605.5 RPX 3892.5 6605.5 GR 3900.5 6613.0 ROP 3948.5 6660.5 $ LOG HEADER DATA DATE LOGGED: 04-FIAR-98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6660.0 TOP LOG INTERVAL (FT) : 3947.0 BOTTOM LOG INTERVAL (FT) : 6660.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 73.1 MAXIMUM ANGLE: 78.6 ... TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ DUAL GAMFuA R_AY ELECTROMAG. RESIS. 4 BOREHOLE A/CD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/qDOFF (IN) : EWR FREQUENCY (HZ) : REM/kRKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P0965CRG8 P0965CRG8 12.250 12.3 SPUD 9.00 47.0 9.0 1200 7.2 2.050 1.750 1.900 3.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 32.2 First Last Name DEPT ROP GR RPX RPS RPM RPD FET Min 3892.5 1 664 13 583 1 385 1 421 1 449 1 481 0 063 Max Mean Nsam 6660.5 5276.5 5537 2928.52 455.408 5425 113.704 54.3892 5426 14.597 4.35836 5427 16.406 4.69711 5427 16.361 4.77464 5427 17.721 5.06807 5427 11.178 0.606774 5427 Readin9 3892.5 3948.5 3900.5 3892.5 3892.5 3892.5 3892.5 3892.5 Readin9 6660.5 6660.5 6613 6605.5 6605.5 6605.5 6605.5 6605.5 First Readin9 For Entire File .......... 3892.5 Last Readin9 For Entire File ........... 6660.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA 3 .5000 START DEPTH 6607 5 6607 5 6607 5 6607 5 6607 5 6616 0 6662 5 STOP DEPTH 8194.5 8194.5 8194.5 8194.5 8194.5 8202.5 8250.0 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined F~Bme Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 06-M3kR- 98 5.07 5.46 MEMORY 8250.0 3947.0 8250.0 72.0 77.4 TOOL NUMBER P0965CRG8 P0965CRG8 12.250 12.3 SPUD 9.10 48.0 9.0 1200 5.8 2.000 1.890 1.900 .000 27.3 Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 3 FT/H 4 1 68 MWD 3 API 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 6607.5 8250 7428.75 3286 ROP 8.79 841.767 187.775 3176 GR 22.325 117.481 69.5602 3174 RPX 1.348 30.853 5.09097 3175 RPS 1.258 42.96 6.07041 3175 RPM 1.189 47.456 6.4166 3175 RPD 1.184 47.251 6.81636 3175 FET 0.11 15.325 1.11516 3175 First Reading 6607.5 6662.5 6616 6607.5 6607.5 6607.5 6607.5 6607.5 Last Reading 8250 8250 8202.5 8194.5 8194.5 8194.5 8194.5 8194.5 First Reading For Entire File .......... 6607.5 Last Reading For Entire File ........... 8250 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER ,_~ FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX FCNT NCNT NPHI GR PEF DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4 .5000 START DEPTH 8195 0 8195 0 8195 0 8195 0 8195 0 8200 0 8200 0 8200 0 8203 0 8221.5 8221.5 8221.5 8250.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE DGR EWR4 CNP SLD $ TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: STOP DEPTH 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 10653.0 (DEGF) 12 -MA~q- 98 5.07 5.46 MEMORY 10653.0 8250.0 10653.0 32.5 81.9 TOOL NUMBER P0962CRNLG6 P0962CRNLG6 P0962CRNLG6 P0962CRNLG6 8.500 8.5 LSND 10.20 45.0 9.5 1200 4.0 1.600 1.028 1.300 57.8 MUD CA/CE AT MT: 1.700 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 RPX MWD 4 OHMM 4 1 68 12 4 RPS MWD 4 OHMM 4 1 68 16 5 RPM MWD 4 OHMM 4 1 68 20 6 RPD MWD 4 OHMM 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 NPHI MWD 4 PU-S 4 1 68 32 9 NCNT MWD 4 CNTS 4 1 68 36 10 FCNT MWD 4 CNTS 4 1 68 40 11 RHOB MWD 4 G/CM 4 1 68 44 12 DRHO MWD 4 G/CM 4 1 68 48 13 PEF MWD 4 BARN 4 1 68 52 14 First Name Min Max Mean Nsam Reading DEPT 8195 10653 9424 4917 8195 ROP 12.66 4774.22 336.957 4806 8250.5 GR 36.229 126.835 84.4756 4901 8203 RPX 1.645 33.347 3.7546 4917 8195 RPS 0.142 31.371 3.97879 4917 8195 RPM 0.115 2000 4.58765 4917 8195 RPD 1.348 2000 22.9519 4917 8195 FET 0.147 74.233 2.25729 4917 8195 NPHI ... 21.626 76.782 47.8285 4907 8200 NCNT 2152 3424 2627.02 4907 8200 FCNT 402 819 537.563 4907 8200 RHOB 1.149 2.617 2.26645 4864 8221.5 Last Reading 10653 10653 10653 10653 10653 10653 10653 10653 10653 10653 10653 10653 DRHO -0.588 0.288 0.0480076 4864 PEF 0.709 4.567 1.88627 4864 8221.5 8221.5 10653 10653 First Reading For Entire File .......... 8195 Last Reading For Entire File ........... 10653 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: . 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE PEF DRHO RHOB FCNT NCNT NPHI FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: 5 .5000 START DEPTH 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653 5 10653 5 10653 5 10653 5 10653 5 10653 5 STOP DEPTH 15365.5 15365.5 15365.5 15357.0 15357.0 15357.0 15349.5 15349.5 15349.5 15349.5 15349.5 15376.0 15425.5 20-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/~GLE: MAXIMUM A/qGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 5.07 5.46 MEMORY 15426.0 10653.0 15426.0 26.7 76.3 TOOL N-UMBER P0962CP~NLG6 P0962CRNLG6 P0962CRNLG6 P0962CP~NLG6 8.500 8.5 LSND 10.20 50.0 9.5 1200 3.5 1. 950 .855 1.800 2.800 69.4 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 5 API 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 OHMM 4 1 68 FET MWD 5 HOUR 4 1 68 NPHI MWD 5 PU-S 4 1 68 NCNT MWD 5 CNTS 4 1 68 FCNT MWD 5 CNTS 4 1 68 RHOB MWD 5 G/CM 4 1 68 DRHO MWD 5 G/CM 4 1 68 PEF MWD 5 BARN 4 1 68 ROP MWD 5 FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min DEPT 10653.5 GR 28.777 RPX 1.1036 RPS 0.7403 RPM 0.5349 RPD 0.3511 FET 0.2386 NPHI 20.4491 NCNT 2152 FCNT 425 RHOB 1.7128 DRHO - 0.16 PEF 1.4948 ROP 1. 0291 Max 15425.5 259.951 13 6794 21 6384 15 3924 24 5954 33 3903 81 7622 3692.92 849.543 3.1135 0.5392 6.2558 655.078 Mean Nsam 13039.5 9545 97.8614 9446 3.01307 9393 3.13866 9393 3.24164 9393 3.3075 9393 1.33534 9393 47.3348 9408 2669.43 9408 563.967 9408 2.40008 9425 0.0910924 9425 2.22279 9425 198.472 9545 First Reading 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 10653.5 Last Reading 15425.5 15376 15349.5 15349.5 15349.5 15349.5 15349.5 15357 15357 15357 15365.5 15365.5 15365.5 15425.5 First Reading For Entire File .......... 10653.5 Last Reading For Entire File ........... 15425.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physi~al EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/02/22 Origin ................... STS Reel Name ............... ~UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
