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Home My WebLink About195-050 • From: Patricia Bettis To: Well History File: PTD 195-050 Date: January 13, 2017 Re: Well Name Change At the request of Hilcorp, the well name for MGS A43-11LW was changed to MGS A43-11RD, effective January 13, 2017. SCANNED JAN 2 2017 Pages NOT Scanned in this Well History File XHVZE 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. i~' '~' '- (~O File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by;. Bevedy Dian~i~cent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ , f..{�r',k ..F. ,3j eta', .in..' •r 4,. :>rt Y. - �^.s-s s ,,^asp ac�•.c ..,..:...�� .. • .. ,; u OF T�� _ ,,,V \I//7y._,-t. THE STATE lla� a (.,.vi'.1 a �u. -;, y /. \v / / A ? 333 West Seventh Avenue !,. —" �s0V'1;K\C:R SE��' j',\j; Ar�-ii Anchorage Alaska 9950 3572 n ain 9C7 27'9 .433 �� /iii '{"�' ,(Ix Y(,/.,'/6, 7', SCAN MAY 0 7 Z 4 Sandra Haggard Regulatory Analyst c..) F (/ �— -� © XTO Energy 9127 South Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, & G Pools, MGS A43-11LW Sundry Number: 314-254 Dear Ms. Haggard: 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, 1 7)---20..e„oci—t--1/4_.-- Cathy '. Foerster Chair DATED this day of April, 2014. Encl. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . ' Z Z./ /. APPLICATION FOR SUNDRY APPROVALS 401 � � . C. 20 AAC 25.280 . w.r 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑., • Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Exte?sion 0 Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate❑ Atter Casing❑ Other ICT cleanout 8acidize i .SOZ- ❑ 2.Operator Name: 4.Current Wel Class: / 5.Permit to Drill Number. XTO Energy Exploratory O Development [J \- 195-050 • DC-H/g•/y 3.Address: Stratigraphic ❑ Service L 1 6.API Number: 9127 South Jamaica Street,Englewood,CO 80112 \ 50-733-10082-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 / Middle Ground Shoal A43-11LW - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL x-87-58- /8.$Y PM MGS E,F,G Oil pots 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ' /0/0g 40U c '01 -9,790— .10,098 . 9,799 Casing Length Size MD TVD Burst Collapse Structural Conductor 400 24" 400 400 Surface 1,609' 13-3/8" 1,609 1,609 3,090 psi 1,540 psi Intermediate 8,798' 7" 8,798' 8,620' 8,160 psi 7,020 psi Drilling Liner 2,339' 5" 8,731' 8,580' 13,940 psi 13,450 psi Liner 1,450' 3-1/2" 10,098' 9,799' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,731'-10,098'. Slotted Liners 2-7/8"&2-3/8" 6.5#N80 and 2-3/8" L80/N80 8,448' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker'FH'packer,Baker"FV-6"TR SCSSV packer @ 8,305'MD,8,200'TVD SSSV @ 325'MD,325'TVD 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program r❑ BOP Sketch 0 •Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for May 2014 15.Well Status after proposed work: Commencing Operations: Oil ❑� • Gas 1 1 Qt� WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sandra Haggard Email Sandra HaggardtG7.xtoenergv.com Printed Name Sandra Haggard Title/ /,/ l/d it/!f cS! Signature e c"� / � Phone 303-397-3672 Da April 10 014 7S�V/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: � . kl—l— 2.54 Plug Integrity ❑ BOP c.f Test Lid Mechanical Integrity Test ❑ Location Clearance ❑ Other: y J 0 O P5 3oP OVIB t 7 201= Spacing Exception Required? Yes ❑ No 1E( Subsequent Form Required: /o- cif 0 APPROVED BY Approved by:a/67 /9 ...,_.„,z,____ COMMISSIONER THE COMMISSION Date: 4.- —u -/,Z 1.18•P-I -i'1W' Li/all i 1 ❑ 1-INA l Submitsn Form and Form 10-403(Revised 10/2012) Appro e i t v I c;T•�`2 onths�t e pate of approval. Attachments in Duplicate )(TO , ENERGY AOGCC April 10,2014 Alaska Oil and Gas Conservation Commission Attn: Cathy P. Foerster,Chair 333 W. 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Form 10-403,Request for Sundry approval Objective: Coil Tubing Cleanout and Acidize to Remove Scale Middle Ground Shoal#A43-11LW MGS Field Cook Inlet,Alaska API: 50-733-10082-01-00 PTD#: 195-050 XTO Energy Inc.hereby submits its Application for Sundry Approval for coil tubing cleanout and acidizing to remove scale deposits in the well. Attached is the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Proposed job procedure 3. Present wellbore schematics and deviation survey If you require additional information,please contact me at 303-397-3672 Sincerely, P."?(/‘e-- -//i Sandra Haggard,Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer To ENERGY To: Cathy P. Foester Guy Schwartz Victoria Ferguson CC: John Baker Matthew Deveau Scott Griffith From: Ajibola Adeyeye Re: MGS A43-11LW(PTD: 195-050) Cook Inlet,Platform A Coil Tubing Cleanout and Acidize to Remove Scale OBJECTIVE: The objective of this workover on MGS A43-11LW producer well is to cleanout and acidize scale deposit in the tubing, liner and across the production interval. The workover plan includes mechanical cleanout for scale via coil tubing jet nozzle and mill. Acid will be spotted as necessary to dissolve some of the tougher scale in the well.Additional acid squeezed into the 0° 4c� producing zone to remove scale near the wellbore.Afterwards, scale inhibitor squeeze will be conducted to further minimize the growth rate of scale. WELL HISTORY This well has a history of scale deposit in the tubing and production liner.Periodic attempts were made in the past to remove some of the deposits via slickline,however,this has lower effectiveness as scale/solids removed end up falling and depositing in the casing. Coil tubing cleanout was conducted on this well in the past,the most recent in 2007.This involved mechanically washing of the wellbore and chemical removal of scale with 10% hydrochloric and xylene mixture.Prior cleanouts have resulted in improved uplift,however,there have been mild success in maintaining steady production.This is mostly due to the eventual re-growth of the scale in the well;good improvement was noticed from prior scale inhibitor squeeze in extending well production. In summary,this cleanout and scale inhibitor squeeze job is part of the necessary well maintenance work to enable steady well production. The anticipated start date for this workover is May 2014.Please contact me at 720-539-1660 with any questions or concerns. Sincerely, Bola Adeyeye Operations Engineer PLF 4-18-11 )(TO Current Completion KB:MGS A43-11 LW Water Depth: 73' Cook Inlet, Alaska Leg 1,Conductor 3 API No.: 50-733-10082 Tbg: Spud: 2-7/8"6.5#N80 8rd EUE @ 6318' Sidetrack: J 2-3/8"4.7#L80/N803 3rd EUE @6 24"Conductor Csg @ 400' Baker"FV-6"TRSCSSV w/2.313""X"@ 325' / Surf Csg: 13 3/8", 54.5 Ib,J55. GLM MD TVD Port Ptro Psc Pso Set @ 1609'. Cmt'd w/1925 sx. 1 1921' 1900' 12 925 892 950 J 2 3356' 3356' 12 910 871 919 3 4508' 4507' 12 895 850 887 4 5406' 5404' 16 950 827 881 5 6116' 6113' 16 935 807 845 6 6624' 6619' 16 920 788 826 Production Csg: 7",29 lb., N80. 7 7136' 7116' 16 905 767 805 Window @ 6772'for sidetrack. 8 7681' 7608' 20 985 735 798 (Original Set @ 8798'.) J 9 8226' 8110' 1/4"Orifice Cmt'd w/1500 SX. X-over from 2 7/8"to 2 3/8"tbg @ 6318'(5-2 7/8"D-SO,4-2 3/8"U-SO GLMs) 1 Jt.2 3/8"tbg Otis"X"Nipple @ 8272'(1.875"ID) 1 Jt.2 3/8"tbg Baker"FH"packer @ 8305'w/30K#shear 1 Jt 2 3/8"tbg Otis"XN"Profile Nipple @ 8350'(1.791"ID) / 1 Jt 2 3/8"tbg Baker Wireline re-entry guide @ 8448' Drilling Liner: 5", 18 lb., P110 FL4S. ,/Set @ 8731'. TOL @ 6392'. �,- J • / J Prod Liner: 3.5", 9.3 Ib, N80 BTC slotted liner set @ 10098'.TOL @ 8650'. TD: 10,098' MD f+0 ENERGY MGS A43-11LW Workover Package for Coil Tubing Cleanout and Acidizing Operations Engineer: Bola Adeyeye Office: (303)3973606 Cell: (720)5391660 Well Identifier Well Name: MGS A43-11LW Permit to Drill Number: 195-050 API #: 50-733-10082-01-00 AFE Number: Objective Perform coil tubing cleanout to remove scale and other debris in the well. Acidize the producing zone and perform scale inhibitor squeeze. The workover plan includes mechanical cleanout for scale via coil tubing jet nozzle and mill.Acid will be spotted as necessary to dissolve some of the tougher scale in the well. Mutual solvent pre-flush and 10% HCI will squeezed into the producing zones to remove scale near the wellbore; N2 foam will be used for diversion. Afterwards, scale inhibitor squeeze will be conducted to further minimize the growth rate of scale. Background This well has a history of scale deposit in the tubing and production liner. Periodic attempts were made in the past to remove some of the deposits via slickline, however,this has lower effectiveness as scale/solids removed end up falling and depositing in the casing. Coil tubing cleanouts were conducted on this well in the past, the most recent in 2007.This involved mechanically washing of the wellbore and chemical removal of scale with 10%hydrochloric and xylene mixture. Prior cleanouts have resulted in improved uplift, however, there have been mild success in maintaining steady production.This is mostly due to the eventual re-growth of the scale in the well, good improvement was noticed from prior scale inhibitor squeeze in extending well production. In summary,this cleanout and scale inhibitor squeeze job is part of the necessary well maintenance effort to enable steady production from the well. Workover History Workover Date Comment Slickline scratcher run Nov 2002 Tagged fill at 10,087' Coil tubing cleanout August 2007 10% DAD acid, net 50 BO, 70 BW Scale inhibitor squeeze April 2008 Bullhead scale inhibitor Slickline scratcher run Dec'08, June '09 Tubing is clear, no fill Slickline scratcher run Jan and Dec 2010 Scratched scale 8250' -8400', no fill in casing Slickline scratcher run May 2012 Cut scale 8,250—8,350 & 9,067, tagged fill at 10,030 Slickline scratcher run Nov 2012 Cut scale from 8,280-8,400' Slickline scratcher run Oct 2013 Scratched scale 8960' -9200', tag fill at 10,026 MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure_FINAL 1 Current Well Status Well is currently producing @100 bopd, 75 bwpd, 115 mcfd gas. Lift gas is continuously injected at 884 mcfd. Wellbore Construction Detail ID Drift Cap. Annular 100% 1.25 SF 100% 1.33 SF Bbl/Ft Bbl/Ft Burst Burst Collapse Collapse Prd Tbg—2-7/8",6.5#, N80 @ 6318' 2.441 2.347 0.00579 0.0291 8590 6872 9070 6819 Prd Tbg-2-3/8'; 4.7#,L80/N80 1.995 1.901 0.00387 11200 8960 11780 8857 @6,318'—8,383' 0.0207 Prd Liner-3.5', 9.3#,N80 10,098' 2.992 2.867 0.00870 8640 6912 7870 5917 Drilling Liner—5" 18#, P110, and Intermediate Csg—7", 29#, N80 Surf Csg—13-3/8",54.5#@ 1925' 12.615 12.459 0.1545 2730 2184 1130 849 Well Data Surface Casing: 13-3/8", 54.5#. Set at 1,609'. Cmt with 1,925 sxs Intermediate Casing: 7", 29#, N80 @ 8,798', sidetrack window @ 6,772' cmt with 1,500 sxs Drilling Liner: 5", 18# P110 FL4S. Set at 8,731'. Production Liner: 3-1/2", 9.3# N80, BTC@ 10,098' (slotted liner)Top of liner @ 8,650'. PBTD: —10,098' Tubing: 2-7/8", 6.5# N80 (surf—6318'), 2-3/8" 4.7# L80/N80 (6318' —8383') Packer: Baker "FH" packer at 8,305' BHST: 170 F BHP: 3000 psi (estimated) Smallest ID: 2-3/8" 'XN' Nipple: 1.791" ID @ 8,350' Max Deviation: 53.17 deg at 3,800' Max DLS: 6.72 deg/100ft at 11,578' Other: Zones GN to HF is perforated across the 7" cemented liner MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure FINAL 2 Vendor Outline Coil Tubing unit—Baker/BJ Services Josh Herald 907-398-8303 Chemical Supply— Baker Petrolite Clyde Willis 907-229-0052 Bits, Motors, BHA Colin Walderp/Jeffery Canter 907-283-8131 Crane Operator—All American Pete Dickinson 907-230-6541 Rousterbout & Drill Supv—All American Pete Dickinson 907-230-6541 GR—CCL logging tool - Schlumberger Barry Milazzo 817-915-9555 Perforating Gun -Schlumberger Tyndall Ellis 907-441-0898 Flowback Iron —All American Oilfield Craig Rang KCI Supply— Baker Hughes Materials Required ■ 18000 gal 10 % HCI Acid ■ 50 bbl Gel pill (supplied by Baker Hughes) ■ 250 bbl 3% KCI —Fresh Water (mixed out of fresh water) ■ 1500 bbl 3% KCI— FIW (fixed out of filtered inlet/sea water) ■ Nitrogen foam will be used for diversion and to assist fluid cleanout ■ 925 gal of Baker Scale Inhibitor, this will be flushed with 3% KCI FIW Equipment Required ■ 1.5" Coil Tubing Unit, 1.5" Pipe, blind rams and Annular preventer BOPE ■ 55 ft Lubricator. Crane, provided by the platform...2 PTS tanks—250 bbl each Diverting Agent (Nitrogen Foam) 75Q ■ Nitrogen volume—260 Mscf. Pumped volume of 3% KCI FIW with nitrogen =850 gal ■ 3 gpt FAW-21 foaming agent Acid Additives and Other Chemicals ■ 10 % HCI — Inorganic acid used to acidize the formation ■ 50 gpt US-40—mutual solvent. Formation water wetting agent & reduce surface tension ■ 25 ppt Ferrotrol 300—acid treatment fluid to prevent precipitation of ferric hydroxide f 25 gpt Super A sol (WLC 603) Mutual solvent (sec section below) ■ 3 gpt NE-945 —Non Emulsifier ■ 5 gpt CI-27—corrosion protection of tubular, casing & BHA ■ 20 gpt Ferrotrol 280L- acid treatment fluid to prevent precipitation of ferric hydroxide ■ 1.0 gpt Clay Master-5C—to prevent formation damage due to scale swelling Lead Fluid Super A-Sol (WLC 603) Mutual solvent,for removal of oil layer& water wet the rock ■ 2000 gal super A-Sol mixed in 2000 gal 3% KCI FIW. This will be divided into 4 stages, 1000 gal for each stage Scale Inhibitor Squeeze ■ 925 gal of mutual solvent A-sol (WLC603) mixed in 22 bbl 3% KCI -FIW MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure_FINAL 3 • 925 gal of scale inhibitor (SCW4004) mixed in 124 bbl FIW...Please call Operations engineer to discuss required volume for over-flush Other Chemicals • Soda Ash —to neutralize spent acid before sending to disposal well • 2.8 gpt FRW-16A— Friction reduction agent for the FIW Well Schematic:A43-11LW TOPLF 4-18-11 ENERGY Current Completion MGS A43-11 LW /'// KB: 38' Cook Inlet, Alaska /%/ Water Depth: 73' Leg 1, Conductor 3 J API No.: 50-733-10082 % Tbg: Spud: 2-7/8"6.5#N80 8rd EUE @ 6318' Sidetrack: / 2-3/8"4.7#L80/N80 8rd EUE @ 6318'-8383' 24"Conductor Csg @ 400' Baker"FV-6"TRSCSSV w/2.313""X"@ 325' Surf Csg: 13 3/8", 54.5 Ib, J55. GLM MD TVD Port Ptro Psc Pso Set @ 1609'. Cmt'd w/1925 sx. 1 1921' 1900' 12 925 892 950 J 2 3356' 3356' 12 910 871 919 3 4508' 4507' 12 895 850 887 4 5406' 5404' 16 950 827 881 // 5 6116' 6113' 16 935 807 845 Production Csg: 7", 29 lb., N80. / 6 6624' 6619' 16 920 788 826 7 7136' 7116' 16 905 767 805 Window @ 6772'for sidetrack. 8 7681' 7608' 20 985 735 798 (Original Set @ 8798'.) J 9 8226' 8110' 1/4"Orifice Cmt'd W/1 500 sx. X-over from 2 7/8"to 2 3/8"tbg @ 6318'(5-2 7/8"D-SO,4-2 3/8"U-SO GLMs) 1 Jt.2 3/8"tbg Otis"X"Nipple @ 8272'(1.875"ID) 1 Jt.2 3/8"tbg Baker"FH"packer @ 8305'w/30K#shear • J 1 Jt 2 3/8"tbg Otis"XN"Profile Nipple @ 8350'(1.791"ID) 1 Jt 2 3/8"tbg / Baker Wireline re-entry guide©8448' Drilling Liner: 5", 18 lb., P110 FL4S. / ' Set @ 8731'. TOL @ 6392'. /// 4 J do J 4 Prod Liner: 3.5", 9.3 Ib, N80 BTC slotted I I liner set @ 10098'.TOL @ 8650'. I I I I TD: 10,098' MD I I MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure_FINAL 4 Production Trend MCF A43-11 LW HEMLOCK BBL 1,100_ .220 1.000. .200 � eoo � rfI _1so 800- r--� Olt ! Jpilyr II r-160 700_ 1i Iy 0,, f i) rII 1' 1 �i .140 600_ 1 'ytio -120 500. / .100 400- r"5r1N_ 80 1 1111 300. 60 200_ _ I .40 Lsir qd-k,„. a �o 10/14108 2/1 5/1 8/1 11/1 2/1 5/11 5/1 11/1 2/1 5/1 5/1 11/1 2/1 5/1 5(1 11/1 2/1 5/1 10/13/13 Gas —Oil —Water —Water In/ —Gan Sljas5d. CO2 Prod ee CO21rtjaeUon SOS Tweet Oa Tarpat —Lfr.Ptoaauto Carte Production Chart (1 year) M200 A43-11 LW HEMLOCK BBL 15o 1,000 •125 800 •100 800 75 400- -50 200• •25 0}IIr (0 4/14/13 6/1 711 8/1 9/1 10/1 11/1 12/1 1'11 211 3/1 4113114 —■Gas —■Oil —■Water —■Water Inj —■Gas Injection 0 CO2 Prod —■CO2 Injection —■Gas Target —■Oil Target ••■LinePressure clear-selections Carte Lift Gas Injection and Production Pressure Chart PSI 1,000- A43-11 LW HEMLOCK Hrs 25 800- -20 B00- 15 400• •10 200 . -5 S . 0 , r0 4/14/11 711 9/1 11/1 111 311 511 7/1 9/1 1111 111 311 511 711 911 1111 1/1 4/13/14 —M Casing Pressure ❑Tubing Pressure —UAnnulus Pressure -•■SurfaceCasingPressure 0 InterCasingPressure D Down Hours -■SoapStick ,:_fear Selection:-: MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure_FINAL 5 Summary Procedure: 1. Conduct safety meeting to review the daily work program and communicated associated risk with the entire crew. it)b•c-r h SPS 2. Test BOPE, NU injection head and lubricator with the holding support of the crane 3. Pickle the coil tubing with acid and flush with 3%brine water, dispose appropriately 4. Pick up the vortex jet nozzle connected to 1-1/2" coil tubing and run into the well. 5. Continue cleaning the production tubing, reduce speed upon approach of the end of tubing.. Cleanout through the liner and proceed until arriving at tagged depth. 6. Perform an extra bottom to top of liner cleanout and continue downhole to tag the well. Record tagged depth and pull coil tubing out of the well. 7. Pick up the bit and motor, if tagged high. Run into well and cleanout additional fill in the liner 8. Lay down the bit and motor. Pick up the roto-jet tool, run into well while cleaning the tubing. Pump down acid across the slotted liner and make multiple bottom to top passes. 9. Shut in the coil tubing annulus and squeeze acid into the perf, pull coil tubing out of well and allow acid to soak for 1-2 hours. 10. Nipple down lubricator, BOPE and move the coil tubing over to the next well. 11. Resume the injection of lift gas on the well. Flow back well to the PTS tank, monitor flow and take periodic pH level of the fluid 12. Once the fluid pH is at recommended level.Call production engineer to discuss the scale inhibitor squeeze sequence. Prepare the batch volume of mutual solvent and separate batch volume scale inhibitor mixed in 3% KCI- FIW. Bullhead into the well to enable squeeze into the producing zones. 13. Resume lift gas injection and collect fluid samples periodically to measure the residuals Risks and Safety Considerations 1. All PPE's (FRC's, hard hat, safety glasses, steel toe boots) must be worn at all times, no exception. Additional PPE's might be required for personnel involved in other specific roles. 2. Pressure test will be required on the BOPE,surface lines and manifolds; refrain from the vicinity of the equipment during these tests. Follow AOGCC itemized set-up for blow-out preventer(Top to Bottom) - One annular type preventer - One blind/shear rams - One pipe ram that is sized for the 1.5" coil tubing 3. Lubricator and injection head will be held with crane during the coil tubing work, personnel should stay clear of the lifting area as much as necessary. 4. Acid and other hazardous chemicals will be mixed in tanks and used during the cleanout process.All required PPE must be used when handling and mixing these chemicals; MSDS sheets must also be available within close proximity of these chemicals MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure_FINAL 6 Pre-Mobilization Plan for Production Operators ***Approximately 1 week prior to resuming coil tubing cleanout, shut off the lift gas supply into the annulus. Open the well to flow up the tubing to bleed-off effluent gas in the well. If well stop flowing, shut-in the well and periodically open to flow to bleed off head gas in the tubing. DETAILED PROCEDURE ***Anticipated shut in pressure on this well is 3000psi. Production tree and wellhead is rated to 5k psi. *** Do not add bleach to the treated FIW ***This well will not be perforated; the tubing size is 2-3/8", hence preventing the run of required gun ***** Note: 3% brine water mixed from fresh water must be used as spacer fluid whenever acid is pumped. Refrain from allowing FIW to get in contact with the acid. All acid will be pre-mixed with fresh water at Baker Hughes site before delivery to the platform. ***** Mobilize, Set-up Equipment, Riq-Up 1. Move in All American Service crew to prepare the platform for the cleanout program, prep work will include insuring space for equipment location are cleared and measured for spotting ahead of time. Ensure crew is on-site at least 3 days prior to coil tubing mobilization. 2. Prior to staging equipment, conduct safety meeting to review the work program; potential hazards should be identified and communicated to the entire crew involved in the program 3. Stage the PTS tanks, move in the 1.5" Coil Tubing unit, lubricator, injector head, acid/other chemical vessels and all associated equipment required for the workover. Set-up the site, lay down and connect pipes to flowback/PTS tank and manifolds. Prepare fresh water mixed adequately with KCI to create 3% brine solution in the mud/PIT tank. - Two PTS tanks will be used on each platform during this program; this will enable adequate flowback of dirty fluid from multiple workover wells before sending offshore. Substantial cleanout of dirty fluid to the disposal well will help in minimizing the amount of sludge transported offshore. - Debris catcher/filter should be installed on the flowback line before the PTS tank to capture solids returns. Filter should be monitored and periodically emptied. MGS A43-111W: Coil Tubing Cleanout and Acidizing Procedure_FINAL C - Ensure there are accessible valves on the flowback line to collect and monitor cleanout fluid on the upstream and downstream of the PTS tanks. Test BOPE, Pickle Coil Tubing 4. Ensure the master and wing valves are closed, re-check to insure the lift gas line is locked out, tagged and closed. Nipple up pipe rams, blind rams, annular preventer, lubricator and injector head. Hoist the lubricator and injector head with the support of the crane. 5. Contact AOGCC 48 hours prior to BOP test,test BOPE to 250 psi and 5000 psi, low and high pressure for both shell and pipe tests. 6. Prior to running the coil tubing into the well, pump 3 bbl of 10% HCI acid down the coil tubing to pickle and flush with 3% KCI—Fresh water. (base fluid of brine must be fresh water). Send the used acid and flush fluid to the PTS tank for appropriate disposal. Cleanout with Vortex Jet Nozzle, Acid Soak and Mill Scale 7. Pick up the vortex jet tool, gamma ray and CCL memory tool and put together the BHA. Memory tool will be installed in the carrier to enable flow around it. 8. Make-up BHA to the coil tubing connector and run into the well. Continue tripping into the well at 100fpm while washing out solids and other debris in the tubing with slick 3% KCI FIW and circulating at 1—2 BPM 9. Continue cleanout and monitor the annulus pressure and returns for difficulty in lifting fluid. Engage the nitrogen and foaming agent to enhance the fluid flowback. Periodically collect samples on the flowback line to assess cleanout effectiveness. 10. Continue cleaning the tubing while proceeding with caution through the restrictions (1.88" 'X' & 1.791" XN-nipple). 11. Reduce the speed while approaching the end of tubing. Continue cleanout through the liner and proceed slowly until tagged. - Pull up every 300 ft to ensure the coil tubing is not getting stuck, pump slugs of gel sweeps to improve the clean-ups. - If tagged high or unable to get to the bottom of the well, pump down 500 gal of acid and spot on top of the scale. Mill will be necessary for further cleanout MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure FINAL 8 12. Make an extra up-down pass from the liner top to the tagged depth to remove additional scale present in the liner. 13. Pull the vortex jet tool out of the well. If unable to get to bottom of the well with the roto-jet tool, pick up 1-11/16" motor 2.5" bit. Run into well at 80 fpm and mill out additional scale deposit in the liner **** This well will not be perforated due to the smaller size tubing (2-3/8") and the inability to locate a smaller gun with effective perforation length **** Acid Squeeze 14. Pick up the roto-jet tool and run in at 100 fpm. Pump down slick 3% KCI FIW while cleaning down to the top of the perforated depth (or top of slotted liner if well wasn't perforated). 15. While at this depth, pump down 10bbI 3% KCI—fresh water spacer and 10 bbl of HCI acid and 10 bbl of 3% KCI-fresh water as 'tail' spacer. Reduce the pumping rate to 0.25 bpm as the acid approach the end of the coil tubing. Gradually trip down the production interval while washing the perforations at this reduced rate.Wash down to the tagged depth. 16. Pull coil tubing back up to 9500 ft, this is the mid-section of the production interval 17. Pump fluid down the tubing while following the tabled sequence below. When 15 bbl of the 3% KCI-fresh water in step 1 have exited the coil tubing, close the coil tubing annulus. Continue pumping the fluid as recommended to squeeze the acid into the formation. Note: Foamed nitrogen in fluid will be used as diverting agent during acid squeeze. This will be applied between each acid stage (refer to table below). MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure FINAL 9 Table 2: Fluid Sequence for Acid Squeeze (FW=Fresh Water, FIW=Filtered Injection Water) Step Fluid Volume Comment/Purpose 1 3% KCI—Fresh Water(FW) 15 bbl Displacement of 3% KCI—FIW into perfs 2 Foamed 3% KCI FW 850 gal Diverting agent to prevent acid into opened zones 3 50% Super A-sol in FW 1000 gal Mutual solvent- remove oil layer in rock&water wet 4 10% HCI acid 3000 gal Acid stage 1 - squeeze into formation 5 Foamed 3% KCI FW 850 gal Nitrogen foam diverting agent (65 Mscf N2) 6 50%Super A-sol in FW 1000 gal Mutual solvent- remove oil layer in rock&water wet 7 10% HCI acid 3500 gal Acid stage 2—squeeze into formation 8 Foamed 3% KCI FW 850 gal Nitrogen foam diverting agent (65 Mscf N2) 9 50% Super A-sol in FW 1000 gal Mutual solvent- remove oil layer in rock&water wet 10 10 % HCI acid 4000 gal Acid Stage 3—Squeeze into formation 11 Foamed 3% KCI FW 850 gal Nitrogen foam diverting agent (65 Mscf N2) 12 50%Super A-sol in FW 1000 gal Mutual solvent- remove oil layer in rock&water wet 13 10 % HCI acid 4500 gal Acid Stage 4—Squeeze into formation 14 3% KCI — Fresh Water 15 bbl Spacer 15 3% KCI — FIW 250 bbl Tubing vol+100%over-displ (liner top to deepest perf) 18. Pull the coil tubing out of the well, lay down the roto-jet nozzle, and re-dress as required. Shut in the well, nipple down the coil tubing lubricator and BOPE. Move coil tubing over to the next well. 19. Allow acid to soak for 1-2 hours. Monitor and chart the tubing pressure. 20. After the designated soak time and upon consultation with the production engineer, open well to flowback to the PTS tank and resume injection of lift gas to aid liquid unloading. Monitor returns and send flowback fluid into the disposal well. - pH of the flowback fluid must be measured and recorded, send record of the data to production engineer and Baker Hughes chemical contact before proceeding to the next step 21. Once the fluid PH is at recommended level (typically pH 5 for extended time), shut off lift gas supply. Scale Inhibitor Squeeze 22. Prepare scale inhibitor mixture. Engage the mud pump and bullhead the scale inhibitor as recommended in table 3. Flush with 3% KCI—FIW and shut in the well for 24 hours. MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure F/ AL 10 Table 3: Scale Inhibitor Squeeze-Fluid Sequence Fluid Type Volume (gal) Comment Mutual Solvent(WLC603) 720 gal mixed with 17 bbl FIW Scale Inhibitor(SCW4004) 720 gal mixed with 97 bbl FIW 3% KCI- FIW To be determined (call Bola) Call prod engr to discuss 23. After 24 hours and upon the approval of the production engineer, handover well to production team and resume injection of the lift gas. 24. Sent the well to test separator. Collect daily, labelled bottle sample of the produced fluid, send sample Baker Hughes lab for further testing for scale inhibitor residuals. Well Deviation Survey A Platform, Well A43-11 LW TVD- Vert. Measured Angle Azimuth RKB TVD DLS Sec deg/100 SVY# Depth deg deg ft Subsea ft ft Tie-In 0.00 0.00 0.00 0.00 -116.00 0.00 0.00 1 100.00 0.50 336.00 100.00 -16.00 0.50 0.27 2 200.00 0.57 340.00 199.99 83.99 0.08 0.82 3 300.00 0.82 346.00 299.99 183.99 0.26 1.43 4 400.00 0.75 341.00 399.98 283.98 0.10 2.12 5 500.00 0.42 334.00 499.97 383.97 0.34 2.71 6 600.00 0.42 335.00 599.97 483.97 0.01 3.18 7 700.00 0.50 338.00 699.97 583.97 0.08 3.67 8 800.00 0.57 357.00 799.96 683.96 0.19 4.07 9 900.00 0.57 2.00 899.96 783.96 0.05 4.32 10 1000.00 0.75 355.00 999.95 883.95 0.20 4.63 11 1100.00 0.50 24.00 1099.94 983.94 0.40 4.77 12 1200.00 1.00 56.00 1199.94 1083.94 0.63 4.11 13 1300.00 1.00 57.00 1299.92 1183.92 0.02 2.93 14 1400.00 0.75 32.00 1399.91 1283.91 0.45 2.13 15 1500.00 0.50 13.00 1499.90 1383.90 0.32 1.94 16 1600.00 0.50 11.00 1599.90 1483.90 0.02 1.97 17 1700.00 0.75 341.00 1699.89 1583.89 0.40 2.35 18 1800.00 1.00 339.00 1799.88 1683.88 0.25 3.21 19 1900.00 1.00 337.00 1899.87 1783.87 0.03 4.23 20 2000.00 1.00 343.00 1999.85 1883.85 0.10 5.21 21 2100.00 1.00 333.00 2099.84 1983.84 0.17 6.23 22 2200.00 0.75 343.00 2199.83 2083.83 0.29 7.14 MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure_FINAL 11 23 2300.00 1.00 341.00 2299.81 2183.81 0.25 7.95 24 2400.00 1.00 341.00 2399.80 2283.80 0.00 8.90 25 2500.00 1.00 341.00 2499.78 2383.78 0.00 9.85 26 2600.00 1.25 326.00 2599.76 2483.76 0.38 11.14 27 2700.00 1.00 310.00 2699.74 2583.74 0.40 12.73 28 2800.00 1.00 303.00 2799.73 2683.73 0.12 14.34 29 2900.00 1.00 302.00 2899.71 2783.71 0.02 15.99 30 3000.00 1.25 302.00 2999.69 2883.69 0.25 17.86 31 3100.00 1.25 304.00 3099.67 2983.67 0.04 19.92 32 3200.00 1.25 308.00 3199.65 3083.65 0.09 21.94 33 3300.00 1.00 321.00 3299.63 3183.63 0.36 23.64 34 3400.00 1.00 336.00 3399.61 3283.61 0.26 24.87 35 3500.00 1.25 333.00 3499.59 3383.59 0.26 26.12 36 3600.00 1.25 333.00 3599.57 3483.57 0.00 27.56 37 3700.00 1.25 325.00 3699.55 3583.55 0.17 29.09 38 3800.00 1.00 322.00 3799.53 3683.53 0.26 30.60 39 3900.00 1.00 311.00 3899.51 3783.51 0.19 32.07 40 4000.00 1.25 312.00 3999.49 3883.49 0.25 33.81 41 4100.00 1.25 303.00 4099.47 3983.47 0.20 35.80 42 4200.00 1.50 299.00 4199.44 4083.44 0.27 38.10 43 4300.00 1.75 294.00 4299.40 4183.40 0.29 40.87 44 4400.00 2.00 287.00 4399.35 4283.35 0.34 44.11 45 4500.00 2.25 284.00 4499.28 4383.28 0.27 47.82 46 4600.00 2.25 280.00 4599.20 4483.20 0.16 51.74 47 4700.00 2.50 283.00 4699.11 4583.11 0.28 55.88 48 4800.00 2.50 283.00 4799.02 4683.02 0.00 60.24 49 4900.00 3.00 279.00 4898.90 4782.90 0.54 65.03 50 5000.00 3.25 281.00 4998.75 4882.75 0.27 70.47 51 5100.00 _ 3.50 282.00 5098.58 4982.58 0.26 76.35 52 5200.00 3.50 282.00 5198.39 5082.39 0.00 82.45 53 5300.00 3.25 284.00 5298.22 5182.22 0.28 88.33 54 5400.00 3.50 283.00 5398.05 5282.05 0.26 94.22 55 5500.00 3.75 280.00 5497.85 5381.85 0.31 100.53 56 5600.00 3.75 281.00 5597.63 5481.63 0.07 107.06 57 5700.00 3.00 279.00 5697.46 5581.46 0.76 112.94 58 5800.00 3.00 279.00 5797.32 5681.32 0.00 118.15 59 5900.00 3.00 279.00 5897.19 5781.19 0.00 123.36 60 6000.00 3.00 282.00 5997.05 5881.05 0.16 128.59 61 6100.00 3.00 281.00 6096.91 5980.91 0.05 133.81 62 6200.00 4.00 280.00 6196.72 6080.72 1.00 139.91 63 6300.00 4.25 280.00 6296.46 6180.46 0.25 147.08 MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure_FINAL 12 64 6400.00 5.00 279.00 6396.14 6280.14 0.75 155.12 65 6500.00 6.00 280.00 6495.68 6379.68 1.00 164.681 66 6600.00 6.00 278.00 6595.13 6479.13 0.21 175.09 67 6700.00 5.75 278.00 6694.60 6578.60 0.25 185.27 Tie-In 6769.00 5.40 277.40 6763.28 6647.28 0.51 195.14 1 6915.00 14.30 312.40 6907.08 6791.08 7.08 219.06 2 6980.00 16.10 310.30 6969.81 6853.81 2.90 235.58 3 7072.00 20.20 302.50 7057.22 6941.22 5.17 263.82 4 7162.00 23.60 296.20 7140.73 7024.73 4.59 297.32 5 7252.00 25.80 291.30 7222.50 7106.50 3.34 334.83 6 7342.00 25.80 290.60 7303.53 7187.53 0.34 373.78 7 7404.00 27.10 291.30 7359.03 7243.03 2.16 401.24 8 7491.00 26.20 292.70 7436.79 7320.79 1.26 440.11 9 7593.00 24.30 290.60 7529.04 7413.04 2.06 483.42 10 7662.00 23.30 291.10 7592.18 7476.18 1.48 511.10 11 8090.00 23.75 291.10 7984.60 7868.60 0.11 681.02 12 8339.00 23.00 291.10 8213.16 8097.16 0.30 779.28 13 8402.00 22.75 294.20 8271.21 8155.21 1.95 803.69 14 8736.00 21.80 299.70 8580.32 8464.32 0.69 930.16 15 8844.00 20.00 304.70 8681.22 8565.22 2.35 968.51 16 8860.00 19.10 315.20 8696.30 8580.30 22.64 973.71 17 8880.00 17.20 321.50 8715.30 8599.30 13.65 979.51 18 8928.00 14.70 322.90 8761.45 8645.45 5.27 991.45 19 9000.00 21.00 309.60 8829.98 8713.98 10.37 1012.29 20 9066.00 25.30 299.70 8890.67 8774.67 8.77 1037.94 21 9102.00 27.00 291.60 8923.00 8807.00 10.97 1053.77 22 9156.00 28.20 286.40 8970.86 8854.86 4.98 1078.51 23 9198.00 27.50 287.80 9008.00 8892.00 2.28 1097.84 24 9248.00 26.80 289.90 9052.49 8936.49 2.37 1120.42 25 9309.00 27.60 290.70 9106.74 8990.74 1.44 1148.11 26 9386.00 27.70 293.40 9174.95 9058.95 1.63 1183.70 27 9457.00 27.90 298.30 9237.76 9121.76 3.23 1216.78 28 9530.00 28.50 300.40 9302.10 9186.10 1.59 1251.24 29 9649.00 29.30 303.80 9406.29 9290.29 1.54 1308.50 30 9743.00 29.50 304.90 9488.18 9372.18 0.61 1354.27 31 9829.00 30.80 304.70 9562.54 9446.54 1.52 1397.07 32 9903.00 31.40 304.00 9625.91 9509.91 0.95 1434.98 33 9999.00 32.60 306.50 9707.32 9591.32 1.86 1485.32 34 10108.00 33.00 307.50 9798.95 9682.95 0.62 1543.47 MGS A43-11LW: Coil Tubing Cleanout and Acidizing Procedure FINAL 13 a J OFFSHORE Well Head Rig Up BAKER■ Q 0/'""1,j HUGHES �. a, y I it 1,1 96"Gooseneck ai c 0 —'` �' i i;+ S&S 800L Injector Head il . ,'ill•, 14 • 7-1 `Jatiy. ir Hydraulic Stripper 4 1/6"10K Al Crossover 4 1/16"10K x 5 1/16"10K 5 1/16"10K Lubricator -10 ft A A 5 1/16" 10K Flow Cross-2 ft 4 Crossover 5 1/16" 10K x 4 1/16" 10K l+ .( 4 1/16"15K Combi BOPs Blind/Shear Ram (. .) ' Pipe/Slip Ram --.— r'` r.' ''1 ^1 `' kk'' V',4 `'J 1 4 1/16" 10K Flow Cross r_ ') I—4 1/16" 15K Blind/Shear Ram �z- • RECEIVED pro MAY 1 3.2008 E N E R G Y Alaska Oil 8 Gas Cons, Commission xTO Energy ln~. AnChOfa9@ 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) May.12, 2008 ~ ~ r O~ Alaska Oil and Gas Conservation Commission ~~ / Attn: Mr. John Norman 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry. Well Operations Report.: Well #A43-11LW -Scale Squeeze Dear Mr. Norman, XTO Energy, Inc. hereby submits its Sundry Operations Report (Form 10-404) for the. scale squeeze performed on the producing well #A43-11LW. This well is located on Platform A, in the Middle Ground Shoal Field of Cook Inlet, AK. Please find attached the following information for your files: SCANNED MAY 2 2 2008 1. Form 10-404 .Sundry Well Operations. Report 2. Daily Report of Operations If you have anyquestions or require additional information, please contactme at (432) 620-6742. .Sincerely, Jeff Gasch Production. Engineer Cc: Paul Figel Scott Griffith Tim Smith RCVCI V ~. ° STATE OF ALASKA AL.~ OIL AND GAS CONSERVATION COM~ION MAY j ~ 2Ot~ REPORT OF SUNDRY WELL OPERATIO~~ alas a Oil & Gas Cons. Corrlf:, 1, Operations Abandon Repair Well Plug Perforations Stimulate Oth SgUBeZe Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate. ^ Re-enter Suspended Well 2. Operator XTO Energy Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Develo merit ~ p ^ Exploratory^ J~© 3. Address: 200 N. Loraine, Suite 80Q, Midland, TX 79701 Stratigraphic^ Service^ 6. API Number. 50-733-10082-01 7. KB Elevation (ft): 9. Well .Name and Number. 116' MGS A43-11 LW 8. Property Designation: 10. Field/Pool(s): ADL-18754 ~ Middle Ground Shoal E,F,G Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,108 feet Plugs (measured) true vertical g 801 feet Junk (measured) Effective Depth measured 10,098 ~ feet true vertical 9,799 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 400 24" 400 400 Surface 1609 13-3/8" 1609 1609 2730 1130 .Intermediate 6772 7" 6772 6763 8160 7020 Production 2339 5" 8731 8580 13940 13450 Liner 1448 3-1/2" 10098 9799 slotted slotted Perforation depth: Measured depth: $,731-10,098 (Slotted liner) True Vertical depth: 8,580-9,799 (slotted liner) Tubing: (size, grade,. and measured depth). 2-7/8" & 2-3/8" N-80 8,383' Packers and. SSSV (type and measured depth) Baker FH Pkr @.8,305' Baker FV-6 SSSV @ 325' 12. Stimulation or cement squeeze summary: Intervals treated (measured): pp~ 8,731-10,098' S DT'L ~A~ 2 2 1~~8 Treatment descriptions including volumes used and final pressure: Squeeze formation w/ 48 bbls Nalco scale inhibitor at 1.4 bpm & 0 psi.. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 195 98 102 635 100 Subsequent to operation: 208 93 108 620 80 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q . Service. ^ Daily Report of Well Operations x 16. Well Status after work: Oil Q Gas ^ WAG ^ GINJ ^ WINJ ^, WDSPL ^ 17. I hereby certify that the foregoing is true and .correct to the bestof my knowledge. Sundry Number or N/A if C.O. Exempt: 308-141 Contact Jeff Gasch Printed Name Jeff Gasch Title Production Engineer Signature ~ Phone (432) 620 6742 Date 5/12/2008 " Form 10-404 Revised 04/2006 {~ Submit Original Only XTO Energy -Midland District Workover Report Page 1 of 2 and Well Workover Re rt MIDDLE GROUND SHOAL A Well # 43-11 LW Objective: Scale check. First 04!24/2008 Report: AFE: 7137 4/25/08 IDA arrive on Platform A. Clean pits and prep mud pumps. RU flowline from mud pump to tubing. 4/26/08 Mix FIW to 3% KCL. Add 200 gals scale inhibitor (Nalco EC6085A} to 43 bbls 3°Io KCL F1W. Pressure test lines to 3500 psi. Open well & pump 48 bbl inhibitor pill followed by 165 bbls 3°Io KCL FIW @ 1.4 bpm. Never caught any pressure. RD lines and mud pump. Clean & pickle pits. SI well until morning 4/27!08 Attempt to bring well on. Casing pressure will not drop below 770 psi. Appear to have gas lift valve. leaking. 4/28/08 Well still Lifting w/ 770 psi csg pressure. RU wireline. RIH with WTS Temp /Pressure recorder. Made stops 100' + all GLM's 1 through 9. POOH. Survey, test chart & gas injection chart were erratic. We did find that no gas is moving through the # 9 Orifice. Valves 6, 7 and 8 all seem to be fluctuating & passing gas. Valves up hole are opening and passing gas as well but seem to in a cycle and not steady.Due to closing pressure of the valve 6, 7 and 8, we believe #6 or 7 may be the culprit with a small chance that the orifice valve could be plugged.New GLV' for 6, 7 or 8 will not be available until morning so we decided to inspect the orifice.RIH with tight 2" scratcher through the 2-318" x 2-718" X-over at 6340' WLM continued down hole out end of tubing to 8450' WLM. Tubing is clear, pull up hole to # 9 GLM. Brush. pocket several times. Pull out of the hole. RIH with Daniels KOT & ML pulling tool to 8251' WLM. Latch & pull # 9 GLM orifice valve (1/4"). POOH.Attempt to `sweep' empty pocket. Brought well on but again casing pressure never came below 770 indicating that a valve up above the orifice is leaking. RIH & set a new 1/a" orifice valve in station # 9 at 8250' WLM. POOH. Forwarded survey information with design sheet to Pollard WL for their evaluation. They suggest # 6 or # 8 to be bad. Well is on production making about 270 BPD gross. Secure equipment & SDFN. 4/29/08 Rig up wireline and pressure test lubricator. RIH with Daniels KOT & ML pulling tool to 7707' WLM. .Latch- & pull # 8 GLV. POOH. RIH with Daniels KOT & new # 8 GLV to 7707'. Set. POOH. Bring well on to production. Casing will still not drop below 770 PSI. RIH with Daniels KOT & ML pulling tool to 6653' WLM. Latch & pull # 6 GLV. POOH. RIH with Daniels KOT & new # 6 GLV to 6653'. Set. POOH. Bring well on to production. Casing will still not drop below 770 PSI. Contact Pollard & order out new # 7 and # 5 GLV's to be delivered in the morning. Well is on production making about 270 BPD gross. Secure equipment & SDFN. 4/30/08 Rig up wireline and pressure test lubricator. RIH with Daniels KOT & ML pulling tool to 7162' WLM. Latch & pull # 7 GLV. POOH. RIH with Daniels KOT & new # 7 GLV to 7162'. Set. POOH. Bring well on to production. Casing will still not drop below 770 PSI. Order GLV's # l through # 5 from Pollard. Arrived in 2 hours. RIH with Daniels KOT & ML pulling tool to 6142' WLM. Latch & pull # 5 GLV. POOH. RIH with Daniels KOT & new # 5 GLV to 6142'. Set. POOH. Bring well on to production. Casing will still not drop below 770 PSI. RIH with Daniels KOT & ML pulling tool to 5434 WLM. Latch & pull # 4 GLV. POOH. RIH with Daniels KOT & new # 4 GLV to 5434'. Set. POOH. RIH with Daniels KOT & ML pulling tool to 5434 WLM. Latch & pull # 3 GLV. POOH. RIH with Daniels. KOT & new # 3 GLV to 5434'. Set. POOH. Bring well on to production at 10:30PM. Production operator is going to monitor well till morning. Secure equipment & SDFN. 5/1/08 Well did not drop below 770 PSI on the casing overnight. Rig up wireline and pressure test lubricator. http://dor/rept_workover.asp 5/12/2008 XTO Energy -Midland District Workover Report ~ Page 2 of 2 RIH with Daniels KOT ~ pulling tool to 3357' WLM. Latch "pull # 2 GLV. POOH. RIH with Daniels KOT & new # 2 GLV to 3357'. Set. POOH. RIH with Daniels KOT & ML pulling tool to 1923' WLM. Latch & pull # 1 GLV. POOH. RIH with Daniels KOT & new # 1 GLV to 1923'. Set. POOH. Bring well on to production. Looked good at first. Casing pressure dropped from 910 to 745 smoothly but then well started loading up and pressure built back up to 770 PSI and hung there. Note that samples from well right now are heavily emulsified. With all GLV's now changed, we are assuming that we may have to flow well in current condition until the emulsification problem clears up before the GLV system will work properly. Production operator is taking periodic samples to see if emulsion is thinning out and will continue to do so as needed. 5/2/08 Emulsified fluid has cleaned up. Lifting off orifice w/csg press 670 psi. 5/3/08 Well tested 214 bopd & 116 bwpd w/ 858 mcfpd lift gas C~ 655 psi csg pressure. Final Report. http://dor/rept_workover.asp 5/12!2008 • • s ~ k COrITSERQ~A~iO OIrIIIISSIO1s~T Jeff Gasch Production Engineer X'PO Energy Inc. 200 N. Loraine, Ste 800 Midland, TX 79705 Re: Middle Ground Shoal, G Zone, MGS A43-11 LW Sundry Number: 308-141 ~~~~~~~C~ APR ~~ 3 200 Dear Mr. Gasch: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 as-©s~ r 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. When providing notice for a representative of the Corrunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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 ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this .~- day of April, 200$ Cathy . Foerster Commissioner Encl. • • 0 APR 1 5 20G$ E 1V' E R G Y I11a ~jf ~ ~§ ~$. Corrtm~s~or~ XTO Energy Inc. A~K:I'fOf~6 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) April 14, 2008 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Sundry Approval to scale squeeze well A43-11LW. Dear Mr. Norman: XTO Energy, Inc. hereby submits its Application for Sundry Approval to squeeze the A43-11LW with scale inhibitor. This well is located on Platform A in the Middle Ground Shoal Field of the Cook Inlet. The well is an oil producer in the West Flank Hemlock reservoir which has a history of scaling problems. The well was last treated in August 2007. Please find attached the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Job Procedure 3. Present Wellbore Schematic Please contact me with any questions @ 432-620-6742. Sincerely, eff Gasch Production Engineer Cc: Scott Griffith Paul Figel Scott Landon LJ STATE OF ALASKA f'`'-'''tili~ APR Z 5 20Q8 ALA O!L AND GAS CONSERVATION COMP~ON APPLICATION FOR SUNDRY APPROVA~a Oil & Gas Cons. Comm~ssi~on 20 AAC 25.280 AnChOf~G~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ .Other Q Alter casing[] Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ fc4,~t ~h/j,~~~. Change approved program^ Pull Tubing^ Perforate New Pool ^ Re-enter Suspended Well ^ k-«~~'" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ~'/G. XTO Energy Inc. Development ^ Exploratory ^ 195-50 3. Address: Stratigraphic ^ Service ^ 6. APt Number: 200 N Loraine, Suite 800. Midland, TX 79705 50-733-10082-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MGS A43-11 LW 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL-18754 • 116' Middle Ground Shoal "G" Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ~ /17~/(y$ 8 9,799 10;098 9,799 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 400 24" 400 400 Surface 1609 13-3/8" 1609 1609 2730 1130 Intermediate 6772 7" 6772 6763 8160 7020 Production 2339 5" 8731 8580 13940 13450 Liner 1448 3-112" 10098 9799 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8731-10098 (slotted liner) 8580-9799 (slotted liner) 2-7/8" & 2-3/8" N-80 8383' Packers and SSSV Type: Baker "FH" Pkr & Baker "FV-6" SSSV Packers and SSSV MD (ft): Pkr @ 8305' &SSSV @ 325' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 4/29/2008 16. Well Status after proposed work: Commencing Operations: Oil Q Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jeff Gasch Printed Name Jeff Gasch Title Production Engineer Signature / Phone 432-620-6742 Date 4/14/2008 t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~+ ~ ~' Plug Integrity [] BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: S ~~~ ~~~ ~. rt.~~~ Subsequent Form Required: ri`~ ~( \ APPROVED BY Approved by: CO,N,~MISSIONER THE COMMISSION Date: , ( _ D~ i~ Form 10-403 Reyf'sed 06/2006 ~ ~ I f~ I n t /~ ~ `1~~~4~ Submit in Dupli~ /~ • XTO Energy Inc. MGS A43-11LW (WEST FLANK) COOK INLET, ALASKA WELL DATA SURFACE CASING: 13 3/8" 54.5# J55 BTC. Set @ 1,609'. Cmt w/ 1925 sx. PRODUCTION CASING: 7" 29#, N80. Window for sidetrack @ 6772' Cmt'd w/ 1500 sx. DRILLING LINER: 5" 18#, P110, FL4S @ 6,392' - 8,731' Cmt w/ 415 sx. PRODUCTION LINER: 3-1/2" 9.3#, N-80 BTC slotted liner @ 8,650' -10,098' TUBING: 2-7/8" 6.5# N80 8rd EUE: Surf - 340' (9 jts) Baker FV-6 SSSV w/ 2.313" X @ 340' 2-7/8" 6.5# N80 8rd EUE: 340-1921' (51 jts) GLM #1 @ 1921' 2-7/8" 6.5# N80 8rd EUE: 1,921-3,356' (45 jts) GLM #2 @ 3,356' 2-7/8" 6.5# N80 8rd EUE: 3,356-4,508' (37 jts) GLM #3 @ 4,508' 2-7/8" 6.5# N80 8rd EUE: 4,508'-5,406' (28 jts) GLM #4 @ 5,406' 2-7/8" 6.5# N80 8rd EUE: 5,406-6,116' (22 jts) GLM #5 @ 6,116' 2-7/8" 6.5# N80 8rd EUE: 6,116-6,318' (6 jts) 2-3/8" pin x 2-718" 8rd EUE x-over @ 6,318' 2-3/8" 4.7# N80 8rd EUE: 6,318-6,624' (10 jts) GLM #6 @ 6,624' 2-3/8" 4.7# N80 8rd EUE: 6,624-7,136' (16 jts) GLM #7 @ 7,136' 2-3/8" 4.7# N80 8rd EUE: 7,136-7,681' (17 jts) GLM #8 @ 7,681' 2-3/8" 4.7# N80 8rd EUE: 7,681-8,226' (17 jts) GLM #9 @ 8,226' 1 Jt 2-3/8" 4.7# N-80 8rd EUE Otis X nipple @ 8,272' (1.875" ID) 1 Jt 2-3/8" 4.7# N-80 8rd EUE Baker FH packer @ 8,305' w/ 30K# shear 1 Jt 2-3/8" 4.7# N-80 8rd EUE Otis XN nipple @ 8,350' (1.791" ID) 1 Jt 2-3/8" 4.7# N-80 8rd EUE 2-3/8" WL re-entry guide @ 8,383' PACKER: Baker 5" FH Pkr @ 8,305' i~ XTO Energy Inc. • • 2 MGS A43-11LW 4-11- 08 OPEN PAY: 8,731-10,098' (3-1/2" slotted liner) BHST: 165 Deg F BHP: 3200 psi MAX DEVIATION: 33 deg @ 10,098' SMALLEST H): 1.791" @ 8,350' XN Nipple PRESENT STATUS: Prod 194 BOPD, 100 BWPD on gas lift. OBJECTIVE: Scale squeeze NOTES: • Heat FIW to +/- 100°F before pumping downhole. Materials Required: • 210 bbls 3%KCL FIW 0 2,1001bs KCL (1,000 lbs / 100 bbl FIW for 3%) (provided by MI) • 200 gals Nalco EC6085A PROCEDURE: 1. SD gas lift. 2. RU mud pump to tubing. Test lines to 5000 psi. 3. RU steam lines to pit to heat FIW to +/-100° F before pumping downole. 4. Mix 200 gals Nalco EC6085A scale inhibitor w/43 bbls 3%KCL FIW. Have 165 bbls 3%KCL FIW in pits for flush. 5. Pump 48 bbl Scale Inhibitor @ +/-1 BPM & 4000 psi max. Flush inhibitor w/ 165 bbls 3%KCL FIW 6. RD lines from mud pump. 7. Leave well SI for +/- 24 hrs for scale inhibitor to adsorb to formation. 8. RWTP. Jeff Gasch Production Engineer Paul Figel Engineering Manager 1~ TO ENERGY MGS A43-11 LW Cook Inlet, Alaska Leg 1, Conductor 3 API No.: 50-733-10082 Spud: Sidetrack: 24" Conductor Csg @ 400' Surf Csg: 13 3/8", 54.5 Ib, J55. Set @ 1609'. Cmt'd w/ 1925 sx. Production Csg: 7", 29 Ib., N80. Window @ 6772' for sidetrack. (Original Set @ 8798'.) Cmt'd w/ 1500 sx. Drilling Liner: 5", 18 Ib., P110 FL4S. Set @ 8731'. TOL @ 6392'. Prod Liner: 3.5", 9.3 Ib, N80 BTC slotted liner set @ 10098'. TOL @ 8650'. TD: 10,098' MD CJ PLF 7-26-04 KB: 38' Water Depth: 73' Tbg: 2-7/8" 6.5# N80 8rd EUE @ 6318' 2- 3/8" 4.7# L80/N80 8rd EUE @ 6318'-8383' ker "FV-6" TRSCSSV w/ 2.313" "X" @ 325' M MD TVD Port Ptro Psc Pso 1921' 1900' 12 925 892 950 3356' 3356' 12 910 871 919 4508' 4507' 12 895 850 887 5406' 5404' 16 950 827 881 6116' 6113' 16 935 807 845 6624' 6619' 16 920 788 826 7136' 7116' 16 905 767 805 7681' 7608' 20 985 735 798 8226' 8110' 3/16" Orifice rver from 2 7/8" to 2 3!8" tbg @ 6318' (5 - 2 7/8" D-SO, 4 - 2 3/8" U-SO GLMs) . 2 3/8" tbg s "X" Nipple @ 8272' (1.875" ID) t. 2 3/8" tbg ker "FH" packer @ 8305' w/ 30K# shear t 2 3/8" tbg s "XN" Profile Nipple @ 8350' (1.791" ID) t 2 3/8" tbg ker Wireline re-entry guide @ 8383' Current Com2etion . . RECEIVED SEP 1 0 2007 ;[!9 .~¡aska Oil & Gas Cons. Commission ,Anchorage XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) September 7, 2007 05"0 \Q5-'" Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Well Operations Report: Well #A43-11LW - Coil Tubing Stimulation Dear Mr. Norman, XTO Energy, Inc. hereby submits its Sundry Operations Report (Form 10-404) J9.f the coil tubing j stimulation performed on the producing well #A43-11LW. This well is located on Platform A, in the Middle Ground Shoal Field of Cook Inlet, AK. Please find attached the following information for your files: 1. Form 10-404 Sundry Well Operations Report 2. Daily Report of Operations 3. Present Wellbore Schematic SCJ.b~NED SE? 1 92007 If you have any questions or require additional information, please contact me at (432) 620-6742. Sincerely, 7#.;iL Jeff Gasch Production Engineer Cc: Paul Figel Scott Griffith Tim Smith . STATE OF ALASKA . AlA~ Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS KI::Gt:.IVI::U SEP 1 0 2007 Alaska Oil & Gas Cons. COO1mission . 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate l!J .;- Other U " Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator XTO Energy Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q / Exploratory 0 195-50 ./ 3. Address: 200 N. Loraine, Suite 800, Midland, TX 79701 Stratigraphic 0 Service 0 6. API Number: 50-733-10082-01 r, 7. KB Elevation (ft): 9. Well Name and Number: 116' ~ MGS A43-11 LW 8. Property Designation: 10. Field/Pool(s): ADL-18754 / Middle Ground Shoal E,F,G Oil Pool '" 11. Present Well Condition Summary: Total Depth measured 1 0, 1 08 ' feet Plugs (measured) true vertical 9,801 ' feet Junk (measured) Effective Depth measured 10,098 feet true vertical 9,799 .,' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 400 24" 400 400 Surface 1609 13-3/8 " 1609 1609 2730 1130 Intermediate 6772 7" 6772 6763 8160 7020 Production 2339 5" 8731 8580 13940 13450 Liner 1448 3-1/2" 10098 9799 slotted slotted Perforation depth: Measured depth: 8,731-10,098 (slotted liner) True Vertical depth: 8,580-9,799 (slotted liner) Tubing: (size, grade, and measured depth) 2-7/8" & 2-3/8" N-80 8,383' Packers and SSSV (type and measured depth) Baker FH Pkr @ 8,305' Baker FV-6 SSSV @ 325' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8,731-10,098' y Treatment descriptions including volumes used and final pressure: Clean out scale and stimulate with 8,000 gals 75:25 10% acid!xylene. Final wellhead pressure during acid squeeze was 1500 psi @ 0.9 bpm. / 13. }J., tr~1 Representative Daily Average Production or Injection Data Oil-Bbl 4J ~ C\.h.<rGas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 93 , ~~'1...(,. ,\ 60 '" (,.,'-\ VoA.{ 'tn \ 61 670 80 Subsequent to operation: 206 , c;,~ "?""'l \. 156 ...·'\(,,\o.\/~t 141 750 80 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory 0 Development Q , Service 0 Daily Report of Well Operations x 16. Well Status after work: OilQ ~. Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 307-253 Contact Jeff Gasch Printed Name Jeff Gasch Title Production Engineer Signature Wc..ti j Phone (432) 620 6742 Date 9/6/2007 . Form 10-404 Revised 04/2006 0 RIG I NA I , RBDMS BFl SEP 1 9 20D7 4 ~ Submit Original Only . ~ ,.~C>7 ~..Þ f./I. °1 · XTO Energy - Midland District Worer Report . Midland Well W orkover Report IIMIDDLE GROUND SHOAL A II Well # 43-11 LW II Objective: Chng Out Equipment First 08/23/2007 Report: AFE: 7137047137 8/23/07 PTSM. Check cranes & prep decks for coil equip. Off load boat. RU PTS flowback tnk. Page 1 of 2 II 8/24/07 PTSM. Fill pits wI FIW & mix to 3% KCL & heat to 100F. Unload Schlumberger equipment from boat. RU coil equip. 8/25/07 Finish RU CT. Test coil, BOPE and circ lines to 25015000 psi. Test flow back line to 250/2000 psi. Pre- job safety and operation meeting with XTO - IDA - Schlumberger. Ready to RIH - DC invertor shorted out in ops cab. Trouble shoot and repair. RIH with wash nozzle @ 40-60 fpm, pumping 0.5bpm @ 250psi initial pressure. Increase pump rate once in 2 3/8" tubing to 1.4 bpm @ 2450 psi. Tag hard bridge at 8929'. PumplO bbls acid to end of coil and close in backside. Squeeze acid past bridge in slotted liner. Inj pressure dropped from 2000 psi to 1000 psi after washing through bridge. Continue in hole at 20 fpm, pumping 1 bpm @ 2400 psi. Wash with 3% KCL FIW at 9200' at 6:00 a.m. 8/26/07 Cont. wash 3-112" liner to 10,098. Pmp 20 bbls Flow Visc sweep. Lay in 13 bbls 10% DAD acid from 10,098' - 8650'. POOH to 8300' & circ minimum rate while SD. Let acid soak for 1 hr. RIH to 10,098 while pmpg 20 bbls Flow Visc sweep at 1 bpm & 2400 psi. Circ hole clean wI 3% KCL FIW. Acid wash slotted liner wI 10% DAD acid at 1 bpm & 2400 psi while making one pass up & dwn. Chase acid wI 20 bbl Flow Visc sweep at 1 bpm & 2400 psi. SI return lines at flow cross & choke & sqz 6,000 gals 10% DAD acid into formation at 0.9 bpm, 4500 psi pmp press & 1,500 psi wellhead press while making passes with wash tool through liner. Over displace acid with 100 bbls 3% KCL FIW (no friction reducer). POOH to 6,000' & prep to flow back well with N2. Start N2 at 300 scf/min. Pump for one hour with no returns. POOH slowly to get well flowing. Started getting returns at 3667'. Rec 10 bbls in 30 mins & well died. Continue jetting well in at 6:00 a.m, 8/27/07 Continue unloading well with N2. Rec 50 bbls total. Start circ btms up wI 3% KCL FIW. Make 4 passes from 8100' - 8350' washing btm gas lift mandrel. Spot 43 bbls scale inhibtor to end of coil tbg. Close in backside & sqz inhibitor at 1 bpm, 4000 psi pump press & 900 psi wellhead press making passes through liner. Flush with 120 bbls 3% KCL FIW. Open backside & POOH pmpg remaining wtr from pits. At 4000' begin pmpg N2 to blow reel dry. Close swab valve & rig down coil equip. Prep for boat. 8/28/07 Back load coil equipment. RU PTS tank to production header. RWTP on gas lift at 15:00. At 6:00 am had rec 276 bbls from well. Injecting returns into disposal well. 8/29/07 Continue to monitor flowback to PTS tank. Inject returns down disposal well. Rec 662 bbls total from well. Water cut 70%. PH 5-7. Tested 145 bopd & 249 bwpd. 8/30/07 Tested 174 bopd & 213 bwpd. 8/31/07 Tested 184 bopd & 201 bwpd. 9/1/07 Tested 195 bopd & 177 bwpd. 9/2/07 Tested 205 bopd & 144 bwpd. http://dor/repCworkover.asp 9/7/2007 .XTO Energy - Midland District wor. Report 9/3/07 Tested 207 bopd & 141 bwpd. 9/4/07 Tested 206 bopd & 141 bwpd. Final Report. Page 2 of 2 http://dor/repCworkover.asp 91712007 ~ ' . ;[!~ MGS A43-11 LW Cook Inlet, Alaska Leg 1, Conductor 3 API No.: 50-733-10082 Spud: Sidetrack: 24" Conductor Csg @ 400' Surf Csg: 13 3/8", 54.5 Ib, J55. Set @ 1609'. Cmt'd w/1925 sx. Production Csg: 7", 29 lb., N80. Window @ 6772' for sidetrack. (Original Set @ 8798'.) Cmt'd wI 1500 sx. Drilling Liner: 5", 18Ib., P110 FL4S. Set @ 8731'. TOL @ 6392'. Prod Liner: 3.5", 9.3 Ib, N80 BTC slotted liner set @ 10098'. TOL @ 8650'. TD: 10,098' MD Current ComDletion 1 I I I I I L_I . PLF 7-26-04 KB: 38' Water Depth: 73' Tbg: 2-7/8" 6.5# N80 8rd EUE @ 6318' 2- 3/8" 4.7# L80/N80 8rd EUE @ 6318'-8383' Baker "FV-6" TRSCSSV wI 2.313" "X" @ 325' GLM MD TVD Port ptro Psc Pso 1 1921' 1900' 12 925 892 950 2 3356' 3356' 12 910 871 919 3 4508' 4507' 12 895 850 887 4 5406' 5404' 16 950 827 881 5 6116' 6113' 16 935 807 845 6 6624' 6619' 16 920 788 826 7 7136' 7116' 16 905 767 805 8 7681' 7608' 20 985 735 798 9 8226' 8110' 3/16" Orifice X-over from 2 7/8" to 23/8" tbg @ 6318' (5 - 2 7/8" D-SO, 4 - 23/8" U-SO GLMs) 1 Jt. 2 3/8" tbg Otis "X" Nipple @ 8272' (1.875" ID) 1 Jt. 2 3/8" tbg Baker "FH" packer @ 8305' w/30K# shear 1 Jt 2 3/8" tbg Otis "XN" Profile Nipple @ 8350' (1.791" ID) 1 Jt 2 3/8" tbg Baker Wireline re-entry guide @ 8383' . ~~~~Œ (ill~ ~~~~æ~ . AI.ASIi& OIL AND GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jeff Gasch Production Engineer XTO Energy Inc. 200 N. Loraine, Suite 800 Midland, TX 79705 - OcfD b...... \~ Re: Middle Ground Shoal Field, E, F, G Oil Pool, MGS A43-11LW Sundry Number: 307-253 Dear Mr. Gasch: SCANNED AUG 0 62007 Enclosed is the approved Application for Sundry Approval relating. to the above referenced well. Please note the conditions of approval set out';jn the enclosed form.··· ..> i","·';.~';'''¡; When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ã. day of August, 2007 Enc!. .y . . RECE\VED JUL 3 I} 2007 ;[t~ !.\¡Iaska Oil & Gas COilS. Commissíon Am::horagc XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) July 27, 2007 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 / RE: Request for Sundry Approval to clean out and acid stimulate well A43-11LW with coil tubing. Dear Mr. Norman: XTO Energy, Inc. hereby submits its Application for Sundry Approval to clean out and acid stimulate well A43-11LW on Platform A, in the Middle Ground Shoal Field of Cook Inlet. The well is an oil producer in the West Flank Hemlock reservoir and production has dropped significantly ./ over the past several months due to scale precipitation in the well bore. The treatment will be done using coil tubing. Please find attached the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Job Procedure 3. Present Wellbore Schematic Please contact me with any questions @ 432-620-6742. :fi~ Production Engineer Cc: Scott Griffith Paul Figel Kameron Fivecoat It p:T.> r/.3/7 Á I STATE OF ÁLASKA r¡;r g;~ AL A OIL AND GAS CONSERVATION COM.SION ~ APPLICATION FOR SUNDRY APPROVALS ~ " Alaska Oil & Gas Cons. Commission RECEIVED JUL 3 0 2007 20 AAC 25 280 1. Type of Request: AbandonO Alter casingO Change approved progran[] 2. Operator Name: XTO Energy Inc. 3. Address: 200 N Loraine, Suite 800, Midland, TX 79705 Suspend 0 Repair well 0 Pull TubingO Operational shutdownO Plug PerforationsO Perforate New PoolO 4. Current Well Class: Development 0 ~ Stratigraphic 0 Perforate 0 Waiver[JnChorage Stimulate 0 ~ Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: OtherO Exploratory 0 Service 0 195-50 6. API Number: ,/ 50-733-10082-01 ,. 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 MGS A43-11 LW ~ 9. Property Designation: 10. KB Elevation (It): 11. Field/Pool(s): ~ F; ~ O,ï/iÞÞ/ ADL-18754 - 116' Middle Ground Shoal ~Pool ~. .,·IU:>" 12. PRESENT WELL CONDITION SUMMARY Total Depth M,D ~:1'"'' 'rota I Depth YVD (ltjl.,7 Effective Depth MD (It): Effective Depth TVD (It): Plugs (measured): 1q.IO~ 'r~~ ,ßOI þþ1'~ 10,098 9,799 none Casing Length Size MD TVD 8. Well Name and Number: Junk (measured): none Burst Collapse Structural Conductor Surface Inte rmedia te Production Liner 400 24" 1609 13-3/8" 6772 7" 2339 5" 1448 3-1/2" 400 1609 6772 8731 10098 400 1609 6763 8580 9799 slotted 2730 8160 13940 1130 7020 13450 slotted Perforation Depth MD (It): 8731-10098 (slotted liner) Packers and SSSV Type: Perforation Depth TVD (It): Tubing Size: Tubing Grade: 8580-9799 (slotted liner) 2-7/8" & 2-3/8" N-80 Baker "FH" Pkr & Baker "FV-6" SSSV Packers and SSSV MD (It): Tubing MD (It): 8383' Pkr @ 8305' & SSSV @ 325' 13. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 15. Estimated Date for o o 14. Well Class alter proposed work: Exploratory 0 Development 8/20/2007 16. Well Status alter proposed work: 0~ Service o Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certily that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Jeff Gasch Title Production Engineer Signature 911~ Phone 432-620-6742 Date Date: Oil 0 ~ WAG 0 Gas 0 GINJ 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Jeff Gasch 7/27/2007 COMMISSION USE ONLY Conditions of approval: Notily Commission so that a representative may witness Sundry Number: <207 of c;;l.~ ~ Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Other: SOCf) "S\ <.... \' \š()~ -\c<;>\ o..<~ ~ \CJ..."'~ ~ _ Location Clearance 0 RBDMS BFL AUG 0 " 2007 Approved by: Form 10-403 Revised 06/2006 (lj" ~Â -T/i tk:M~ER ORfGI ffAL APPROVED BY THE COMMISSION Date: J? ..3-41" Subsequent Form Required: LtC'-\.. ~7Q16/ ~jmit;. r;;I~c~7 . . XTO Energy Inc. MGS A43-11LW (WEST FLANK) COOK INLET, ALASKA WELL DATA SURFACE CASING: 13 3/8" 54.5# J55 BTC. Set @ 1,609'. Cmt wi 1925 sx. PRODUCTION CASING: 7" 29#, N80. Window for sidetrack @ 6772' Cmt'd wi 1500 sx. DRILLING LINER: 5" 18#, PlIO, FL4S @ 6,392' - 8,731' Cmt wi 415 sx. PRODUCTION LINER: 3-1/2" 9.3#, N-80 BTC slotted liner @ 8,650' -10,098' TUBING: 2-7/8" 6.5# N80 8rd EVE: Surf - 340' (9 jts) Baker FV-6 SSSV wi 2.313" X @ 340' 2-7/8" 6.5# N80 8rd EVE: 340-1921' (51 jts) GLM #1 @ 1921' 2-7/8" 6.5# N80 8rd EVE: 1,921-3,356' (45 jts) GLM #2 @ 3,356' 2-7/8" 6.5# N80 8rd EVE: 3,356-4,508' (37 jts) GLM #3 @ 4,508' 2-7/8" 6.5# N80 8rd EVE: 4,508' -5,406' (28 jts) GLM #4 @ 5,406' 2-7/8" 6.5# N80 8rd EVE: 5,406-6,116' (22jts) GLM #5 @ 6,116' 2-7/8" 6.5# N80 8rd EVE: 6,116-6,318' (6 jts) 2-3/8" pin x 2-7/8" 8rd EUE x-over @ 6,318' 2-3/8" 4.7# N80 8rd EVE: 6,318-6,624' (10 jts) GLM #6 @ 6,624' 2-3/8" 4.7# N80 8rd EVE: 6,624-7,136' (16 jts) GLM #7 @ 7,136' 2-3/8" 4.7# N80 8rd EVE: 7,136-7,681' (17 jts) GLM #8 @ 7,681' 2-3/8" 4.7# N80 8rd EVE: 7,681-8,226' (17 jts) GLM #9 @ 8,226' 1 Jt 2-3/8" 4.7# N-80 8rd EVE Otis X nipple @ 8,272' (1.875" ill) 1 Jt 2-3/8" 4.7# N-80 8rd EVE Baker FH packer @ 8,305' wi 30K# shear 1 Jt 2-3/8" 4.7# N-80 8rd EVE Otis XN nipple @ 8,350' (1.791" ill) 1 Jt 2-3/8" 4.7# N-80 8rd EVE 2-3/8" WL re-entry guide @ 8,383' PACKER: Baker 5" FH Pkr @ 8,305' . XTO Energy Inc. MGS A43-11L W 7-24-07 OPEN PAY: . . 2 8,731-10,098' (3-1/2" slotted liner) BHST: 165 Deg F BHP: 3200 psi MAX DEVIATION: 33 deg @ 10,098' SMALLEST ID: 1.791" @ 8,350' XN Nipple PRESENT STATUS: Prod 102 BOPD, 70 BWPD on gas lift. OBJECTIVE: Clean up scale in wellbore and scale squeeze NOTES: · AFE # 713704 · No fluids shall be pumped into the production header. Send all returns to flowback tank and pump to disposal well. · Record any use of the disposal well with fluid type, volume and injection rates & pressures. Overflush by 125 bbl FIW at end of disposing fluids. · Heat FIW to +/- 100°F before pumping downhole. · Talk to Production Operators about not bleaching the waterflood plant immediately before or during operations Materials Required: · 8,500 gals 10% DAD Acid. (75:25 Acid:Xylene). Pre-mixed in SLB tanks. · 800 bbls 3% KCL FIW o Friction Reducer (Supplied by service co.) o 8,000 lbs KCL (1,000 lbs /100 bbl FIW for 3%) (provided by MI) · 3000 c-scfNitrogen · 1,000 1bs Soda Ash (provided by MI) · 60 bbl Flow-Visc gel (3 Iblbb1 Flo-Visc + 1 ga1l20 bb1 Greencide provided by MI) Equipment Required: · 1-1/2" CTU. Install pressure gauges on CT, CT annulus and tbg annulus. · Jet Blaster scale removal too1- 1-11/16" OD. · Five 2000 gal lined acid tanks (provided by SLB) · 250 bbls Flowback tank o Tie mud pump into tank to pump returns to A44-11 disposal well. o Install 2" line for gas to production header and 2" vent line for N2 returns. · Send all non-N2 gas to production header · Send all N2 to vent line o Have H2S monitor at the flowback tank · Return line from well w/ choke manifold to 250 bbl flowback tank o Manifold to contain sample catcher to monitor fluid pH PROCEDURE: 1. SD gas lift. 2. MIRU Schlumberger 1.50" CTU. RU BOP's and test to 5,000 psi. Max press is 5,000 psi on CT. CTU operator to ensure all tools are calipered before Rill. Smallest ID = 1.791" @ XN Nipple @ 8,350'. XTO Energy Inc. MGS A43-11LW 7-24-07 . . 3 3. RU steam lines to pit to heat FIW to +1_100° F before pumping downole. 4. Hold safety meeting with all service & production personnel about the procedure, corrosive chemicals, and possible H2S exposure. CLEAN OUT HOLE: 5. With the CT annulus open, RIH wi Jet Blaster tool @ +1- 40 fpm max while pumping @ +1- 1 BPM slick 3% KCL FIW. Send all returns to flowback tank and then to disposal well. Slow the CT rate to 10-20 fpm across GLM's and in the 3-112" slotted liner from 8,650 - 10,098'. Be cautious and do frequent weight checks once inside 3- 1/2" slotted liner. Slickline tagged and was temporarily stuck at 8,772' on 6-29-07. At TD, circ hole clean wi 20 bbl Flo-Visc pill followed by 50 bbls slick 3% KCL FIW @ max pump rate below 5,000 psi. Be prepared to use acid if can not make progress into the hole. Use acid only when necessary. ACID SPOT & SOAK: 6. With the CT annulus open & Jet Blaster tool starting @ 10,098', lay 550 gal (13 bbl) 10% HCL from 10,098' to 8,650' while pulling up hole using slick 3% KCL FIW to displace. PU CT to 8,300' and SD (continue to circ FIW at min rate). Let acid soak for 1-2 hr. Load PTS tank with 1000 lbs soda ash. 7. Start up and, keeping the CT annulus open, run the CT down through the acid while circ slick 3% KCL FIW @ max pump rate. Proceed to 10,098'. Circ hole clean wi 20 bbl Flo-Visc pill followed by 50 bbls slick 3% KCL FIW. ACID WASH PERF'S: 8. Once hole is clean, keep the CT annulus open and begin to acid wash slotted liner wi 2,000 gal (48 bbl) 10% HCL @ pump rate to be determined by SLB engineer for maximum effectiveness of JetBlaster tool. Move wash tool at rate that will allow 1 pass up and 1 down, covering slotted liner from 10,098' - 8,650'. 9. With the Jet Blaster tool @ 10,098', circ hole clean wi 20 bbl Flo-Visc pill followed by 50 bbls slick 3% KCL FIW @ max pump rate. ACID INJECTION JOB: 10. Keeping the CT annulus closed, inject 6,000 gal (143 bbl) 10% HCL acid into the perfs while making passes across the interval from 10,098-8,650' while pumping @ 0.5-1 BPM and moving the wash tool @ 15 - 20 ft/min. Adjust rate as necessary for maximum performance of JetBlaster tool. 11. Finish pumping all acid @ 10,098'. Over-displace acid by injecting 100 bb13% KCL FIW (no friction reducer) into the formation while making passes @ +1-20 ft/min. 12. Open the CT annulus. PU coil tbg to fluid level (+/-1,500' wi BHP = 2,700 psi). Cool down the Nitrogen pump. Begin to jet well with N2 @ +1- 250 scflmin while RIH @ 40 ftlmin, taking returns to the flowback tank. (Objective is to recover load of spent acid +1- 150 bbl). SD N2 after acid load is recovered. Unload the surface tank to the disposal well and vent gas during jetting with N2. SCALE INHffiITOR SOZ: 13. Once an effort has been made to recover most ofthe acid load, RIH wi CT to 8,650' while circ 3% KCL FIW @ 12 BPM. Close the CT annulus. From 8,650' to 10,098', pump 48 bbl Scale Inhibitor (Nalco EC6085A) chemical (200 gal EC6085A + 43 bb13% KCL FIW) @ 0.75 BPM while moving @ 20 ft/min. Overflush the scale inhibitor wi 120 bb13% KCL FIW (no friction reducer) while making passes across slotted liner. 14. POOH wi CT. RD CT unit. 15. Leave well SI for +1- 24 hrs for scale inhibitor to work. . XTO Energy Inc. MGS A43-11LW 7-24-07 . . 4 16. RU flowback tank to well and production header. Start up gas lift and RWTP. Produce into PTS tank for +/_ 2 days and send fluids to disposal well to make sure acid/xylene load has been fully recovered before putting fluids from well into production header. RÆ~L Jet! asch Production Engineer Paul Figel Engineering Manager ;: . . ;[!~ MGS A43-11 LW Cook Inlet, Alaska Leg 1, Conductor 3 API No.: 50-733-10082 Spud: Sidetrack: 24" Conductor Csg @ 400' Surf Csg: 13 3/8", 54.5 Ib, J55. Set @ 1609'. Cmt'd wI 1925 sx. Production Csg: 7", 29 lb., N80. Window @ 6772' for sidetrack. (Original Set @ 8798'.) Cmt'd wI 1500 sx. Drilling Liner: 5", 18Ib., P110 FL4S. Set @ 8731'. TaL @ 6392'. Prod Liner: 3.5", 9.3 Ib, N80 BTC slotted liner set@ 10098'. TaL @ 8650'. TD~MD IPlo!> /Hi> rv ~.¡..¡.; ~~~ .,.'51...1 Current Completion 1 I I I I I L_I PLF 7-26-04 KB: 38' Water Depth: 73' Tbg: 2-7/8" 6.5# N80 8rd EUE @ 6318' 2- 3/8" 4.7# L80/N80 8rd EUE @ 6318'-8383' Baker "FV-6" TRSCSSV w/2.313" "X" @ 325' GLM MO TVO Port ptro Psc Pso 1 1921' 1900' 12 925 892 950 2 3356' 3356' 12 910 871 919 3 4508' 4507' 12 895 850 887 4 5406' 5404' 16 950 827 881 5 6116' 6113' 16 935 807 845 6 6624' 6619' 16 920 788 826 7 7136' 7116' 16 905 767 805 8 7681' 7608' 20 985 735 798 9 8226' 8110' 3/16" Orifice X-over from 2 7/8" to 2 3/8" tbg @ 6318' (5 - 2 7/8" O-SO, 4 - 23/8" U-SO GLMs) 1 Jt. 2 3/8" tbg Otis "X" Nipple @ 8272' (1.875" 10) 1 Jt. 2 3/8" tbg Baker "FH" packer @ 8305' wI 30K# shear 1 Jt 2 3/8" tbg Otis "XN" Profile Nipple @ 8350' (1.791" 10) 1 Jt 2 3/8" tbg Baker Wireline re-entry guide @ 8383' ON OR BEFORE . C:LOR_I'~I:FILM-DOC 95 .... 05(} 95---050 95 ..... 050 95--050 Geolog-¥cal Mat. er"'ia'Js Inven'kor'.'!/ DATA T DATA.~P L U S p ::, I-.I C / S L - .,,..~. 6786-8710 RESISTIVITY ,.._k:" 8732 --. i 0076 · . · ~ 8750'-. i0 i08 . 6 7 5 2 ~i R T ---. J /,S R NO--.T?E P T H S ,S i'll V E I',.! 8 7 5 3 ~., 'B, I !... / B H C /,3 R / A H S P~sSFuT. H,S-. · 6 1 V ,q i0 ...... ~,07 ~R' COMP!...~TIC, N DATE 61'R5/%'~/' · . . [) ,::.~ '11 e: () 3/' i !.:] / 9 '? [-~ I..I j'q I') A i' [!.. ..... [..:: [!{ C V D ~ [.) 6 /3 (') / 9 5 i [) 6 ,/2, ()/' 9 I 06/' 3 ('J/' 9 5 '1 ri / ~'" rt ~:. "9 .. ....., /' .. 06 /3.0/' !35 0 [:J/" 3 ()//95 i 06 / 3 [J/9 5 /I /0~/'"~1~.~''' DAIL¥ WELL OPS ~ ~'7 I/ / ?j~/' TC: ~/"~,] /"t,~"/' /I /"~/"cFi-/ Ar'e (:ir'y W a s -t; h e Ar'e we1 i We 'i '1 '¥ s ,C "Jlq M E N T S Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. Box 576 Houston, TX 77001 October 30, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, AK 99501-3192 SUBJECT: SUBMITTAL OF WELL COMPLETION REPORT (FORM 10-407) for MIDDLE GROUND SHOAL A43-11LW REFERENCE: APPROVAL NUMBERS 95-50 Enclosed are duplicate copies of the Well Completion Report (Form 10-407) for Middle Ground Shoal A43-11LW. Redrilling operations were completed 6/23/95, the date of first production was 6/23/95, and the representative well test date was 7/01/95. If you have any questions or wish to discuss, please call Marcus Winder at 713/544- 3797 or Jeff Wahleithner at 713/544-3344. Sincerely, .,~'G. S. Nady, Manager /7~ ~ Asset Administration - Western Asset Continental Division Enclosures .~. , ~.. ~ v )~- ~ I~0V 08 1995 Gas Cons. C0mmi~si~r~ ~chorage WCPAOGCC.DOC- I NOV 08 1995 ~a$_tf~ U!! .& Gas Cons. C0mnlissip~ ...... STATE.OF ALASKA ,SKA OIL AND GAS CONSERVATION C(_ IISSION WELL coMp'LETION OR RECOMPLETION REPORT AND LOG .. Status of Well Classification of Service Well 2. Name of Operator ' ,:~lll~--~.! Z Permit ~u~b~-r": · -- Shel 1 Western E&P Inc. ~,:~ , , x . 95-50 P.O. Box 576, Houston, TX 77001-0576 5o- 733-10082-01 -,~x'-';i,/ 4. Location of well at surfaoe _ '. i~'~ " [ - ,;'n': ,' ..... ~.~,., . 9;' Unit ~ Lease N~me PLATF A, LEG 1, C0ND 3, 1628' FSL & 430' FEL Sll, T8N,.iR[3~i~"-!~!~'~I[!'~I,. ~ ' '~" ~ MIDDLE: GROU[qD SHOAL At Top Prcx:lucing Interval~ ~~_~i ' ~'a'/~: '*' ' 1'O. Well Number [a 10.108' MD-KB: 2340' FSL & 1802' FEL Sll, T8N, R13W, Si ::'" 11. Field and Poc~ 5. Elevation in feet (indicate KJ], DF, etc.) ~ 6. Lease Designation and ,?~rial No. HGS "G" POOL 116' KBI ADL 18754 12_ Date Spu<3k~=~d 13. Date T.D. Reached 14. Date Cornp., Susp. or At:~3nd J 15. Water Depth, if offshoreJ 16. No. of C~3mpletions 5-16-95 6-17-95 6-23-95I 80 ~eetUskjl SINGLE 10,108'MD;.. 9801' TVa - . . YES [] NOI--II i' 340 feetMD ~ Type Eleotric or Other Logs Run I)TTF/RH£/RR/AM.q. ~RT-,1/GR 23. CASING, LINER ,auND CEMENI'ING RECORD SE1-TING DEPTH MD CASING SIZE WT. PER Il'. GP, ADE TOP B(:)l-roiVl i-K)i_E SIZE CEMENI'ING RECORD AMOUNrl- PULLED 5" 18# N80 6400' 8729' 6" 415 SX - - - 3-1/2" 9, ~ N80 8650' 10,098' 4-1/8" SL01-rED LNR 24. Perforations ol:,gn to Prcx:luction (MD + TVD of Top and E~3ttorn and 25. TUBING RECORD interval, size and number) SIZE DEPTH SEI' (MD) PACKJ~R SET (MD) 2- 7/8" 8383' 8319' N/A - SL01-FED LNR FROM 5" LNR SHOE TO TD 26. ACID, FRACTUP, E, CEMENI' SQUEEZE, ETC. DEPTH INTERVAL (MD) ,~uMOUNT & KJND Oi: MATERIAl_ USED DUPLICATE .,,, ~1. PROI)LIOTION TEST Date First Production J Method of Operation (Flowing, gas lift etc.) F;-73-9.5I C-,A~ I ]'FT Date of Test Hours Tested PRODUCTION FOR OIL-BB~_ GAS-MCF WATER-BBL CHOKE SIZE ~ GAs-OIL RAT~ 7- 01-95 24 TEST PERIOO ~81 126 I 128I 331 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL. OiL GRAVITY-APl (corr) Press. 100 550 24-HOUR RATE 34.7 28, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil. gas or water. Submit core chips. NONE NOV 08 1995 _Al~sl~ 0il & Gas Cons, Commission Annhnr~n~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate - 49 - , . GEOLOGI£~,,~j_ ~KERS FORMATION TESTS Inolude interval tested, pressure data, all fluids reoovered and graVi NAME MI~AS. DEPTH TRUE VERT. DEPTH and time of each phase. SEE ATTACHED GEOLOGIC MARKER SUMMARY 31. LIST OF ATTACHMENTS MORNING REPORTS, DIRECTIONAL SURVEY, GEOLOGIC MARYJ~R SUMMARY 32. I hereby certify t~at the foregoing ~s true and correct to the.best of my knowledge Signed (~_~f.~.Z~,~ G.S. NADY Titk~ MGR. - ASSET ADMIN. Date 10/30/95 7 C INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is Used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attaChments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item '27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB. etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Fo~m 10-407 June 26, 1995 Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. Box 576 Houston. TX 77001 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: FORMATION TOPS PICKS FOR THE SWEPI MGS A-43-I 1LW, MIDDLE GROUND SHOAL FIELD, KENAI BOROUGH, ALASKA Here is a list of formation tops encountered in the SWEPI MGS A43-11LW (APl# 50-733-10082-01), as required by the AOGCC. Please note that this well was drilled through the overturned limb of the Middle Ground Shoal anticline, so the second set of Hemlock formation tops were encountered in reverse order. A43-11LW (KB = 116') Approximate Formation Top MD TVD Subsea GB 6,872' 6,865' GD 7,010' 6,998 GN 7,240' 7,212' GO 7,268' 7,237' GR 7,560' 7,499' GS 7,610' 7,545' HC 7,822' 7,739' HD 7,890' 7,801' HE 7,950' 7,856' HI: 7,980' 7,884' H/ 8,041' 7,940' I-tX 8,090' 7,985' HN 8,216' 8,100' HR 8,361' 8,233' Fault 8,380' 8,25 I' ItR (repeated) 8,483' 8,346' -6,749' 45,882' -7,096' -7,121' -7,383' -7,429' -7,623 -7,685 -7,740 -7,768 -7,824 -7,869 -7,984 -8,117' -8,135' -8,230' HR (overturned) 9,300' 9,099' -8,983' HN 9,510' 9,285' -9,169' HK 9,733' 9,480' -9,364' HI 9,799' 9,537' -9,421' HF 9,876' 9,603' -9,487' HE 9,932' 9,651' -9,535' HD 9,972' 9,684' -9,568' HC ' 10,048' 9,749' -9,633' TD 10,108' 9,799' -9,683' If you have any questions, I can be reached at (713) 544-2389. Very tmly yours, Maria A. Balzarim Semor Petrophysicat-E~ Anadrill Schlumberger Clien. t ~.,, ~.~ .:. SHBI-,- L .WESTERN-~-~ &. P ~ INC.. Field ..... : MIDDLE GROUND SHOAL Well ...... : A43-11LW Section at: 290.00 Engineer.,: Mike Teel Unit s ..... : FEET 07/12/95' ......................... Computation-; .... :.-MINiMUm'CURVATURE'-: ...... Survey Date,,.: 07/12/95 KB Elevation.,: 116,00 ft Reference ..... : Magnetic Dcln.: 22.636 E (Calculated from a tie-in station at 6769 MD) S MEAS INCLN DIRECTION C DEPTH ANGLE AZIMUTK N. 6.769 5,40 277.33 3 6915 14.30 312,40 3 6950 15,70 312.40 3 6980 16.10 310,30 3 7010 17.00 308.90 ........... RECORD OF SURVEY ........................................................... Pg' ~:' VERTICAL-DEPTHS ·SECTION RELATIVE-COORDINATES CLOSURE BKB SUB-SF~ DISTNCE FROM-WELL-HF_J~ DISTNCE AZIi~JTH 6763,3 6647.3 194.7 81.,5. N 177,.5 W 195.3 294,66 6907.1 6791.1 218,1 94,6 N 197.7 W 219,1 295,57 6940,9 6824,9 226.5 100,7 N 204.4 W 227.8 296.23 6969.7 6853.7 234.1 106,1 N 210,5 W 235.8 296,75 6998.5 6882,5 242.2 111.6 N 217,1 W 244.1 297.19 /lOO 1 ..67. 7.08 4.00 2.34 3.28 3 7042 18.90 304.70 3 7072 20,20 302.50 3 7102 21,50 300.80 3 7132 22.50 299.00 .3 7162 ·23,60· 296.20. .. 3 7192 24.50 294,10 3 7252 25.~80. 2.91.30· 3 7297 26.40 291.30 .3 7.3.4.2 2518© 290.60 .3 7374 2·6.80 291·,50 3 7404 27.10 291.30 . . 3 7.491 26.20. 2·92'.70· 3 7593 24.30 290,60 3 7662 23.30 291,10 1 8402 22.75 294.13 7028,9 6912.9 251,6 117.4 N 225.0 W 253,8 297.56 7057,2 6941.2 261.4 123,0 N 233.4 W 263,8 297.79 7085,2 6969.2 271,8 128,6 N 242,5 W 274.5 297.94 7113.1 6997.1 282.9 134.2 N 252.2 W 285.7 298.01 -7140 . 7 . 7024 . 7 294 · 6. i39.6 N . 262 . 6. W ·297 . 4 298 . 00 · . ..... 7168.1 7052.1 306.7 144.8 N 273,7 W 309.7 297.88 7·222.4. 7106.4. 332..2 .. 154.6 N 2-97.2 .W. 335,0 · · 297.49 7262.8 7146.8 352.0 161.8·· N. 315.7 .W 354..?, .2.97., 14 73·03,2 7187.2 3~1'.8 i'68',9 N 334.2 W 374,4 296.82 7331..9 7215...9 38.6.0 ,174.0. N 347,4 W 388.5 · · 2.96..60 .. 7358.6 7242.6 399.5 178~9 N 360.1 W 402.1 296.42 7436,4 7320,4. .438.5 193.5 .N 396,2 W 441,0 296.03 7528.6 7412.6 482,0 209,6 N 436.7 W 484,4~ 295,64 .. . 7591.8 7~75,8 509.9 219.5 N 462.7 W · 512,1 ,295,38 8272.8 8156.8 798,9 330.7 N 729.8 W 801.3 294.38 ^Station Types~ 1/SINGLE SHOT 3/MWD N/INTERPOLATED ***Grid and:~ma,gne~ic" cor~e.ctions--~.haue.-been-~applie~-.-.~o-gh~s~su~r~V~ys*.*-*~-.-~---' ''--' 7,18 4.98 4.78 4.02 5.18 4.14 2'.94' 1.3,3 1.50 3.2-7 1,00 1,26 2.06 1.48 0',18 "-(~n'~t~:'i! '(c')'S5 'A-43iJ. L~5 s;t. 52' i [':'1'2"A'{4" 'f)' ' A43-11LW MEAS DEPTH 8736 8844 8860 3 3 3 Page 2 07/12/95 ................................ RECORD. OF SURVEY ...................................... ....................................... {~a% eu&-a.~ed.--f-rom-.a---t-ie-.in:.-.s-ta~on--.a~ .... 6769-.MD) ................................................................... . . INCLN DIRECTION VERTICAL-DEPTHS SECTION RELATIVE-COORDINATES CLOSURE DL ~NGLE AZII~TH BKB SUB-SF, A DISTNCE FROM-WELL-HE3d3 DISTNCE AZIMUTK /100 21.80 299.70 8581,9 8465.9 924.5 387,8 N 842.6 W 927.6 294.71 0.69 20.00 304.70 8682.8 8566.8 962.1 408.3 N 875.3 W 965.8 295.01 2.35 t'9';10 .... 3'15';'2'0 ...... 869'7-;"9 .... 8582;9 ............ 967';"1 ............ 4't1'-'7'"'N .........8'79"'4"-W .......... 971'0 ............... 2'95':'0922'.'68"' 8880 17 20 321 50 8716 9 8600 9 972 6 416 3 N 883 5 W 976 7 295 23 13 65 8~2.8 ..... 14.70 .322..9.0 8763.1 86.47,1. 983.8 42..6...8 N 8.91.6 W. 988-.5 295.58 $.,.2~.: 9000 21.00 309,60 8831.6 8715.6 1003.6 442,3 N 907.1 W 1009.1 295,99 10,37 9066 25.30 299.70 8892.3 8776.3 1028.7 456.8 N 928.~ W 1034.7 296.20 8.77 9102 27,00 .290,6.0. .8924.6 8.80.8.6 104~,5 4.63..5 N 94.2,8 W 105.0.6 296.18 12.09 9156 28.20 286.40 89.72.5 8856.5 1069.5 471.4 N 966.5 W 1075.3 296.00 4.23 9198 27.50 287.80 9009.6 8893.6 1089.0 477.2 N 985.3 W 1094.7 295.84 2.28 9248 26,80 289,90 9054,1 8938.1 1111,9 484,6 N 1006,8 W 1117.4 295.70 2.37 9309 27.60 290,70 9108.4 8992,4 1139.7 494.2 N 1033,0 W 1145.1 295,57 1.44 9386 27,70 293,40 9176.6 9060,6 1175.4 507,6 N 1066,1 W 1180.8 295.46 1.63 9457 27.90 298.30 9239.4 9123.4 1208.4 522.1 N 1095.9 W 1213,9 295,47 3.23 9530 28.50 300.40 9303.7 9187.7 1242.4 539.0 N 1125.9 W 1248.3 295.58 1,59 9649 ,2.9,., 3 0 .... 303.. 80, 9743 29 ;50 304.90 9829 30.80 304.70 9903 · 31,,40 304,00: 9999 32,60 306,50 ... .9,4.0.7-,.9. .92.91,.9,. 9489.8 9373.8 9564.2 9448.2 ..9'627.,5 9511.5 9708.9 9592.9 ..1-298,6 .... 5.69... 6-N... 1343.3 595.6 N 1212,7 W 1351,1 1385.1 62'0,2 N 1248,2 W 1393.8 1'422..1 64I:'8 N - 1279 ,.'8.W. 't'431.'7" 1471.2 671.2 N 1321.3 W 1482.0 · .. 295...87 1.5'4 296'.16 0.61 296.42 1.52 ~ ~ ~9 6 ~ 63. 0.95 2.96.. 93 1,8.6. ~ 10108 32.,60 306.50, .9800.8 9684.8 1527,5 70.6.1 N 1368.5 W 'Station Types: 3/MWD N/INTERPOLATED ~**Grid,and.magnetic corrections have been applied, to these ,surveys*** 1539.9 297.29 0.00 knadrll (c)95 A43£LLWD Bk.$2 lt:12 AM 2) ' SWEPI pJ_JkSKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 10040 9 MIDDLE GROUND SHOAL PRESENT DEPTH L~SE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LJ~ST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 764 LAST BOP TEST 05/11/95 LAST CSG TEST os/11/gs DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: RIGGING UP /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : RIG ACCEPTED ON A43-11LW 12:00 P.M. 5/10/95. 18.00 REMOVE ~ SECURE ALL RIG ASSOCIATED EQUIPMENT IN PREPARATION FOR RIG PLATFORM MOVE. SKID RIG OVER PLATFORM #1 WHILE CLEARING DECK AHEAD OF IT. ALIGNED RIG OVER A43-11LW AND RIGGED UP ALL DRILLING EQUIPMENT IN PREPARATION FOR WgRKOVER/DRILLING. PREP. TO BEGIN OPERATIONS. DURING RIG MOVE SLICKLINE UNIT RIH AND PULLED GLM #6. CIRCULATED HOLE WITH FIW IN ATTEMPT TO KILL WELL. TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMF_~NT ING PICKUP/LAY DOWN DS INSPECT BILk RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 18.00 SWEP. A. SKA DAILY DRILLING REPORT RIG NAME PLATFORM "A" PROG. DEPTH 10040 ) MIDDLE GROUND SHOAL PRESENT DEPTH L~,~,~sE · PLATFORM WA" FOOTAGE DRILLED WELL A43-11LW SIZE OF I2tST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /GALLOWAY DR PRESENT ACTIVITY: RIGGING UP ON PLATFORM PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DaY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 765 LAST BOP TEST LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) 24.00 PREPARED FOR BOAT CALLOUT. UNLOADED BOAT AND TOOK ON DIESEL FUEL DURING DAY. COMPLETED RIG SKID OVER LEG #1 ON PLATFORM. WELD BEAMS BACK ON PIPE RACK. SET MI/D LINES AND CLEAN PITS. R/U ELECTRICAL CABLES IN TRAYS TO RIG AND OTHER ASSOCIATED ELECTRICAL EQUIPMENT. INSTALL FRESH WATER LINE TO RIG. M/U STEAM LINES. HANG 10" FLOWLINE F~/glFOLD BETNFEEN RIG AND MI/D PUMPS. NANG LINES FOR CHOKE FLOWLINES AND WATER RETURN LINE. PREP TO HANG MANIFOLDS. CLEAN FLOWLINE TO SHAKERS. CONT. RIG UP PROCESS. NOTE: TO AIT ~-7~BERS~ IT'S TIME TO INVOICE FOR HS&E SAFETY BONUS FOR A24-01LE. ANOTHER GOOD, SAFE, JOB GUYS!!! 05/12/9~ 1 TIME (HRS) C73M. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAI RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 24.00 SWEPI AL/tSKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG N~ME pLATFoRM "Aw PROG. DEPTH 10040 ELEVAT. KB TO MSL · D MIDDLE GROUND SHOAL PRESENT DEPTH DIST. KB TO BHF ~ _~E PLATFORM 'A" FOOTAGE DRILLED' NLTA LTH/YTD WELL A43-11LW SIZE OF LAST CSG 5.000 LTA LTH/YTD WORK ORDER 728520 DEP. OF LAST CSG 8735 DAYS SINCE LAST LTA SIDE TRACK WATER DEPTH 80 LAST BOP TEST 116.0 DATE 38.4 DAY / EST. DAY / DAYS +/- 766 LAST CSG TEST 05/13/95 2 DRILLING FOREMA=N: WELLS R V PRESENT ACTIVITY: RIGGING UP /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 COMPLETE CONSTRUCTION OF CHOKE MANIFOLD. INSTALL ALL SAFETY BOOMERS ON FLOW'LINES. FABRICATE NEW 6' WATER RE/73R/g LINE FROM RIG. SET ALL HANDRAILS AND V DOOR. SET SLOP TANK IN WELLHEAD ROOM. M/U VALVES ON MUD CROSS. HAND WATER LINES. FABRICATE A/gD HANG 4" CHOKE LINE TO 6" LINE. HANG BUFFALO FAN IN PITS. PREPARING TO NU BOP AT REPORT TIME. TIME (HRS) Ctg~. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAM I NG SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/W]{ TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING 24.00 PAGE 1 OF 1 SWEPI SKA DAILY DRILLING REPORT xIn NAME. PLATFORM ; ) MIDDLE GROUND SHOAL LEASE PLATFORM WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 10040 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LA..qT CSG 8735 WATER DEPTH 80 /GALLOWAY DR ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 767 LAST BOP TEST 05/14/95 LAST CSG TEST PRESENT ACTIVITY: COMPLETE BOP TEST SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 COMPLETE RIG UP pROCEDURES OVER A43-11LW. 1.00 .50 2.50 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ __ PP2 @ KILL SPEED __ ~ __ HELD PRE-JOB SAFETY MEETING. INSTALLED TWO WAY CHECK IN TBG HANGER. REMOVE SAFETY VALVE AND PRODUCTION CHOKE. M/U LANDING JT TO ND TREE. UNABLE TO WORK TREE LOOSE WITH PULLS UP TO 120,000#. M/U OBSTINATE TREE REMOVAL BHA~ X-OVER~ 1 JT HWDP, FISHING JARS, 1 - 4 3/4 DC, ACCELERATOR, AND 1 JT HWDP. JARRED TWICE ON TREE WITH 11.50 6.00 PULLS OF 85~000 TO 95,000#. TREE CAME FREE ON SECOND JARRING LICK. L/D JARRING EQUIPMENT. HELD PRE-JOB SAFETY MEETING. N/U BOP'S AND RELATED EQUIPMENT. PERFORM SUCCESSFUL BOP TEST. PREPARING TO POH WITH PRODUCTION EQUIPMENT AT REPORT TIME. NOTE: RECOGNITION TO THE AIT TEAM FOR HAVING THE FOP, SIGHT TO ANTICIPATE THE POSSIBLE PROBLEM WITH THE WELLHEAD TREE AND/OR TUBING HANGER AND HAVING THE PROPER EQUIPMENT ON LOCATION AHEAD OF TIME. THIS ACTION SAVED CONSIDER. ABLE TIME AND MONEY. THANKS GUYS ..... TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REJU~ I NG SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/W}{ 11.50 TESTING BOP /WH 6.00 RUNNING CASING CEMENTING PICK-UP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN 2.50 WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 4 . 00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM #A" PROG. DEPTH 10040 9 MIDDLE GROUND SHOAL PRESENT DEPTH LEASE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /GALLOWAY DR PRESENT ACTIVITY: RIH WITH SCRAPPER ASSEMBLY ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 768 LAST BOP TEST 05/14/95 LA.ST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.00 REMOVE BPV. M/U LANDING SUB AND PULL TBG HA/NGER AND LINER SEAL ASSEMBLY FREE. CIRCULATE BOTTOMS UP. POH LAYING DOWN PRODUCTION EQUIPMENT. SET WEAR RING AND M/U MULESHOE ON 18 STDS 2 7/8. RIH WITH 3.5 DRILL PIPE A/qD CEMENT STINGER. TAGGED UP AT 8296'. COULD NOT WCRK DEEPER. ATTEMPTED TO BREAK CIRCULATION AT 8296'. DRILLPIPE WAS PARTIALLY PLUGGED. PULLED UP HOLE TO WORK PLUG FREE. RE-tURNED TO 8296' AND BROKE CIRCIILATION. CIRCULATED BOTTOMS UP. HELD PRE-JOB SAFET~f MEETING. RU HOWCO. BROKE CIRCUI. J%TION AND PUMPED 30 BBLS FRESH WATER AHEAD OF ~. MIXED AND PUMPED 87 SX'S CLASS G CEMENT WITH .25% CFR-3r 1 GPS HA_LAD 344L~ AND .15% HR5. FOLLOWED TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET RE PAI RS FISHING NIP UP/DOWN /BOP/WH CEMENT WITH 10 BBLS FRESH WATER AND 39 BBLS FIW TO PLACE ON SPOT. CEMENT PLUG SHOULD BE IN PLACE FROM 8296-7296'. RD CEMENT LINES. POH WITH 15 STDS DRILLPIPE AND CIRCIYLATE BOTTOMS UP TO CLEAN HOLE. CHECK FLOW AND P0H WITH ASSEMBLY. CUT AND SLIP 100' DRILLING LINE AND SERVICE TOP DRIVE. M/U 6" MILL AND 7" CASING SCRAPPER ASSEMBLY. RIH WITH CASING SCRAPPER AT REPORT TIME. TESTING BOP /WH RUNNING CA.SING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT __ EVALUATION CORING OTHERS 6.50 1.50 3.00 2.00 1.00 2.00 2.00 1.50 1.00 -T0 _ _ 13.50 4.00 3.50 1.00 2.00 "A I I [ SWEPI ALASKA DAILY DRILLZNG REPORT 1 Prog. Depth ~.0~0. ELevat. K~ to MSL Footage Drilled ~LTA LTH/~TD , 116.0 bare 38.~ ii,ii $i~e of Last CS~ ~5.000 LTA LTH/Y~.D /. Dap. of LeSt Csg .,8.7,$$, Days sinc~ Last LTA 769 . · Water Depth 8~ Last 80P ~est 05/I~/95 LaSt': CS~ TeGt ELL~.: R.m~, ,,, .... / B~A Inspection Crum. kot ',Hfs) ~ities (~how hours for each sub-activity) : ~itt ~peed INLET WATER. (PUMPED ALL RETURNS DOWN DISPOSal WELL) IR~ IN CONTROL )OX. I LAY DO~N MIL /SCRAPER i ~UL.E SH'OE ~8 STDS 2 ~8" TUBING BELOU DR~) Rl ON CEMENT 'E~F~?E~T CASING ?~00 PSI ~)0 MINS. J~.so ,LA;Y~JDb~t~]~JBG [5~ JTS:)[ CEi4ENIIN~ STINBER. j RNA~'~M~:JN fl~ FLEX gOLLAR, SURFACE TEST MWD, 0[. TIN AT TIN~.~J(~i~ CH~CKING EACH TOOL JOl~t FOR WEAR-AND HARDB~NO C~DITION WH:I~J, TJ~[~ RE,C. qRDING' THE CONDITION AND JoI~T' LOCATION ......... ! ..... ,' , :' '" ~*/' Y~e~*t I1 ....... ~ ' } Gred I~,~.L-API . ~ ........... $.nd ~ PF ,, ~xc Lime ~ Sa~p dl F6op~JJiN Co~en,t USING I~LET uATER j Vo~ume~: BL~)}}J iAct.Jve Vo't. Lost (Z~ hfs) )uitt ' '; ~i,,. j.' Or~Lt.ing~ T; , · Hook L ad , Data ~ R~"; ~ :' ' -- -- ,] ..... j~ , : ~ Drag Oown : Bit We sbt O, : 0 Nip up/houri /Bop/ Testing. gOP"/WH Runninni casinq Pickup/Lay .ODin Inspect' BHA Rig up/TeaK Down Wa~t on' we&t~er/a ~ve[~a~!ion Coring. Others MHd AHHiP~nn~ I I' · .. , .. I I I I J 1 cum. Ro;t.: 'H:r~ lantat ~ n'P Mud MotOr Tr{pp{.n~ C&C ~ Reaming; · surveys Jet · R upu i r~. Fishing; m'm m, .. 13.5,O 1 .~0 .. .. .9.50 I .OO a't L-- ', O. O0 ; . · Sulfide ,, OWR j-'"'"HydrauLia t AY/tV J Liner t s:rok~: lops'" , ./,' .. TOTRL P. 01 SWEPi DAILY DRILLING REPORT PAGE 1 OF 1 RIc-NAME PLATFORM - ! MIDDLE GROUND SHOAL LEASE PLATFORM 'A" WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLIN~ FOREMAN: WELLS R V / PRESENT ACTIVITY: RUNNING IN HOLE W/6' WHIPSTOCK PROG. DEPTH 10040 PRESENT DEPTH 6797 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 05/16/9~ DIST. KB TO BHF 38.4 DAY 5 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS 4/- DAYS SINCE LAST LTA 769 LAST BOP TEST 05/14/95 LAST CSG TEST 05/15/95 .50 REPAIR IRON ROUGHNECK, BROKEN ELECTRICAL WIRE IN CONTROL BOX. 2.00 3.00 FINISHED POH W/SCRAPER ASSMY. LAY DOWN MILL/SCRAPER, MAKE UP 2 7/8" MI~E SHOE, TIH W/18 S/DS 2 7/8' TUBING BELOW DRILLPIPEo TAGGGED TOP OF HARD CEMENT AT 7437'. (SET 10K WEIGHT ON CEMENT) 1.00 MAKE UP TOP DRIVE, CLOSED PIPE RAMS. TEST CASING T/2300 PSI F/30 MINS. HELD OK. 1.S0 POH W/DRILL PIPE T/TBG X-O. 1.50 LAYED DOWN TBG (54 JTS) CEMENTING STINGER. 6.50 RIG UP SWS. RAN BA/fER CIB ON WIRELINE. SET PER CCL AT 6797'. POH/RD. 3.50 MAKE UP WEA~RFORD 6' WHIPSTOCK, ANADRILL ORIENTING SUB, INSTALLED ANADRILL MWD IN NM FLEX COLLAR, SURFACE TEST MWD~ OK. TIH AT REPORT TIME. (WE ARE CHECKING EACH TOOL JOINT FOR WEAR AND HARDBAND CONDITION WI4ILE TIH AND RECORDING THE CONDITION AND JOINT LOCATION IN STRING) NOTE: BAKER CIB IS SET 6' ABOVE A CASING COUPLING LOCATED BY THE CCL. _ . (COUPLING IS AT 6803') 1.00 CIRC HOLE CLEAN W/INLET WATER. (PUMPED ALL RETURNS DOWN DISPOSAL WELL) 1.50 POH W/SCRAPER ASSMY. TIME (HRS) CI/M. ROT. HRS ROTATING MUD MOTOR TRIPPING 13.50 C & C 1.00 REAMING SURVEYS JET REPAIRS .5O FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 1.00 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 1.50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 6.50 SUMPS~RY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 FINISHED TIH W/CASING S~ER ASSMY T/7100', TOP OF 5' LINER. B~A INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ PP2 ~ KILL SPEED ~ SWEP ~ugKA DAILY DRILLING REPORT PAGE 1 OF 1 ~Tc NAME PLATFORM "A" PROG. DEPTH 10040 D MIDDLE GROUND SHOAL PRESENT DEPTH 6799 LEASE PLATFORM "A" FOOTAGE DRILLED 2 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: TRIP IN HOLE W/ELONGATION MILL ELEVAT. KB TO MSL 116.0 DATE 05/17/95 DIST. KB TO BHF 38.4 DAY 6 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 770 LAST BOP TEST 05/14/95 LAST CSG TEST 05/15/95 Bm~ INSPECTION (C~. ROT HRS) PP1 ~ KILL SPEED 175 ~ 30 PP2 ~ KILL SPEED 420 ~ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 FINISHED TIH W/WHIPSTOCK; CHECKING TOOL JOINT CONDITION. .50 BREAK CIRC, ORIENT WHIPSTOCK/STARTER MILL ASSMY T/282 DEG MAG. 4 DEG'S HI-SIDE RIGHT. 1.50 MILL W/STARTER MILL F/6772' T/6774'. 2.50 POH W/STARTER MILL ASSMY. LAY DOWN MILL, MWD, NM FLEX COLLAR, OS SUB. 2.00 8.50 MAKE UP AND TIH W/WINDOW MILL ASSMY T/6772'. MILL F/6772' T/6789', (TOP & BOTTOM OF WINDOW) THEN DRILLED T/6799', 10 FEET OF OPEN HOLE. 4.50 POH W/WINDOW MILL ASSMY, LAYED DOWN 70 JTS OF DRILL PIPE THAT NEEDS HARDBANDING. 2.50 LAY DOWN WINDOW MILL ASSMY, MAKE UP WATERMELON MILL (ELONGATION ASSMY) AND TIH AT REPORT TIME CHECKING THE REST OF THE DRILL PIPE IN THE DERRICK FOR WF_JLR. TIME (HRS) CUM. ROT. HRS 10.00 ROTATING 10.00 MUD MOTOR TRIPPING 11.50 C & C REAMING SURVEYS .50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 2.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RTc NAME PLATFORM "A" PROG. DEPTH 10040 D MIDDLE GROUND SHOAL PRESENT DEPTH 6806 LEASE PLATFORM "A" FOOTAGE DRILLED 7 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: MOTOR DRILLING AT 6806' SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 FINISHED TIH W/MILL ASSMY #3 INSPECTING DP CONDITION. 1.00 ELONGATE WINDOW. ELEVAT. KB TO MSL 116.0 DATE 05/18/95 DIST. KB TO BHF 38.4 DAY 7 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 771 LAST BOP TEST 05/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 30 4.00 CLEAN PITS, PREP F/CHANGE OVER TO OIL BASED MUD. PP2 ~ KILL SPEED ~ 50 4.00 BUILD PRE-MIX, DISPLACE INLET WATER W/OIL MUD, CIRC/COND F/MOTOR ASSMY 11.00 POH. LAY DOWN MILLING ASSMY. MAKEUP MOTOR ASSMY AND STAND BACK IN DERRICK. PICKED UP 70 JTS 3 1/2" REBUILT DRILL PIPE, FLUSHED IT OUT. SLM OUT W/DP. TIH W/MOTOR ASSMY, SURFACE TEST MWD, OK. TIH, FILL PIPE AT 3670 ~ AT THE WINDOW. 1.00 ORIENT W/M'WD. TIME (HRS) 12.50 1.50 GETTING STARTED DRILLING W/BIT #1. 6799' T/6806 AT REPORT TIME. CUM. ROT. HRS ROTATING 1.00 MUD MOTOR 1.50 TRIPPING 9.50 C & C 4.00 REAMING SURVEYS 1.00 JET RE PA I RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 3.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON COR I NG ASKA DAILY DRILLING REPORT PAGE 1 OF 1 RT~ NAME PLATFORM "A" PROG. DEPTH 10040 3 MIDDLE GROUND SHOAL PRESENT DEPTH 7050 LEASE PLATFORM "A" FOOTAGE DRILLED 244 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FO~: WELLS R V / PRESENT ACTIVITY: ALTERNATLY SLIDE/ROTATE BIT #1 ELEVAT. KB TO MSL 116.0 DATE 05/.19/95 DIST. KB TO BHF 38.4 DAY 8 NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 772 LAST BOP TEST 05/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PPl ~ KILL SPEED 1000 ® 30 PP2 ~ KILL SPEED 1650 ~ 50 S~Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 ALTERNATLY SLIDE ~ ROTARY DRILL F/6806' T/7050' W/BIT #1. TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON 34.50 11.00 11.00 2.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 10040 ) MIDDLE GROUND SHOAL ~ PRESENT DEPTH 7143 L~E PLATFORM "A" FOOTAGE DRILLED 93 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: ALTERNATLY SLIDE/ROTATE BIT #2 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 ROTARY DRILL F/7050' T/7060' W/BIT #1. 4.50 5.00 ELEVAT. KB TO MSL 116.0 DATE 05/20/95 DIST. KB TO BHF 38.4 DAY 9 NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 773 LAST BOP TEST 05/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ® KILL SPEED 1050 ~ 30 PP2 ® KILL SPEED 1700 @ 50 CHECK F/FLOW, NONE. PULLED 3 STDS T/WINDOW, DROP DART, SHEAR OPEN PUMP OUT SUB, PUMP DRY JOB AND POH W/BIT #1. LAYED DOWN 72 JTS OF PIPE TO BE RE-HARDBANDED. (ALREADY HAD 3 LAYED DOWN SO A TOTAL OF 75 F/SHOP.) PICKED UP 30 JTS HWDP AND 45 JTS NEWLY HARDBANDED DP. CIRC THRU IT TO FLUSH CLEAN F/MWD OPERATIONS. POH. 5.00 MAKE UP BIT #2 ON MOTOR ASSMY, TIH (FILL PIPE AT 4500') T/7060; REAM 1.00 7.50 - _ LAST 50'. SURVEY AT 7055', PROBLEMS W/PULSAR JAMMING, SURGED PIPE UNTIL CLEARED. ALTERNATLY SLIDE AND ROTARY DRILL F/7060' T/7143' W/BIT #2. BIT #1 CON-D: 8-7-LT-MH-E-2-JD/ER-HR/PR TIME (HRS) CUM. ROT. HRS 43.00 ROTAT I NG 1 . 50 MUD MOTOR 7.00 TRIPPING 8 . 00 C & C REAMING .50 SURVEYS 1.00 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS 6.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING SWEP~ XSKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME- PLATFORM "A" PROG. DEPTH 10040 ) MIDDLE GROUND SHOAL PRESENT DEPTH 7422 L~E PLATFORM "A" FOOTAGE DRILLED 279 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: FINISHING UP TESTING BOPE ELEVAT. KB TO MSL 116.0 DATE 05/21/95 DIST. KB TO BHF 38.4 DAY 10 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 774 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1050 @ 30 PP2 @ KILL SPEED 1700 @ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 18.50 ALTERNATLY SLIDE AND ROTARY DRILL F/7143' T/7422' W/BIT #2. 3.00 CHECK F/FLOW, POH T/WINDOW, DROP DART, SHEAR OPEN PUMP OUT SUB, PUMP DRY JOB AND POH W/BIT #2. LAYED DOWN MOTOR. 2.50 DOING WEEKLY BOPE TEST. BIT #2 COND: 5-6-BT-H1/3-E-I-HR TIME (HRS) CUM. ROT. HRS 60.00 ROTAT I NG 10 . 00 MUD MOTOR 7.00 TRIPPING 3.00 C & C REAMING SURVEYS 1.50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /W-H 2.50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL ~ PLATFORM "A" W~ A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: DRLG. W/ BIT #3 PROG. DEPTH 10040 PRESENT DEPTH 7460 FOOTAGE DRILLED 38 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 FINISH TESTING BOP AND INSTALL WEAR BUSHING- 2.00 SERVICE RIG AND CHECK BEARINGS ON BLOCK DOLLY ROLLERS. 1.50 P/U BHA (ROT. DRLG ASSY.) 3.00 RIH, FILL DRILL PIPE, CHECK MWD. .50 WORK THRU 7" WINDOW WITH BHA. .50 RIH BRIDGE AT 6900'. 1.00 WASH AND REAM FROM 6900' TO 7422'. 1.00 ATTEMPT MWD SURVEY. NO SUCCESS. 3.00 POH TO WINDOW CHECK FOR FLOW, PUMP PILL,FINISH POH. 1.50 CHANGE OUT MWD MODULE AND CHECK SAME.( BLOWN FUSE IN OLD ONE). 3.50 RIH W/ BIT #3. 4.00 DRLG F/7422' TO 7460'. _ -- ELEVAT. KB TO MSL 116.0 DATE 05/22/95 DIST. KB TO BHF 38.4 DAY 1__1 NLTA LTH/YTD ~/.__ EST. DAY __ LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 775 LAST BOP TEST ~ LAST CSG TEST 05/15/95. BHA INSPECTION (CUM. ROT MRS) PPl@ KILL SPEED 1050 @ 30 PP2 ® KILL SPEED 1700 @ 50 TIME (HRS) CUM. ROT. HRS 64.00 ROTATING 4.00 MUD MOTOR TRIPPING 10.00 C & C REAMING 1.00 SURVEYS 1.00 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 2.50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT ~ EVALUATION CORING OTHERS 5.50 SWEP? ~SKA DAILY DRILLING REPORT PAGE 1 OF 1 RI~ NAME- PLATFORM [ ) MIDDLE GROUND SHOAL I.%u~E PLATFORM WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: DRLG. W/ BIT # 3 PROG. DEPTH 10040 ELEVAT. KB TO MSL 116.0 DATE 05/23/95 PRESENT DEPTH 7715 DIST. KB TO BHF 38.4 DAY 12 FOOTAGE DRILLED 255 NLTA LTH/YTD / EST. DAY SIZE OF LAST CSG 5.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 8735 DAYS SINCE LAST LTA 776 WATER DEPTH 80 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 / BEA INSPECTION (CUM. ROT HRS) PPl ~ KILL SPEED 1050 ~ 30 PP2 ® KILL SPEED 1700 ® 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 DRIX~. 6" HOLE W/ BIT # 3 F/7460' TO 7715'. TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/W}{ TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 88.00 24.00 SUEPI ALASKA DAILY DRILLING REPORT RIG NAME PLATFORM "A" FT n MIDDLE GROUND SHOAL LL PLATFORM "A" WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: PULLING TO SHOE PROG. DEPTH 10040 PRESENT DEPTH 7917 FOOTAGE DRILLED 202 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / PAGE 1 OF 1 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.00 PUMP PILL - TOOH FOR BHA 3.50 BHA - L/D MUD & MONELS - P/U STEEL (LOCKED) ASSEMBLY 2.50 TIH - FILL PIPE @ 5800' - TIH TO UINDOU .50 SERVICE RIG/TOP DRIVE .50 TIH TO 7637' .50 REAM FROM 7637' TO 7717' 13.00 ROTARY DRLG FROM 7717' TO 7917' · 50 CHECK FLOW - WELL FLOWING APPROX. 8.5 BBL/HR - PULL TO SHOE ELEVAT. KB TO MSL 116.0 DATE 9~Z~/_~ DIST. KB TO BHF 38.4 DAY 13 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- +9.0 DAYS SINCE LAST LTA 777 LAST BOP TEST ~!/95 LAST CSG TEST ~!~/9~ BNA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 520 @ 30 PP2 @ KILL SPEED 1160 @ 50 NOTEi HAD EARTHQUAKE AT APPROX. 0300 HRS - PLATFORM SHOOK MO. RE THAN NORMAL! IADC DULL GRADE BIT #3 - 2-3-ER-A-E-I-CT-BHA NOTEi DOC HAS BEEN PRINTING WRONG CUMMULATIVE COST - WILL ATTEMPT DAI'LY COST = $27z439 CUMM. COST = $345,860 TO CORRECT. T I ME (HRSI ........ CUM. ROT. HRS 101.00 ROTATING 13.00 MUD MOTOR TRIPPING 6.50 C & C REAMING .5O SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/~4H TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 3.50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS .50 SWEp~I_~ALASKA DAILY DRILLING REPORT ~ PAGE 1 OF 1 RIG NAME PLATFORM FIELD - MIDDLE GROUND SHOAL ~E PLATFORM ,,-~L A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: SELTZ R H PROG. ~PTH 10040 PRESENT DEPTH 7917 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / PRESENT ACTIVITY: MIXING LOST CIRC. PILL ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 778 05/25/95 BOP TEST 05/21/95 I.,/~ST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 520 ® 30 PP2 @ KILL SPEED 1160 @ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 MONITOR FLOW - PULL UP INSIDE WINDOW ~ 6772' - SHUT IN WELL & MONITOR PRESSURE BUILD UP - WT. UP PITS TO 13.2 #/GAL - PREPARE TO KILL WELL NOTE; DP PSI BUILT TO 1050 & STABILIZED, CASING PSI WAS BETWEEN 1250 & 1300 PSI - JUST PRIOR TO PUMPING KILL MUD, DP PRESSURE FELL TO 650 PSI & CASING TO 720 PSI - BLEED PRESSURE FROM WELL & PUMP 13.2 MUD THROUGH OPEN CHOKE - NOTE; PUMPED 250 STKS OVER DISPLACEMENT & FAILED ~O GET 13.2 MUD TO SURFACE, HOLE TAKING FLUID - SHUT DOWN PUMPING & MIX 40 BBL 13.2 #/GAL LCM PILL W/40 #/BBL CAL CARB & 20 #/BBL LIQUID CSG - DISPLACED PILL W/ 50 BBL 13.2 #/GAL W/ 8#/BBL CAL CARB & 20 #/BL LIQUID CSG (DISPLACED SO 20 BBL WAS IN ANNLrLUS) - PULL 12 STDS (SLOW) TO 5735' (PULLED DRY) - ATTEMPT TO BREAK CIRC - NO RETURNS - MIX AN- OTHER 59 BBL 13.2 #/GAL LCM PILL W/ 32 #/BBL CAL CARB & 20 #/BBL LIQ. CSG - PUMP 30 BBL OF PILL PILL - WAS ABLE TO GET PARTIAL RETURNS (20- 25%) WHILE ROTATING PIPE & CIRC. - SHUT DOWN PUMP - TIH TO SHOE - FILL PIPE & ANNI/LUS - SHUT IN WELL, PUMP 1 BBL OF LCM PILL EVERY 1/2 HR DOWN DP - PUMPED TOTAL OF 10 BBL - DID NOT SEE ANY PRESSURE INCREASE, WELL HOLDING 100 TO 150 PSI TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAM. INS SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 101.00 24.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM 'A" PROG. DEPTH 10040 '~ MIDDLE GROUND SHOAL PRESENT DEPTH 7917 ~SE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ R H / PRESENT ACTIVITY: WEIGHTING UP PITS ELEVAT. KB TO MSL 116.0 DATE 05/26/95 DIST. KB TO BHF 38.4 DAY 15 NLTA LTH/YTD / EST. DaY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 779 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 520 ~ 30 PP2 ~ KILL SPEED 1160 ~ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 BLEED PRESSURE FROM ANNULUS & DP - FILL INSIDE OF DP W/ 13.0 # MUD - (FLUID DROPPING DOWN PIPE) - LET FLUID SEEK LEVEL, SO AS TO DETERMINE APPROPRIATE MUD WT - FILL PIPE (2 BBLS) - NOTE; ANNULUS STAYING FULL, MONITOR WELL - MIX 50 BBL LCM PILL (84 #/BBL CAL CARB, 8.5 #/BBL LIQ. CSG, 50 #/BBL OM SEAL) - SPOT PILL ~ 6882' - PUMPED 50 BBL LCM PILL, DTSPIJ%CED W/ 40 BBL 13.0 # MUD - PLrkL 14 STDS DP - NOTE; SWABBING WELT, WHILE PULLING BIT & STAB THROUGH PILL, ROTATE PIPE WHILE PULLING EXT- REMELY SLOW - AT 5587', CHANGE SHAKER SCREENS & CIRC - START PUMPING % 1 BBL/MIN & INCREASED TO 2 BBL/MIN - NOTE; STARTED GETTING LCM PILL BACK 300 - 400 STKS PRIOR TO BOTTOMS UP (APPROX 28 BBLS) - FINISH CIRC WELL ~ 5587' - WELL APPEARED STABLE, PREPi~RE TO MAKE 5 STD SHORT TRIP PRIOR TO TOOH FOR BHA - WELL STARTED FLOWING - MONITOR FLOW (3 BBL/HR) - NOTE~ FORMATION WATER WAS FLOWING DIRECTLY UP THROUGH OIL BASE MUD - SHUT WELL IN & MONITOR PRESSURES --WT UP & CONDITION 200 BBL MI/D TO 13.0 #/GAL - PRESSLrRES ~ 0600, 300 PSI ON CSG & 30 PSI DP. NOTE; CHANGED OUT TOP DRIVE SPEED CONTROL CARD WHILE CONDITIONING MUD. NOTE; CIRCI/LATED 3 HRS ~ 5582' & LOST APPROX. 11 BBLS TO FORMATION. (CIRC. ~ 1-2 BBL/MIN) TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAI RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING 101.00 24.00 SWEP1 ~ASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM D MIDDLE GROUND SHOAL Lu.~.SE ' PLATFORM WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: SPOT LCM PILL PROG. DEPTH 10040 PRESENT DEPTH 7917 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 ELEVAT. KB TO MSL 116.0 DATE 05/27/95 DIST. KB TO BHF 38.4 DAY 16 NLTA LTH/YTD / EST. DaY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 780 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 520 ~ 30 PP2 ~ KILL SPEED 1160 ~ 50 FINISH WEIGHTING PITS UP TO 13.0 #/GAL - DISPLACE HOLE TO 5572' W/ 13 #/GAL MUD (RAN OUT OF MUD IN PITS JUST PRIOR TO 13.0 REACHING SUR- FACE) - TRANSFER MUD IN PITS - CLEAN P-7 (DISPOSAL WELL PIT, GOT LCM MATERIAL IN IT) - CONDITION MUD IN PITS TO 13.0 - TIH TO 6692' - CIRC. 13.0 # MUD - NOTE; HAD NO LOSSES UNTIL 13.0 # MUD WAS 550 STKS FROM SURFACE, AT THAT TIME HOLE TOOK 45 BBL - MONITOR STATIC HOLE CONDIT- IONS WITH TRIP TANK - LOSSING 10 BBL/HR - MIX 20 BBL LCM PILL W/ 60 - 80 #/BBL OM SEAL (NOTE; USED 5 DRUMS OF RECOVERED OM SEAL FROM OTHER PILL) - RIH TO 6881' & SPOT PILL - NOTEf PUMPED PILL WHILE PULLING PIPE SO NOT TO SWAB WELL - MONITOR WELL ~ 6214' - NO LOSSES NOTE~ LOST 45 BBLS MUD WHILE SPOTTING PILL. TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C &C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 101.00 24.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FT~T~ MIDDLE GROUND SHOAL E PLATFORM WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: MIXING MUD PROG. DEPTH 10040 PRESENT DEPTH 7917 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / ELEVAT. KB TO MSL 116.0 DATE 05/28/95 DIST. KB TO BHF 38.4 DAY 17 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 781 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 520 ~ 30 PP2 ~ KILL SPEED 1160 ~ 50 S~Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 MONITOR WELL FOR LOSS/GAIN - CONFERENCE CALL W/SWEPI ENGINEERING, M-I ENGINEERING, & RIG IMPLEMENTATION TEAM TO DISCUSS WATER BASE VS OIL BASE MUD FOR WELL, DECIDED TO GO WITH 12.0+ WATERBASE - WELL STARTED FLOWING W/13.0 MUD - CHECKED FLOW, 1.6 BBL/HR - SHUT WELL IN - TRANS- FER OIL BASE MUD OUT OF PITS (RAN ACROSS SHAKERS TO GET LCM OUT) - CLEAN PITS - FILL PITS W/FIW - MIX & CONDITION MUD SHUT IN PRESSURES ~ 0600 HRS - 84 PSI ON DP & 420 PSI CSG SET SPEED (RPM) ON TOP DRIVE SPIN MODE - WORKED ON CURRENT LIMIT SET- TINGS ON TOP DRIVE W/GEN #1-3-5. FOUND BURNT RESISTOR IN TECH POWER BOX (ABOVE DC PANEL) CHANGE OUT DERRICK CLIMBER WT. BUCKET LINE TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH __ TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON 101.00 24.00 SWEP~f~-JkSKA DAILY DRILLING REPORT PAGE 1 OF 1 pTc NAME PLATFORM 'A' PROG. DEPTH 10040 D MIDDLE GROUND SHOAL PRESENT DEPTH 8056 LEASE PLATFORM "A" FOOTAGE DRILLED 139 WELL ~ A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST cSG 8735 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 05/29/95 DIST. KB TO BHF 38.4 DAY 18 NLTA LTH/YTD / EST. DAY . LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 782 LAST BOP TEST 05/21/95 LAST CSG TEST .05/15/95 DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.50 BUILD WATER BASED MUD WHILE MONITOR DRILLPIPE AND CASING PSI. BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED 2.50 RIH FROM 6692 TO 6772. PPG 25 BBLS MIN. OIL SWEEP FOLLOWED BY 12 PPG H20 BASED DRILL MUD. DISPLACED OUT MINERAL OIL MUD WITH THE H20 BASED MUD SYSTEM. 2.50 RIH WITH BHA. HIT BRIDGE AT 7387'. PULLED UP AND INSTALLED TOP DRIVE. REAMED DOWN FROM 7356' TO 7917' - HARD BRIDGE AT 7678'. 9.50. ROTARY DRILL FROM 7917' TO 8013'. 1.00 MADE SHORT TRIP AND CIRCULATED BOTTOMS UP. NO GAS ON B/U. 4.00 RIH AND CONT. ROTARY DRILLING. ROTARY DRILLED FROM 8013' TO 8056' AT REPORT TIME. 700 ~ 28 1200 ~ 40 TIME (HRS) CUM. ROT. HRS 114.50 ROTATING 13.50 MUD MOTOR TRIPPING C&C 3.50 REAMING 2.50 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 4.50 SWEPI AI2~SKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM D MIDDLE GROUND SHOAL L~SE PLATFORM "A" WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING PROG. DEPTH 10040 PRESENT DEPTH 8245 FOOTAGE DRILLED 189 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 /GALLOWAY DR ELEVAT. KB TO MSL 116.0 DATE 05/30/95 DIST. KB TO BHF 38.4 DAY 19 NLTA LTH/YTD / EST. DaY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 783 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 760 ~ 20 PP2 ~ KILL SPEED 1150 ~ 50 S~Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.00 ROTARY DRILLED FROM 8056 - 8090'. 2.00 DROPPED SURVEY AND ALLOWED TO SHOT. MIXED AND PUMPED DRY JOB. 2.50 POH WITH BHA. .50 RETRIEVE SURVEY AND M/U BIT ~5. 3.50 RIH WITH BHA. FILL PIPE AT WINDOW. .50 TAGGED BRIDGE AT 7695. M/U TOP DRIVE AND BROKE CIRCULATION. REAMED/ WASHED OPEN HOLE FROM 7695 - 80'90' (15' FILL ON BOTTOM). 11.00 ROTARY DRILLED FROM 8090' - 8245'. NOTE: RECEIVED VERBAL APPROVAL FROM AOGCC (BLAIR WONDZELL) TO POST- PONE WEEKLY BOP TEST TO AFTER SETTING 5" LINER. NOTE: AFTER DISPLACING HOLE wITH 12.1 H20 MUD THE HOLE WOULD TAKE FLUID WHILE PUMPING AT 40 SPM (13.2 ECD). DECREASE STK/MIN TO 17 AND LOSS STOPPED (12.9 ECD). REDUCED MUD WT. TO 11.8 SO WE COULD DRILL WITH 40 STK/MIN. (THIS PERTAINS TO YESTERDAYS REPORT) TOTAL GAIN/LOSS AA~TER BIT TRIP = +/- 30 BBL. _ _ MUD FROM BOTTOMS UP WAS IN GOOD SHAPE (COUPLE LIGHT SPOTS). TIME (HRS) CUM. ROT. HRS 129.50 ROTATING 15.00 MUD MOTOR TRIPPING 5.00 C & C 1.00 REAMING .50 SURVEYS 2.00 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA .50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON SWEPI SKA DAILY DRILLING REPORT RT- NAME- PLATFORM "A" PROG. DEPTH 10040 ~ , MIDDLE GROUND SHOAL PRESENT DEPTH 8360 LEASE PLATFORM "A" FOOTAGE DRILLED 115 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LdkST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: ROTARY DRILLING SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 ROTARY DRILL FROM 8245 - 8261'. ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 784 PAGE 1 OF 1 os/31/9s 20 LAST BOP TEST 05/2.1/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1% KILL SPEED 650 ~ 15 PP2 ~ KILL SPEED 875 ~ 30 1.00 MAKE SHORT TRIP UP TO 7637' - 2' OF FILL ON RETURN TO BOTTOM. 9.50 ROTARY DRILL FROM 8261 - 8339'. .50 C~IECK FOR FLOW~ DROP SURVEY AND PUMP DRY JOB. 3.00 POH WITH BHA. 2.00 RETRIEVE SURVEY AND LAY DOWN BHA. M/U BIT ~6 AND NM BHA ASSEMBLY. 3.50 RIH WITH NEW BHA. FILL DP AT WINDOW. 1.00 M/U TOP DRIVE. REAMED/WASHED OPEN HOLE FROM 8270' TO 8339'. 17' FILL ON BOTTOM AFTER TRIP. 2.00 ROTARY DRILL FROM 8339' - 8360'. NOTE: GAINED 35 BBLS ON ROUND TRIP. IADC DULL GRADE BIT #5 - 4-7-RG-H,A-E-1/4-BT-TQ NOTE: DROPPED DRIFT SURVEY. TWO SURVEYS DIFFERED. ONE SHOWED 22.00 AND THE OTHER SHOWED 24.00. INCLINATION ANGLE OF 23.00 IS AVERAGE OF THE TWO. _ ~ NOTE TO ALL CONTRACTORS: CONTRACTOR HOURS FOR MAY ARE DUE TO LARRY LITTLE. THANKS ..... TIME (HRS) CUM. ROT. HRS 142.50 ROTATING 13.00 MUD MOTOR TRIPPING 7.50 C & C REAMING 1.00 SURVEYS .50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /hq{ RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 2.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT ~ EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PI~TFORM "A" PROG. DEPTH 10040 D MIDDLE GROUND SHOAL PRESENT DEPTH 8590 L~SE PLATFORM "A" FOOTAGE DRILLED 230 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 06/01/95 DIST. KB TO BHF 38.4 DAY 21 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS DAYS SINCE LAST LTA 785 LAST BOP TEST .05/21/95 LAST CSG TEST 05/15/95 DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 7.00 ROTARY DRILL FROM 8360' TO 8443'. 1.00 CHECK FLOW. DROP RETRIEVABLE SURVEY AND PUMP DRY JOB. 1.00 POH TO WINDOW. 1.00 RIH WITH SLICKLINE AND RETRIEVED SURVEY TOOL. 1.00 RIH WITH BHA. WORKED THRU BRIDGE AT 8240'. 12.00 ROTARY DRILLED FROM 8443' - 8590'. NOTE: WHILE SURVEYING-WELL FLOWED 1.3 BBLS PER HOUR. THANKS TO ALL TEAM MEMBERS WHO TURNED IN THIER CONTRACTOR HOURS. FOR THOSE REMAINING IT WOULD BE APPRECIATED IF YOU COULD GET THEM IN TODAY. THANKS AGAIN ....... BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 @ KILL SPEED 720 ~ 15 950 ~ 30 TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON 162.50 20.00 2.00 2.00 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL I 'E PLATFORM %. A43-11LW SWEPI AI_J~SKA DAILY DRILLING REPORT · · PROG. D.. _~ 10040 PRESENT DEPTH 8750 FOOTAGE DRILLED 160 SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: CIRC AND COND MUD/HOLE SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 ROTARY DRILL FROM 8590' TO 8622'. .50 CHECK FOR FLOW AND PUMP DRY JOB. 4.00 POH WITH BHA. .50 M/U BHA AND BIT #7. 2.00 RIH WITH BHA TO WINDOW AND FILL DP. 1.00 CUT AND SLIP 100' OF DRILL LINE. 1.00 RIH WITH BHA TO 8500'. .50 M/U TOP DRIVE AND WASH/REAM FROM 8500 - 8622'. 10.00 ROTARY DRILL FROM 8622 - 8750'. PAGE 1 OF 1 ELEVAT. KB TO MSL l16.u DATE 06/02/95 DIST. KB TO BHF 38.4 DAY 22 N-LTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 786 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 870 ~ 20 PP2 @ KILL SPEED 1020 ~ 30 1.50 CHECK FOR FLOW AND CIRC. FOR 15 MIN. POH TO WINDOW. HOLE STICKY OFF BOTTOM. · 50 CIRC AND COND MUD/HOLE AT 6760'. IADC BIT GRADE BIT #6 - 5-8-RG-H,A-E-6-BT/TQ TIME (HRS) CUM. ROT. HRS 175.00 ROTATING 12.50 MUD MOTOR TRIPPING 8.50 C & C 1.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH __ TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA 1 . 00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT __ EVALUAT I ON CORING OTHERS 1.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 10040 '~ MIDDLE GROUND SHOAL PRESENT DEPTH 8750 SE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ R H /GALLOWAY DR ELEVAT. KB TO MSL 116.0 DATE 06/03/9~ DIST. KB TO BHF 38.4 DAY 23 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 787 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 PRESENT ACTIVITY: R/U TO RIH WITH CASING SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 FINISH CIRCUI2%TING HOLE CLEAN AND PUMP DRY JOB. 2.00 POH WITH BHA. 2.00 LAY DOWN BHA. 1.50 R/U SWS ELECTRICLINE UNIT. 3.00 RIH WITH SWS AND LOG OPEN HOLE INTERVAL WITH DUAL INDUCTION, SONIC, AND GA~/~J%RAY LOGGING TOOLS. 1.50 R/D SWS AND SERVICE TOP DRIVE. 2.00 M/U CLEANOUT BEA. 3.50 RIH WITH BHA. FILL PIPE AT WINDOW AND CONT. IN HOLE TO 8750'. 3.00 COND AND CIRCULATE MUD WHILE WORKING PIPE SLOWLY. CHECK FLOW AND PUMP DRY JOB. 4.00 POH WITH BHA. DRIFTED 3.5 DRILL PIPE. L/D BHA. 1.00 PREP TO RIH WITH CASING LINER. NOTE: DAILY COSTS INCLUDE $26,000 FOR OPEN HOLE LOGS. IADC DULL GRADE BIT #7 - 3-4-ER-A-E-1/16-TD NOTE: GAINED 65 BBLS ON CLEANOUT TRIP. BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 % KILL SPEED 740 ~ 20 840 ~ 30 TIME (HRS) CUM. ROT. HRS 180.50 ROTATING MUD MOTOR TRIPPING 9.50 C&C 3.5O REAMING SURVEYS JET REPAIRS 1.50 FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 4.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING 5.50 SWEPI AJ_JkSKA DAILY DRILLING REPORT PAGE 1 OF 2 RIG NAME PLATFORM "A" PROG. DEPTH 10040 D MIDDLE GROUND SHOAL PRESENT DEPTH 8750 ~. bE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 06/04/95 DIST. KB TO BHF 38.4 DAY 24 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 788 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 DRILLING FOREMAN: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: CIRCULATING OUT CEMENT STRINGERS SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 CONTINUE PREPARATION TO M/U LINER. BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 20 PP2 ~ KILL SPEED ~ 30 9.00 M/U CEMENT PLUG DROPPING HEAD. R/U SAFETY VALVE FOR LINER. RIH WITH BAKER FLOAT SHOE (5 - 4.276 - 1.55), 1 JT 5" 18# FL-4S CSG, BAKER DOUBLE VALVE FLOAT COLLAR (5 - 4.201 - 1.35), 1 JT 5" 18# FL-4S CSG~ BAKER LANDING COLLAR (5 - 4.201 - .85), 54 JTS 5" 18# FL-4S CSG~ 5" 8RD BOX X 5" FL~4S PIN X-OVER, BAKER "HMC" LINER HANGER (5.875 - 4.201 - 5.45), BA/~.ER C-2 SETTING SLEEVE W/6' TIE-BACK SLEEVE (5.750 - 5.250 - 7.50), AND BAKER RUNNING TOOL STEM ON 3.5" DRILLPIPE. 4.00 RIH SLOWLY WITH LINER. FILLED DP EVERY 10 STANDS UNTIL WINDOW. M/U TOP DRIVE AND CIRCULATED THROUGH BRIDGES AT 7698' AND 8100'. WORKED PAST LEDGE AT 8695'. CIRC PAST FILL AT 8731'. POSITIONED LINER FOR CEMENT JOB. FLOAT SHOE AT 8729.45. FLOAT CO~ AT 8685.42. LANDING COLLAR AT 8642.07. LINER HANGER AT 6399.5. TOP OF TIE-BACK SLEEVE 6392.00'. 3.00 PICK UP CEMENT HEAD AND CIRCULJ%TE AND COND MUD WHILE R/U HOWCO. CF24ENTED LINER IN PLACE WITH 415 SX'S GLASS "G" W/ .1% HR5, 2% CFR3, .12 GPS HA.LAD 344L - 15.8 PPG~ 1.15 YIELD. PUMPED 20 BBLS FRESH WATER AHEAD AND 5 BBLS BEHIND CEMENT SLURRY. FOLLOWED WITH 83 BBLS 11.8 PPG 1.50 MUD DISPLACEMENT. PUMPED 1ST 60 BBLS DISPLACEMENT AT 2.5 BPM AND FINAL _ __ AT 1 BPM. DROPPED PLUG BEFORE DISPLACEMENT. DID NOT BUMP PLUG. FULL _ CIRCULATION THROUGHOUT CEMENT JOB. TIME (HRS) CUM. ROT. HRS 180.50 ROTATING MUD MOTOR TRIPPING 8.00 C & C 3.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING 9.00 CEMENTING 1.50 PICK-t/P/LAY DOWN DS INSPECT BHA .50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.50 .50 ROTATE OFF HANGER AND L/D CEMENT HEAD. SWEPI ALASKA DAILY DRILLING REPORT PAGE 2 OF 2 RIG NAME PLATFORM "A" DATE 06/04/95 WORK ORDER 728520 FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A43-11LW SIDE TRACK SUMMARY OF OPERATIONS CONTINUE -- 2.50 POH WET WITH 15 STA/TDS DP. CHECK FLOW. POH AND L/D SETTING TOOL. .50 BREAK DOWN BAKER CEMENT HEAD. .50 M/U CLEAI~ OUT ASSEMBLY. 1.50 RIH WITH BHA. TAGGED CEMENT STRINGER AT 5198'. .50 M/U TOP DRIVE AND BEGIN CIRCULATING OUT CEMENT STRINGERS FORM 5198 TO 52-98'. CIRCULATING HOLE AT REPORT TIME. NOTE: WHILE MAKING UP LINER HANGER SETTING TOOL BACKED OUT - LAID DOWN AND REDRESSED. WHILE MAKING UP CEMENT HEAD 4.5 CONNECTION BACKED OUT - HAD TO BE REMADE UP. NOTE: DAILY COSTS INCLUDE 13.5M$ FOR CEMENT AND 4.5M$ FOR CASING. ,.?, 'i995 Gas Cons. Ar~cho~'ag~ pTe NAME PLATFORM "A" D MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A43-11LW SWEPI ALASKA DAILY DRILLING REPORT PROG. D~.. _H 10040 PRESENT DEPTH 8750 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 WORK OPtDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: RIH WITH 4 1/8 CEMENT MILL. PAGE 1 OF 1 ELEVAT. KB TO MSL l16.~u DATE 06/05/95 DIST. KB TO BHF 38.4 DAY 25 NLTA LTH/YTD / EST. DaY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 789 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/9% BH~ INSPECTION (CU~. ROT HRS) PPi ® KILL SPEED ~ 20 PP2 ~ KILL SPEED ~ 30 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.00 CONT. IN HOLE TO 5345'. CIRCULATED OUT CEMENT AND CONTAMINATED MUD AT 5345'. CHANGED SHAKER SCREENS. CIRC. EXTREMELY SLOW DUE TO AUGER BEING UNABLE TO KEEP UP WITH RETURNS. 2.00 DISPLACE CASING WITH FIW. 5.00 DRILL OUT SOFT CEMENT FROM 5345' TO 6060'. 2.00 LOST DC POWER TO MUD PUMPS. PULLED UP TO 5950' AND TROUBLE SHOT PROBLEM. CHANGE OUT BURNT CONTACTS TO PUMP IN DC PANEL. 2.50 DRILLED OUT CEMENT FROM 6060 - 6392' (TOP OF LINER). 1.00 CIRCUI2%TED HOLE CLEAN. TESTED LINER TOP WITH FIW TO 2300# PSI. HELD OK FOR 10 MINUTES. CHECK FOR FLOW - NO FLOW. PUMP DRY JOB. 4.00 POH WITH BHA WHILE LAYING DOWN 48 JTS. 3.5 DP WITH BAD HARDBANDING. 1.50 L/D BHA AND 27 JTS HWDP. 1.00 M/U NEW BHA WITH 4 1/8 CEMENT MILL. 1.00 RIH WITH BHA AT REPORT TIME. TIME (HRS) CUM. ROT. HRS 192.00 ROTATING 11.50 MUD MOTOR TRIPPING 5.00 C&C 3.00 REAMING SURVEYS JET REPAIRS 2.00 FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 2.50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM ~ -T.aD MIDDLE GROUND SHOAL ,E PLATFORM WELL A43-11LW WORK ORDER 728520 SIDE TRACK PROG. DEPTH 10040 PRESENT DEPTH 8750 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 06/06/95 DIST. KB TO BHF 38.4 DAY 26 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 790 LAST BOP TEST 05/21/95 LAST CSG TEST 05/15/95 DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: CLEANING OUT 5" LINER /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.50 CONT TO RIH WITH BHA TO TOL AT 6392'. BHA INSPECTION (CUM. ROT HRS) PPI ~ KILL SPEED ~ 20 PP2 @ KILL SPEED ~ 30 .50 M/U TOP DRIVE AND BREAK CIRCULATION. DRILL OUT 5' OF CEMENT IN THE THROAT OF THE LINER FROM 6392 - 6397'. 1.50 CONT TO RIH UNTIL TAGGING AT 8407'. 1.00 M/U TOP DRIVE AND BREAK CIRCUI2%TION. DRILL OUT CEMENT STRINGER FROM 8407 - 8558'. 1.00 CIRCULATED OUT CONTAMINATED MUD THROUGH GAS BUSTER. 2.50 DRILLED OUT HARD CEF~MqT FROM 8558' - 8590'. .50 CHECK FOR FLOW AND PUMP DRY JOB'. 3.50 POH WITH BI{A. 3.50 CHANGE OUT WORN MILL AND PICK UP AN ADDITIONAL 33 JTS 2 7/8 DRILLPIPE. .50 M/U TOP DRIVE AND FLUSH THROUGH 2 7/8 DRILLPIPE DUE TO EXTREME RUST IN INTERNALS OF 2 7/8 DRILLPIPE. 2.00 RIH WITH BHA. 1.00 CUT AND SLIP 100' DRILL LINE. SERVICE CROWN. ' 3.00 RIH AND TAG CEMENT AT' 8590'. M/U TOP DRIVE AND BREAK CIRCULATION. PUMP SWEEP AND CIRCULATE HOLE WHILE TESTING ALL GAS ALARMS WITH AOGCC. NOTE: BAD RUST IN 2 7/8 DRILL PIPE - LOST RABBIT AND PC PIPE IN ONE JT. - STUCK. _ SPECIAL THANKS TO SCHLUMBERGER FOR THE USE OF DOG HOUSE FOR EPOCH MUD LOGGERS. TIME (HRS) CUM. ROT. HRS 195.50' ROTAT I NG 3 . 50 MUD MOTOR TRIPPING 10.50 C & C 5.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICkUP/LAY DOWN DS 3 . 00 INSPECT BHA . 50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 1.00 _ . SWEP' ASKA DAILY DRILLING REPORT PAGE 1 OF 1 RTq NAME PLATFORM "A" PROG. DEPTH 10040 D MIDDLE GROLTND SHOAL PRESENT DEPTH 8750 L~_~%SE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 06/07/95 DIST. KB TO BHF 38.4 DAY 27 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 791 LAST BOP TEST 06/07/95 LAST CSG TEST 05/15/95 DRILLING FOREMA/q: SELTZ R H PRESENT ACTIVITY: RIH WITH BHA /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.50 DRILL OUT HARD CEMENT FROM 8590 - 8642' (LANDING COLLAR). 1.00 SI WELL AND PSI TESTED 5" CASING TO 2300# - HELD OK FOR 30 MIN. 1.50 DRILL OUT LANDING COLLAR AT 8642-8643. DRILL OUT ~La~RD CEMENT FROM 8643 - 8686 (FLOAT COLLAR). BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 20 PP2 @ KILL SPEED ~ 30 3.00 DRILL OUT FLOAT COLLAR. DRILL OUT HARD CEMENT FROM 8687 - 8630' (SHOE) DRILL OUT SHOE AND 6' OF OPEN HOLE. 1.50 PUMP 22 BBL MUD SWEEP AND CIRCULATED HOLE CLEAN. .50 PERFORM SHOE LEAK OFF TEST TO 11.0# PPG EQUIVALENT. DROP SINGLE SHOT AND CHECK FOR FLOW. 4.00 POH WITH BHA. 1.00 STAND BACK BHA. 5.50 PERFORM SUCCESSFUL BOP TESTS - AOGCC REP. ON LOCATION. 2.00 M/U NEW BHA WITH BIT #8. .50 BEGIN TO RIH WITH BHA AT REPORT TIME. RECOGNITION TO THE INLET CRANE CREWS LED BY KENNY MILLER AND MARK QUINT FOR THIER ASSISTANCE IN DEMOBILIZING PLATFORM 'C" AND THIER HARD WORK WITH THE RECENT INCREASE IN BOAT TRAFFIC. TIME (HRS) CUM. ROT. HRS 203.50 ROTATING 8.00 MUD MOTOR TRIPPING 4.50 C ~ C 1.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 5.50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 3.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.50 SWEPI ALASKA DAILY DRILLING REPORT RIG NAME PLATFORM "A" PROG. DEPTH 10040 FI MIDDLE GROUND SHOAL PRESENT DEPTH 8909 LE,_ PLATFORM "A" FOOTAGE DRILLED 172 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEP. TH 80 PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 28 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS DAYS SINCE LAST LTA 792 LAST BOP TEST ~9Z/95 LAST CSG TEST DRILLING FOREMAN: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: ON BOTTOM MILLING SUMMARY OF 3.00 RIH OPERATIONS (SHOW HOURS FOR EACH OPERATION) : WITH BHA. BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 20 PP2 @ KILL SPEED @ 30 TAG AT 8737' AND PICKED UP 6' M/U TOP DRIVE AND BREAK CIRCULATION PUMP HIGH VIS. PILL FOLLOWED BY 7.8# OIL BASED MUD. 6.56 ROTARY DRILLED FROM 8737' - 8909'. .50 CHECK FLOqz_pROP SURV~Zz_AND PUMP DRY JOB. 2.50 POH WITH BHA. 1.00 L/D BHA - 1 DC HAD SWELLED BOX. RETRIEVED SURVEY. 4 1/8 BIT HAD LOST ALL CON~z SHANKSz_AND ONE JET. M/U BHA WITH 4 1/8 MILL. 1.00 M/U TOP DRIVE AND BREAK CIRCULATION. PREP TO MILL UP LOST CONES. 4.00 RIH WITH BHA - LAID DOWN 3 JTS 2 7/8 DP WITH FLARED JTS. NOTE: RECOVERED SURVEY IS QUESTIONABLE - WILL RESURVEY ON MILL TRIP. _ TIME ~E~I CUM. ROT. HRS 210.00 ROTATING 6.50 MUD MOTOR TRIPPING 9.50 C & C 5.50 REAMING SURVEYS .50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 2.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING ~T~D~ SWEPI~ 'SKA DAILY DRILLING REPORT PAGE 1 OF 1 -k ~AME- PLATFORM "A" PROG. DEPTH 10040 FIELD MIDDLE GROUND SHOAL PRESENT DEPTH 8917 LEASE PLATFORM "A" FOOTAGE DRILLED 8 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 06/09/95 DIST. KB TO BHF 38.4 DAY 29 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST nTa 793 LAST BOP TEST 06/07/95 LAST CSG TEST 05/15/95 DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: POH WITH BHA. /GALLOWAY DR S~Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 MILL OUT UNDER GAUGE HOLE FROM 8904 - 8909'. 5.00 ROTARY MILL OUT HOLE/JI/NK FROM 8909 - 8912'. .50 DROP SURVEY AND PUMP DRY JOB. 3.00 POH WITH BHA. 1.00 4.50 · L/D USED BHA AND M/U NEW BHA WITH CONCAVE MILLING ASSEMBLY. RIH WITH BHA. RABBITED ALL 2 7/8 DP LOOKING FOR LOST SURVEY TOOL. FOUND TOOL IN 17TH STAND. NO READABLE SURVEY. FILLED DP AT 4090'. 9.00 M/U TOP DRIVE AND BRF_,AK CIR~TION. MILL OUT HOLE/JUNK FROM 8912' - 8917'. .50 CHECK FLOW AND PUMP DRY JOB. BEGIN TO POH WITH BHA AT REPORT TIME. RECOGNITION TO ANADRILL AND WEATHERFORD FOR THIER QUICK REACTION TO MOBILIZING PERSONNEL AND EQUIPMENT DUE TO THE'RECENT CHANGE IN NEEDS. BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ® 20 PP2 ~ KILL SPEED ~ 30 TIME (HRS) CUM. ROT. HRS 224.00 ROTATING 14.00 MUD MOTOR TRIPPING 7.50 C & C .50 REAMING .50 SURVEYS .50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH __ TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 1.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 .gAME PLATFORM "A" PROG. DEPTH 10040 FIELD MIDDLE GROUND SHOAL PRESENT DEPTH 8928 LEASE PLATFORM "A" FOOTAGE DRILLED 11 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /GALLOWAY DR PRESENT ACTIVITY: PERFORMING MWD SURVEY ELEVAT. KB TO MSL 116.0 DATE 06/10/95 DIST. KB TO BHF 38.4 DAY 30 NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 794 LAST BOP TEST 06/07/95 LAST CSG TEST 05/15/95 Bm~ INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 20 PP2 ~ KILL SPEED % 30 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.00 POH WITH BHA. 2.50 L/D MILL AND STABILIZERS. M/U BIT #9 AND BHA WITH MOTOR. 1.00 RIH WITH BHA AND SURFACE TEST MWD. 3.00 CONT TO RUN TO BOTTOM WITH BHA. FILL DP AT 4475 AND SHOE. .50 TAKE MWD SURVEYS AT 8771 AND 8884'. 1.50 WASH AND REAM OPEN HOLE FROM 8884 - 8917'. .50 ORIENT TOOL FACE A~rD MOTOR DRILL FROM 8917'T0 8928'. 1.00 EXPERIANCED MWD FAILURE. MADE MULTIPLE ATTEMPTS TO FREE UP MWI). 2.50 CHECK FLOW AND PUMP DRY JOB. POH WITH BHA. .50 L/D BHA. 2.00 M/U NEW BHA. CHANGED OUT MWD RECIEVER SUB. 1.00 SURFACE TEST MWD. 4.00 RIH WITH BHA. CHECK MWD AT 4500' AND SHOE. TAG UP AT 8928'. 1.00 PERFORMING MWD SURVEY AT 8899' AT REPORT TIME. NOTE: DISCOVERED 62M$ ERROR ON LOTUS SPREAD SHEET. MADE CORRECTION IN TODAYS REPORT. CORRECT DAILY COSTS OF $34,372. _" f_ IADCC BIT GRADE #9 - 2-2-WT-A-E-I-ER-DTF TIME (HRS) CUM. ROT. HRS 224.50 ROTATING .50 MUD MOTOR TRIPPING 13.50 C & C REAMING 1.50 SURVEYS 3.50 JET REPAI RS FISHING NIP UP/DOWN /BOP/WH __ TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 5.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON COR I NG SWEP! .SKA DAILY DRILLING REPORT PAGE 1 OF 1 NAME- PLATFORM ~,~D MIDDLE GROUND SHOAL LEASE PLATFORM WELL A43 - 11 LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 10040 PRESENT DEPTH 9143 FOOTAGE DRILLED 215 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / PRESENT ACTIVITY: TRIP IN HOLE W/NEW BIT ~12 ELEVAT. KB TO MSL 116.0 DATE 06/11/95 DIST. KB TO BHF 38.4 DAY 31 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 795 I-JkST BOP TEST 06/07/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CU~. ROT .RS) PP1 ~ KILL SPEED 1100 ~ 20 PP2 ® KILL SPEED 2200 ® 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 CIRC OUT AREATED MUD TO GET MWD TO GOING~ SURVEY AT 8899' BIT DEPTH. 3.00 MOTOR DRILL F/8928' T/9041' W/BIT #10. ROTARY REAM OUT WHAT WE DRILLED 8.50 CHECK F/FLOW, NONE. TRIP F/NEW BIT. 1.00 CUT DRLG LINE AT SHOE ON WAY BACK IN HOLE. 3.00 MOTOR DRILL F/9041' T/9143' W/BIT #11. ROTARY ~ OUT WHAT WE DRILLED 7.50 CHECK F/FLOW, NONE. TRIP F/NEW BIT AT RPT TIME. BIT #10 COND: 3-3-WT-A-E-1-RG-HRS BIT #11 COND: 3-3-WT-A-E-I-RG-HRS NOTE: ALL THE BITS HAVE DEEP WEAR AROUND THE GREASE PORTS; DOWN INTO THE SNAP RINGS .... DOYLE TOOK A BIT TO HTC AND THE HTC REP WILL HAVE INSERTS INSTALLED AHEAD OF THE AREA OF EXCESSIVE WEAR ON FUTURE BITS. (THIS WAS NOT THE CAUSE FOR LOSING CONES FROM BIT #8, WE ARE SEEING THIS ON THE MOTOR RUN BITS ONLY) TIME (HRS) CUM. ROT. HRS 230.50 ROTATING MUD MOTOR 6.00 TRIPPING 16.00 C & C 1.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RT~ NAME PLATFORM "A" PROG. DEPTH 10040 D MIDDLE GROUND SHOAL PRESENT DEPTH 9242 Lr_~aSE PLATFORM "A" FOOTAGE DRILLED 99 WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN:~WELLS R V / PRESENT ACTIVITY: TRIPPING FOR NEW BIT #14 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 TIH W/BIT ~12 .50 SERVICE RIG/TOPDRIVE AT SHOE FINISH TIH T/9143' W/BIT #12 MOTOR DRILL F/9143' T/9152' W/BIT #12..VERY SLOW ROP. CHECK F/FLOW, NONE. TRIP FOR NEW BIT #13. .50 2.50 8.50 3.50 MOTOR DRILL F/9152' T/9242' W/BIT #13 6.00 TRIPPING F/NEW BIT #14 AT REPORT TIME. ELEVAT. KB TO MSL 116.0 DATE 06/12/95 DIST. KB TO BHF 38.4 DAY 32 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 796 LAST BOP TEST 06/07/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PPi ~ KILL SPEED llS0 ~ 20 PP2 ~ KILL SPEED 2300 ~ 40 BIT #12 COND: DIAMONDS GONE FOR 5/16TH OF i~N INCH ON SHOULDER OF FACE OF BIT...ALL OTHER DIAMONDS ON FACE WORE EXCESSIVLY. BIT #13 COND: 4-5-WT-A-E-I-SD-HRS TIME (HRS) CUM. ROT. HRS 236.50 ROTAT I NG MUD MOTOR 6.00 TRIPPING 17.50 C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING SWEP~--'~-ASKA DAILY DRILLING REPORT PAGE 1 OF 1 RTG NAME_ PLATFORM D MIDDLE GROUND SHOAL L~.ASE PLATFORM "A" WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: RIH W/BIT #16 PROG. DEPTH 10040 PRESENT DEPTH 9501 FOOTAGE DRILLED 259 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / ELEVAT. KB TO MSL 116.0 DATE 06/13/95 DIST. KB TO BHF 38.4 DAY 33 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- LAST BOP TEST O6/O7/95 L~T CSG TEST 05/~5/95 BHA INSPECTION (CUM. ROT HRS) PPl Z KILL SPEED 1150 U 20 PP2 @ KILL SPEED 2300 ~ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.50 RIH W/ BIT # 14. 4.00 6 .S0 5.00 4.00 DRLG. W/ BIT # 14,F/9242' TO 9353'.SURVEY, CHECK F/FLOW. TRIP FOR BIT # 15. CHANGE BIT, CHECK MWD, RIH. DRLG. W/ BIT # 15 F/9353' TO 9501'. CHECK FOR FLOW POH 1.00 MAKE UP BIT #16, CHECK MWD AND MOTOR, RIH. Off !995 ' ~chorage SWEPI ~KA DAILY DRILLING REPORT TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 243.50 7.00 16.00 1.00 PAGE 1 OF 1 ~-' NAME PLATFORM "A" ~ MIDDLE GROUND SHOA~L LEASE PLATFORM WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 10040 PRESENT DEPTH 9840 FOOTAGE DRILLED 339 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / PRESENT ACTIVITY: DRLG W/ BIT # 17 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.50 RIH TO SHOE W/ BiT #16. .50 SERVICE RIG AND TOP DRIVE. .50 FINISH RIH. ELEVAT. KB TO MSL 116.0 DATE 06/14/95 DIST. KB TO BHF 38.4 DAY 34 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 798 LAST BOP TEST 06/07/95 LAST CSG TEST 05/15/95 BHA INSPECTION (C-~JM. ROT HRS) PPl Z KILL SPEED 1150 ~ 20 PP2 e KILL SPEED 2250 ~ 40 6.00 DRLG W/ BIT #16 FROM 9501' TO 9693'. (SLID F/9574' TO 9614') .50 SURVEY, CHECK FOR FLOW~PUMP PILL. 7.50 POH,CHANGE BIT, CHECK MWD AND MOTOR, RIH W/ BIT #17. .50 REAM F/9668' TO 9683'. 5.00 DRLG. W/ BIT # 17 F/9693' TO 9840'. (SLID F/9693'TO 9727') TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING 254.50 9.00 2.00 11.50 .50 P-~ NAME PLATFORM "A" D MIDDLE GROUND SHOAL LEASE PLATFORM WELL A43 - 11LW WORK ORDER 728520 SIDE TRACK DRILLING FO~: WELLS R V SWEPI ALASKA DAILY DRILLING REPORT PRO{]. ~ ~'H 10040 PRESENT DEPTH 10043 FOOTAGE DRILLED 203 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / PRESENT ACTIVITY: TRIP FOR BIT # 19 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 DRLG F/9840' TO 9873' W/BIT # 17. .50 CHECK FOR FLOW, SURVEY,PUMP PILL. 4.50 POH,B~ BIT. · '- -- PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE 06/15/95 DIST. KB TO BHF 38.4 DAY 35 NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 799 LAST BOP TEST 06/~4/95 LAST CSG TEST 05/15/9~ BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1125 ~ 20 PP2 ~ KILL SPEED 2275 ~ 40 4.00 TEST BOP'S TO 250/5000 PSI AND ANNULAR TO 250/3500 PSI. OK. 3.50 MAKE UP BIT # 18, SURFACE TEST MOTOR AND MWD, RIH TO SHOE. 1.00 SLIP AND CUT DRLG. LINE. .50- RIH AND REAM 23' TO BOTTOM. 6.00 .50 2.50 _ _ ! D~ F/9873' TO 10043' W/BIT #18. (ORIENT AND SLIDE F/9873' TO 9903'.) CHECK FOR FLOW~SURVEYfPUMP PILL. POH TIME (HRS) CUM. ROT. HRS 261.50 ROTATING 6.00 MUD MOTOR 1.00 TRIPPING 11.00 C & C 1.00 REAMING SURVEYS JET REPAIRS FISHING ..__ NIP UP/DOWN /BOP/WH TESTING BOP /WH 4.00 RUNNING CASING CEMENTING PICkUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM ~ MIDDLE GROUND SHOAL L__~E PLATFORM WELL A43-11LW WORK ORDER 728520 SIDE TRACK DRILLING FO~: WELLS R V PRESENT ACTIVITY: POH W/ FISH PROG. DEPTH 10040 PRESENT DEPTH 10043 FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / ELEVAT. KB TO MSL 116.0 DATE 06/16/95 DIST. KB TO BHF 38.4 DAY 36 NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LA. ST LTL 800 LAST BOP TEST 06/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1125 ~ 20 PP2 ~ KILL SPEED 2275 ~ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 FINISH POH AND L/D MWD, CHANGE MUD MOTOR, M/U BIT # 19 5.00 RIH~CHECK MOTOR~FILL PIPE TWICE. .50 ATTEMPT TO DRILL W/ BIT #19{ WOULD NOT DRILL. 1.00 CBU, CHECK FOR FLOW, PUMP DRY JOB. 4.50 POH.PIN END OF JARS BROKE (2.375" PH-6 CONNECTION) TOF 9928'. 2.50 WAIT ON FISHING TOOLS. SERVICE RIG. 7.00 MAKE UP FISHING TOOLS AND RIH. .50 TAG FISH AND ENGAGE FISH INTO OVERSHOT. .50 POH. TIME (HRS) CUM. ROT. HRS 262.00 ROTATING .50 MUD MOTOR TRIPPING 19.50 C & C 1.00 ~ING SURVEYS JET REPAIRS FISHING .50 NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT 2.50 EVALUATION CORING SWEPIfALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM ) MIDDLE GROUND SHOVEL Lm~SE PLATFORM WELL A43-11LW WORK OkDER 728520 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. D~fH 10040 PRESENT DEPTH 10108 FOOTAGE DRILLED 65 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 8735 WATER DEPTH 80 / PRESENT ACTIVITY: SHORT TRIPPING FOR LOGS SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 POH TO SHOE W/FISH .50 DROP DART AND SHEAR PUMP OUT SUB,PUMP DRY JOB. ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 801 o6/17/95 37 LAST BOP TEST 06/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1140 ~ 30 PP2 ~ KILL SPEED 2050 ~ 50 5.50 POH W/ FISH, LAY DOWN FISHING TOOLS,BIT #19 AND MUD MOTOR. 6.50 MAKE UP BIT #20, PICK UP NEW MUD MOTOR, INSPECT BHA.(L/D GALLED XO, L/D LEAD COLLAR PIN CUT OFF CENTERr L/D GALLED NM DC). 4.50 RIH W/BIT # 20. TEST MOTOR, FILL PIPE TWICE. _. 1.00. MAKE UP TOP DRIVE AND REAM 73' TO BOTTOM 2.50 DRLG W/ BIT #20 F/10043' TO 10108'. 1.50 CIRC BOTTOMS UP. 1.50 SHORT TRIP TO SHOE. ~ BIT #19 HAD 1 CONE WITH ROUGH BEARING.THE CONSESUS BY US IS THAT THE BHA HAD PARTED AND ~L%D ARRIVED ON BOTTOM BEFORE THE DRILL STRING DID. TIME (HRS) CUM. ROT. HRS 264.50 ROTATING 2.50 MUD MOTOR TRIPPING 12.00 C & C 2.00 REAMING 1.00 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 6.50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RT~ NAME PLATFORM "A" PROG. DEPTH 10040 ) MIDDLE GROUND SHOAL PRESENT DEPTH 10108 LEASE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: TIH W/CLEAN OUT ASSMY SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 7.50 CIRC/COND AT 10108' W/BIT #20 FOR LOGS 2 HRS, POH. 14.00 ELEVAT. KB TO MSL 116.0 DATE 06/18/95 DIST. KB TO BHF 38.4 DAY 38 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 802 · , LAST BOP TEST 06/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT MRS) PP1 ~ KILL SPEED 1140 ~ 20 PP2 ~ KILL SPEED 2050 ~ 40 RIG UP SCHLUMBERGER. RIH W/LOGS; AT 500' THE GR FAILED. POH, LAY DOWN GR. FLY OUT ANOTHER GR TOOLr MAKE UP RIH T/3000', GR TOOL FAILED. POH, LAY DOWN GR CHECK TOOL RERUN TOOLS, GR FAILED AT 3700'; TEMP PROBLEM. CONTINUE RIH AND LOG INDUCTION WHILE MOBLIZING ANOTHER GR. POH AFTER GETTING INDUCTION LOG, MAKE UP GR, RIH T/10082', LOGGERS TD, LOG GR, 2.50 POH, TEAR OUT SCHLUMBERGER. TIH W/BIT #20RR AT RPT TIME. BIT #20 COND: 2-2-ER-A-E-I-WT-LOG NOTE: TODAYS COST IS TOTAL OF TODAYS AND YESTERDAYS COST. $31697 $39964 TIME (HRS) CUM. ROT. HRS 264.50 ROTAT I NG MI/D MOTOR TRIPPING 8 . 00 C & C 2.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON 14 . 00 COR I NG SWEPI ALASKA DAILY DRILLING REPORT ,- PAGE 1 OF 1 .iG NAME PLATFORM "An PROG. L .H 10040 FIELD MIDDLE GROUND SHOAL PRESENT DEPTH 10108 E PLATFORM "An FOOTAGE DRILLED W~oL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: RUNNING 3 1/2" SLOTTED LINER ELEVAT. KB TO MSL 116.:0 DATE 06/19/95 DIST. KB TO BHF 38.4 DAY 39 NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 803 LAST BOP TEST 06/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 800 ~ 20 PP2 ~ KILL SPEED 1680 @ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.00 TIH W/BIT #20RR T/SHOE. 1.00 FILL PIPE AND CDL 100'. 1.00 2.50 .50 1.00 1.00 TIH T/9170', BRIDGE. WASH/~ F/9170' T/9678'. TIH F/9678' T/10053'. WASH/REAM F/10053' T/10108'. CIRC/COND. 2.50 SHORT TRIP T/SHOE AT 8731'r HAD FEW TIGHT SPOTS BOTH WAYS. DID NOT HAVE TO REAM, WAS ABLE TO WORK THRU. 3.00 CIRC/COND PUMP HI-VIS SWEEP. 4.50 1.00 3.00 _ POH W/CLEAN OUT ASSMY~ 3 SMALL TUGS NOTED. LAY DOWN BHA. SAFETY/PROCEDURES MEETINGr RIG T/RUN LINER. RUNNING 3 1/2n LINER AT RPT TIME. TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON C 0 R I NG OTHERS l,d'l' 'rr% 264.5O 11.50 4.00 3.50 3.00 2.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM LA" PROG. DEPTH 10040 FIELD MIDDLE GROUND SHOAL PRESENT DEPTH 10098 Z PLATFORM "A" FOOTAGE DRILLED WE~ A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: CIRC/COND MUD PREP T/CIRC DIESEL ELEVAT. KB TO MSL 116.0 DATE 06/20/95 DIST. KB TO BHF 38.4 DAY 40 NLTA LTH/YTD / EST. DAY LTL LTH/YTD / DAYS +/- DAYS SINCE LAST LTL 804 LAST BOP TEST 06/14/95 LAST CSG TEST 05/15/95 BHA INSPECTION (CUM. ROT MRS) PPl ~ KILL SPEED 725 ~ 20 PP2 ~ KILL SPEED 1300 ~ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 6.50 RUNNING 3 1/2n SLOTTED LINER W/1.66 INNER STRING. HANGER ASSMY HUNG UP AT TOP OF THE 5" LINER. .50 ATTEMPT T/WORK INTO 5' LINER TOP. 3.00 POH T/LINER HANGER, FOUND SUB W/4.250" O.D. ON LINER HANGER. 2.00 SENT SUB TO MACHINE SHOP, HAD IT TURN-ED DOWN T/4.05' O.D. 6.50 TIH W/LINER ASSMY. DETAILED: 10.42' BLANK PUP W/ORANGE PEEL F/SHOE AND 4-1/2' HOLES IN FACE, non RING SEAL SUB, 46 JTS OF SLOTTED, 30 MESH 3 1/2" BT&C (SPECIAL CLEARANCE COUPLINGS) 9.3~, N-80, (1425.36') BAKER 3 1/2" X 5" HYFLO II LINER HANGER, "C-2" SETTING SLEEVE W/6' TIE BACK! RUNNING TOOL STEM. SET MANGER W/SHOE AT 10098' AND TOP OF LINER AT 8650'-ROTATE OFF LINER UNABLE TO CIRC W/1.66 STINGER THRU THE "On RING SUB~ PULLED OUT OF IT AND CIRC OK. CIRC/COND MUD AT 50-60 SPM'S= 3.5 TO 4.2 BBLS/MIN WHILE PREP T/DISPLACE W/DIESEL AND CAPTURE MLrD IN STORAGE TANK AT RPT TIME. RUNNING CENTRIFUGE TO LOWER MUD WEIGHT ~ STRINGING IN MAPCO-200. 1.00 4.50 __ TIME (HRS) CUM. ROT. HRS 264.50 ROTATING MUD MOTOR TRIPPING 3.00 C & C 4.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /W-H RUNNING CASING 13.00 CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT 2.00 EVALUATION CORING OTHERS 1 ~n SWEPI..._..AI2t~KA DAILY DRILLING REPORT NAME PLATFORM "A" PROG. D~H ~D MIDDLE GROUND SHOAL PRESENT DEPTH LEASE PLATFORM "A" FOOTAGE DRILLED WELL A43°llLW SIZE OF LAST CSG WORK OI$_DER 728520 DEP. OF LAST CSG 10040 10098 5.000 8735 80 PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE 06/21/95 DIST. KB TO BHF 38.4 DAY 41 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 805 ' SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: POH WITH BHA WATER DEPTH /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 CIRCULATE AND CONDITION MUD IN WELLBORE. LAST BOP TEST 06/14/95 U~T ~SG TEST 0S/lS/gS BHA INSPECTION (CUM. ~OT HRS) PP1 ~ KILL SPEED 640 ~ 20 PP2 ~ KILL SPEED 1880 ~ 40 3.50 CHECK FLOW AND PUMP DRY JOB. POH WITH RUNNING TOOL AND WASH STRING. 1.00 L/D RUNNING TOOL AND PUMP THROUGH WASH STRING TO ASSURE IT IS NOT PLUGGED. 2.50 M/U WASH STRING ON TAIL, WITH 5" X 7" TANDEM CSG SCRAPER ASSEMBLY. 2.50 RIH TO 10,080' AND M/U TOP DRIVE. CONT. TO RIH SLOWLY TO TD. 7.00' EST. CIRC PSI AND HELD ON LOCATION SAFETY MEETING. PUMP 63 BBLS DIESEL FOLId)WED BY 25 BBL SWEEP. DISPLACED WELLBORE WITH CLEAN DIESEL. RECIPROCATED PIPE WHILE DISPLACING. 3.00 SD TO ALLOW DIESEL TO CLEAN WELLBORE. CLEANED PITS AND 0THER MISC JOBS ON RIG FLOOR. 1.50 CIRCULATE WELL WITH CLEAN DIESEL. 1.50 CHECK FOR FLOW AND BEGIN TO POH WITH CLEANOUT ASSEMBLY. NOTE: DAILY COSTS INCLUDE COSTS OF 3.5 LINER AND DIESEL FOR COMPLETION. DIRECTIONAL SURVEYS I COOR LAST SHOT I COST DATA TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAI RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS MUD ADDITIONS 264.50 7.50 10.00 3.50 3.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 10040 ! ~ MIDDLE GROUND SHOAL PRESENT DEPTH 10098 LE,,.SE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WORK ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ R H /GALLOWAY DR ELEVAT. KB TO MSL 116.0 DATE 06/22/95 DIST. KB TO BHF 38.4 DAY 42 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 806 / LAST BOP TEST 06/14/95 LAST CSG TEST 05/15/95 PRESENT ACTIVITY: RIH WITH SLICKLINE SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 CONT. TO POH WITH CLEANOUT ASSEMBLY. 1.50 L/D WASH STRING ASSEMBLY. BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED 2.00 REMOVE WEAR RING AND PREP RIG FOR PICKING UP AND RUNNING PRODUCTION EQUIPMENT. 11.50 RIH WITH PROD EQUIPMENT AS FOLLOWS: WL ENTRY GUIDE (3.1Xl.995}~ 1 JT 2 3/8 EUE 8RD 4.7# N-80 TBG~ OTIS XN NIPPLE (2.375X1.875), 1 JT 2 3/8, BAKER FH PACKER W/ PUPS (30K SHEAR) (4.125X2.X13.5), 1 JT 2 3/8, OTIS X NIPPLE (2.375X1.875), 1 JT 2 3/8, GLM #9 (3.875X1.901X14.49), 17 JTS 2 3/8, GLM #8 (3.875X1.901X14.54), 17 JTS 2 3/8, GLM #7 (3.875Xl.907X 14.51), 16 JTS 2 3/8, GLM #6 (3.875Xl.907X14.44), 10 JTS 2 3/8, 2 3/8 PIN X 2 7/8 EUE 8RD X-OVER, 6 JTS 2 7/8 EUE 8RD 6.5# N-80, GLM #5 (4.750X2.347X14.77), 22 JTS 2 7/8, GLM #4 (4.750X2.347X14.74), 28 JTS 1.50 2 7/8, GLM #3 (4.750X2.347X14.84), 37 JTS 2 7/8, GLM #2 (4.750X2.347X 14.78), 45 JTS 2 7/8, GLM #1 (4.750X2.347X14.81), 51 JTS 2 7/8, BAKER FY-6 SSSV W/TLO (4.625X2.313X15.66), 9 JTS 2 7/8, TBG HANGER WITH PUP. INSTALLED 7 TOTAL BAN-DS ON SSSV CONTROL LINE. ONE EVERY OTHER JT. M/U LANDING JT AND LAND TBG HANGER IN WELLHEAD. R/U AND CIRCULATE 1 1/2 TBG VOLUME. DRAIN RISER AND SET LOCK DOWN PINS. 4 50 R/U SLICK LINE AND TEST LUBRICATOR TO 1500#. RIH WITH OPENING TOOL AND OPEN SSSV. RIH AND SET PLUG IN N TEST SPOOL. SET PKR % RPT TIME. 640 ~ 20 1880 ~ 40 TIME (HRS) CUM. ROT. HRS 264 . 50 ROTAT I NG MD-D MOTOR TRIPPING 14 . 00 C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 1 . 50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON COR I NG OTHERS 8.50 SWEPI AI2t~KA DAILY DRILLING REPORT PAGE 1 OF 1 RIc NAME PLATFORM "A" PROG. DEPTH 10040 ; ~- MIDDLE GROUND SHOAL PRESENT DEPTH LE~SE PLATFORM "A" FOOTAGE DRILLED WELL A43-11LW SIZE OF LAST CSG 5.000 WOR~ ORDER 728520 DEP. OF LAST CSG 8735 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 96/23/95 DIST. KB TO BHF 38.4 DAY 43 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 807 f LAST BOP TEST 06/14/95 LAST CSG TEST 05/15/95 DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: RIG RELEASED /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 FINISHED SETTING'PRODUCTION PACKER WITH 1000# ON TUBING. TOOK PSI UP TO 3500# TO TEST TUBING. 1.00 P0H WITH SLICKLINE AND R/D UNIT. 4.50 INSTALL BPV. CLEAN ROTARY AND RIG FLOOR AND ASSOCIATED EQUIPMENT. 10.50 N/D BOP'S AND EQUIPMENT. HELD ON LOCATION SAFETY MEETING. N/D RISERS AND INSTALLED WELLHEAD. PRESSURE TESTED WELLHEAD AND TREE TO 5000#. COMPLETED FABRICATING ALL CONNECTIONS BACK ON WELLHEAD TREE. REMOVE BPV AND TURNED WELL OVER TO PRODUCTION. 1.50 ~LEANED WELLHEAD ROOM AROUND 43-11. NOTE: RIG RELEASED FROM A 43-11LW 12:00 A.M. 6/23/95. 640 ~ 20 1880 ~ 40 TIME (HRS) CUM. ROT. HRS 264.50 ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAI RS 4.50 FISHING NIP UP/DOWN /BOP/WH 10.50 TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 3.00 t~OV OS !995 Gas Cons. Commissio~ Shell Western E&P Inc. An affiliate of 8hell Off Company P. O. Box 576 Houston, TX 77001 June 26, 1995 Mr. Larry Grant Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: SUBJECT: LOG DATA FROM SWEPI MGS A-43-11LW, MIDDLE GROUND SHOAL FIELD, COOK INLET, ALASKA Enclosed please find the following log data from the SWEPI MGS A-43-11LW well Middle Ground Shoal Field, Kenai Borough, Alaska (API# 50-733-10082-01): 1 BLP Phasor Dual Induction- Gamma Ray log ~- (_~'? ~ ~ "'- q( 1 BLP Borehole Compensated Sonic - Gamma Ray log ..__ (_~ 7 ~'(-. 1 BLP Induction Resistivity - Gamma Ray log ---- ~~ ~---- [ (._9~9 1 Sepia Phasor Dual Induction - GR log 1 Sepia Borehole Compensated Sonic - Gamma Ray log 1 Sepia Induction Resistivity - Gamma Ray log 1 LIS tape DITE/BHC/GR/AMS 1 Tape Listing DITE/BHC/GR/AMS 1 LIS tape IRT-J/GR ! Tape Listing IRT-J/GR 1 List of Formation Tops Please sign one copy of this letter and return to me at the above address. Very truly yours, Maria A. Balzarini Senior Petrophysical Engineer Receivedb/~/, ~'" ~ Date; . /- .× June 26,1995 Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. Box 576 Houston, TX 77001 Mr. Larry Grant Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: SUBJECT: FORMATION TOPS PICKS FOR THE SWEPI MGS A-43-11LW, MIDDLE GROUND SHOAL FIELD, KENAI BOROUGH, ALASKA Here is a list of formation tops encountered in the SWEPI MGS A-43-11LW (API//50-733-10082-01), as required by the AOGCC. Please note that this well was drilled through the overturned limb of the Middle Ground Shoal anticline, so the second set of Hemlock formation tops were encountered in reverse order. A-43-11LW (KB= 116') Approximate Formation Top MD TVD Subsea GB 6,872' 6,865' -6,749' GD 7,010' 6,998 -6,882' GN 7,240' 7,212' -7,096' GO 7,268' 7,237' -7,121' GR 7,560' 7,499' -7,383' GS 7,610' 7,545' -7,429' HC 7,822' 7,739' ~ -7,623' HD 7,890' 7'801'p~ EC~! V~.0_-7'685' HE 7,950' 7,856'_ 7,740' 7,768' I-t2F 7,980' 7,884'~ HI 8,041' 7'940~ ~ 0 ~ -7,824' HK 8,090' ~t10.~7~98~5.. ~ -7,869' HN 8,216' -8~,~1001' & ~05 ~:on$. -7,984' ('~;;h~' ~8,117' HR 8,361' 8,233' ,4ilC]-tO~rit£o ,jsl~._~ 35' Fault 8,380' 8,251' HR (repeated) 8,483' 8,346' -8,230' HR(overtumed) 9,300' 9,099' -8,983' I-IN 9,510' 9,285' -9,169' IlK 9,733' 9,480' -9,364' HI 9,799' 9,537' -9,421' HF 9,876' 9,603' -9,487' HE 9,932' 9,651' -9,535' HD 9,972' 9,684' -9,568' HC 10,048' 9,749' -9,633' TD 10,108' 9,799' -9,683' If you have an), questions, I can be reached at (713) 544-2389. VeD, truly yours, Maria A. Balzarini Senior Petrophysi¢_~ E~ MEMORANDUM TO: David Job.~~ Chairman THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 6,1995 Blair Wondzell,~ P. I. Supervisor 4/'~,,,,~r FROM: John Spaulding~-.,,.- SUBJECT: Petroleum Insp. FILE NO: AV3LFFCD.doc BOP Test Shell A Shell Western E&P Middle Ground Shoals PTD95-50 Tuesday June 6, 1995: I witnessed the BOPE test on Shell Western E&P's Shell "A" platform Middle Ground Shoals Unit. The AOGCC BOPE test report form is attached for reference. ~ Upon my on June 5 1995 at 6pm i learned that the BOPE test scheduled for this evening would be delayed for approximately 24 hours due to hole problems. The test was started at 11 pm and lasted for 4 hours, all systems were found to be in excellent condition and a very good test was observed. While testing the H2S gas detectors the light on the rig floor burned out and a bulb was not readily available and was to be ordered, although the visual alarm was the inoperable the audible alarms were working quite well. Summary: ! witnessed the BOPE test on SWEPI's Shell "A" Platform, 0 failures 4 hour test time. Attachments: AV3LFFCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Inlet Drilling Rig No. Operator: Shell Western E&P Well Name: Casing Size: 5" Set @ 8731' Test: Initial Weekly X Other DATE: 6/6/95 PTD # 95-50 Rig Ph.# 770-5756 Rep.: George Brewster Rig Rep.: R. V. Wells Location: Sec. 11 T. 8N R. 13W Meridian Seward Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location yes Standing Order Posted (Gen) yes Well Sign yes Drl. Rig ok Hazard Sec. yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 500/5,000 P 1 500/5,000 P 1 500/5,000 P 2 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 300/3,000 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 P P P P 2 P I P CHOKE MANIFOLD: No. Valves 13 No. Flanges 30 Manual Chokes Hydraulic Chokes I Test Pressure P/F 500/5,000 P 500/5,000 P 1 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 P Pressure After Closure 2300 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 21 Trip Tank ok ok System Pressure Attained minutes 52 Pit Level Indicators ok ok Blind Switch Covers: Master: YES Remote: Flow Indicator ok ok Nitgn. Btl's: 4 average 2000 Meth Gas Detector ok ok Psig. H2S Gas Detector ok "Ok sec. sec. YES Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: During testing of the H2S detection system the light on the rig floor burned out; the H2S sytem still has the audible alarms in operation while waiting on the light bulb to arrive. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Insp~el~L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FFCD.XLS John H. Spau/ding MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, Chairman DATE: June 6,1995 THRU: Blair Wondzell, ¢~~ FILE NO: P. I. Supervisor ~/'~ ~ FROM: John Spaulding~o~,,~ SUBJECT: Petroleum Insp?' AV3LFFCD.doc BOP Test Shell A Shell Western E&P Middle Ground Shoals PTD95-50 Tuesday June 6, 1995: I witnessed the BOPE test on Shell Western E&P's Shell "A" platform Middle Ground Shoal~ Unit. The AOGCC BOPE test report form is attached for reference. Upon-my(bn June 5 1995 at 6pm I learned that the BOPE test scheduled for this evening would be delayed for approximately 24 hours due to hole problems. The test was started at 11pm and lasted for 4 hours, all systems were found to be in excellent condition and a very good test was observed. While testing the H2S gas detectors the light on the rig floor burned out and a bulb was not readily available and was to be ordered, although the visual alarm was 'the,inoperable/the audible alarms were working quite well. Summary: I witnessed the BOPE test on SWEPI's Shell "A" Platform, 0 failures 4 hour test time. Attachments: AV3LFFCD.XLS ,,._ ._..._ BOPE 'i',st Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 5" Test: Initial X Workover: Inlet Drilling Rig No. Shell Western E&P Set @ 8731' Weekly X Other DATE: 6/6/95 PTD # 95-50 Rig Ph.# 776-5756 Rep.: George Brewster Rig Rep.: R. V. Wells Location: Sec. 11 T. 8N R. 13W Meridian Seward MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location yes Standing Order Posted (Gen) yes Test Quan. Pressure P/F 500/5,000 P Well Sign yes Drl. Rig ok Hazard Sec. yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP 1 500/5,000 P 1 500/5, 000 P 2 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I P 300/3,000 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 13 Test Pressure P/F 500/5,000 P 30 500/5,000 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 2300I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 21 Trip Tank ok ok System Pressure Attained minutes 52 Pit Level Indicators ok ok Blind Switch Covers: Master: YES Remote: Flow Indicator ok ok Nitgn. Btl's: 4 average 2600 Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok sec. sec. YES i..-Na i)er-0f.Failu..i:;s.: ........................ ............ ;Tes.t:Time~Hoursl ......... ~U~:~e:;::oi:vaives te~t:~d ........ 20--.Repair orRePlaC~ment::of~ail~: I Equipment will be made w~'~-~'~ 0 ~ay's. Notify the Inspector and follow with Written or Faxed verification to Ithe AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: During testing of the H2S detection system the light on the rig floor burned out; the H2S sytem still has the audible alarms in operation while waiting on the light bulb to arrive. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspj~l~JrL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FFCD.XLS John H. Spaulding ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVEFtNOFt 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 44.61 Re: Thc applicatiou of Shell Western E&P Inc. to drill, complete and produce thc Middle Ground Shoal No. A43-1 I LW well in thc Middle Ground Shoal Field. G. S. Nady Manager - Asset Administration Alaska Enginccri ng/Assct Admi n istralion Shell Western E&P Inc. P. O. Box 576 Houston, Tx. 77001 Dear Mr. Nady: Tile rcfcrcnccd applicalion was received on April 1 l, 1995. Thc Middle Ground Shoal No. A43-I ILW well is 1o be drilled lo thc slccply dipping west flank of thc reservoir. Structural complexities in this portion of~he field require producers to be drilled at less than 80-acre spacing to insure adequate drainage. Thc subjccl well will bc Iht third producer in thc soulhcast qnartcr of Section 11, T8N, RI3W SM.. Tile Alaska Oi! and Gas Conservation Commission has reviewed thc evidence available and hereby anlhorizcs tl~c drilling, completion and production of thc referenced well pursuant to Rule 6 of Consc~'ation Order No. 44. BY ORDER OF TIlE CO Olt ?~vi(~?hn?~:?mirman. L~ . . ~ crman Babcock. Colnmissioncr Alaska Oil and Gas Conscn, ation Commission /~aS;~la1 ~)ilDa°nUdgl~;;' cCo°nn;cn~,~a ~?OlnlC~olnmission ALASKA OIL AND GAS / C ONSERVATI ON CO--SSI ON TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANC, HORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 27, 1995 G. S. Nady Mgr., - Asset Admin. Shell Western E&P Iuc. P O Box 576 (WCK 5237) Houston, Texas 77001-0576 Re: Middle Ground Shoal A43-11LW Shell Western E & P Permit No. 95-50 Sur. Loc. PltfA, Leg 1. Cond 3. 1628'FSL & 430'FEL SI 1. T8N. RI3W, SM Btmnholc Loc. I{)247'MD-KB: 2119'FSL & 1799'FEL. SI 1. T8N, RI3W, SM Dear Mr. Nady: Enclosed is thc approved application for permit to rcdrill the above referenced well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required by law from olher governmental agencies, and docs not authorize conducting drilling operations until all other required pcrmitling determinations arc made. Bioxvout prcvcnlion equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approxinmtcly 24 hours) must be given to allow a rcprcscnlalivc of the Commission Io witness a lcsl of BOPE installing new hole. Notice may be given by contacting Iht Commission al ( _ dlffEnclosurcs cc: Department offish & Game. Habitat Sectiou w/o cncl. Department of Environmental Consen,ation w/o encl. ,' "' STATE OF ALASKA AL,~ .... A OIL AND GAS CONSERVATION COMMIbo.,DN PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill J---'] Redrill J-X-] lb. Type of well. Exploratory F----JStratigraphic Test I--] Development Oil j-~rj Re-Entry J~Jaeepen J---l ServiceF~-j Development Gasr--j Single Zone[--] Multiple ZoneJ---] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Shell Western E&P Inc. 116' K}3 feet MIDDLE GROUND SHOAL 3. Address (W(.,K 5'ZZ,'7') 6. Property Designation "G" POOL P.O. Box 576, Houston, TX 77001-0576 ADL 18754 4. Location of well at surface PLATF A, LEG 1, COND 3 7. Unit or property Name 11. TypeBond(s**eoAAc25:o25) 1628' FSL & 430' FEL Sll, T8N, R13W, S.M. MIDDLE GROUND SHOAL BLANKET At top of productive interval 8. Well number Number 9000' MD-KB; 1978' FSL & 1424' FEL Sll, T8N, R13W, S.M. A43-11LW 400 HH 7522 At total depth Amount 9. Approximate spud date 10247' MD-KB; 2119' FSL & 1799' FEL Sll. TDN. R13W S.M. $200.000 5/01/95 i2_. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO a,d TVO) property line 3481 feet 1300 feet 3746 10 247 MD feet 16. To be completed for deviated 'wells 17. Anticipated pressure (,~ 2o **c 25.o35 (,, 2)) Kickoff depth 7000 feet Maximum hole angle 41 o Maximum,u,ac~ 914 m~g ^t to,a~ Uepth (WO) 4535 18. Casin.g program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 5" 18~ N80 FL4S 2400' 6600' 6595' 9000' 8786' 300 SX 4-1/8" 3-1/2" 9.3# N80 FJ 1300' 8936' 8725' 10236' 9966' NA (SLOI-fED LNR) 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary RECEIVED Total depth: measured 8798 feet Plugs (measured) true vertical 8771 feet APR 2 4 1995 Effective depth measured 8700 feet Junk (measured) true vertical 8675 feet Alaska 0il & Gas Cons, Commission mch0ra _;e Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 319' 24" 650 SX 319' 319' Surface 1609' 13-3/8" 1925 SX 1609' 1609' Intermediate 8798' 7" 1500 SX 8798' 8771' Production Liner Perforation depth: measured 8314' - 8609' true vertical 8298' - 8587' 20. Attachments Filing fee'Jr~-J Property platJ-~-J BOP Sketch~ Diverter Sketch BI Drilling program J~] Drilling fluid program J~J Time vs depth plot J~j Refraction analysis J----] Seabed report ~ 20 AAC 25.050 requirements [~] 21. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed~-~,~,zJ~ ~,,~A ~ G. S. NADYTiIle HGR.- ASSET ADHIN. Date 4/04/95 · - " ' Comission Use Only Permit Number lAp, number ] 1See cover letter ?~'- -,_~O ! 50- .,~.~,~-//O O o~.. -<:::P /I -- --'~' ¢~-~''' If°r other requirements Conditions of approval Samples required [--] Yes_J~ No Mud Icg required ~ Yes~;:~ No Hydrogen sulfide measures.[~:~ Yes ~ No Directional survey require~ Yes r--] No Required working pressure for ROPE r---m 2M; ~ 3M - J~ 5M - 1OM - -- 15M Other: Origin C jignedLl . F--I ! ] by order of Approved by David W. Johnston commissioner the commission Date X///C,'7,/~..Z WE'LL LOCA~'iON el_AT N..,U N C '.%HA[ FIELD MIDDY. 'F. G A--~I../',TF()~M COOK INI_£T, ALASKA WE:I I ' A4,..3--1 1LW S~J'RFAC. E LOCA';I()N I 6'),~, FSL 450 F'~.L. ~,~1 i TOSN R12~W K~E I 16' MSL · : · 11 A4- ' - ! 1 =(_ND . _ ' A4¢-- '~ T LVV 1024/ .'CB 9966 TVD - ' 21i9 FSL 1799 [ kL : '[A~(~.l' ~ 1 77E~ MD ?~6'lVO .~ . 1B'9 FSI. 949 F~.L . ' A/+.I A32- 11G o: ~, A32--. 1'~ R~ } ; 2 [ A12A-'01~ -A!1--01C A12 ":* ' i'. 't '~, A22-L:: (; / / A13 - 1LND 4" / /; \ ' /\ / ,- /::< / / / I $9~,__;~i:.~D~' ' ' ; .... R"l .... A/'1' I ....... ?..,,;., · / / / ' ~/ /; ;; ,',24 .-O ! I_EP !i ...... ' ..... // 12C A1~-120 .~---~' A23-' 2G A1.5 ._.. 12RDG RECEIVED APR 1 1 1995 Alaska Oil & Gas Cons. Commission Anchora,? , 12. 13' TOTAL P.O? MIDDLE GROUND SHOAL WELL NO. A43-11LW WELL PROGRAM Middle Ground Shoal (MGS) A43-11LW will be a redrill of existin~ well A43-11. The objective is the West Flank Hemlock reservolro The well will be drilled directional out of the existing 7" casing through the crestal Hemlock to 9,000'MD-KB. A 5" liner will be run and cemented. The well will be directional drilled with a 4 1/8" hole to TD of 10,247'MD-KB, 9,966'TVD-KB. The well will be completed in the West Flank Hemlock by running a 3 1/2" slotted liner. RECEIVED APR 1 1 1995 Al~ka Oil & Gas Cons. Commission Anchora,/~ WELL: LOCATION: OBJECTIVE: EVALUATION A43-11LW PLATFORM A, LEG 1, CONDUCTOR 3 1,628' FSL 430' FEL Sll TOBN R13W SM HEMLOCK GEOLOGY DRILLING PROGNOSIS FIELD: KB: MIDDLE GROUND SHOAL 116' DRILLING LOGS WIRELINE LOGS AMS GR LDT CNL DITE I I I I I I RESISTIVITY LOG MUD SIGNIFICANT LOGGERS FORMATIONS G SANDS HEMLOCK HC HEMLOCK HN HEMLOCK HR HEMLOCK HN2 HEMLOCK HK2 HEMLOCK HE2 HEMLOCK HC2 TD III II '1 I I H I h MD (TVD) 319' 1,609' (1,609') 6,600' (6,595') 7,000' (6,993') 7,769 (7,666') 8,527' (8,346') 9,000' (8,786') 10,247' (9,966') L_ II HOLE SIZE 6,1 1/8" CASING MUD DIRECTIONAL PROGRAM PROGRAM 20" I 13 3/8" 711 5'm CEMENTED I MINERAL OIL BASE MUD 9.0 PPG TO 13.0 PPG EXPECTED MUD WEIGHT 9.0 PPG 3 1/2" SLOTTED LINER J EE Ei E D BUILD & TURN TO 41DEG NTOW DROP & TURN @ 7,769' TO 18 DEG N70W 20 DEG NTOW I I I I I Oil & Gas Cons. Commission /Im~ora.~ o MIDDLE GROUND SHOAL A43-11LW DRILLING FLUID PROGRAM The 6" hole and 4 1/8" hole will be drilled using an oil base mud. The anticipated mud weight is 11.0 ppg in the 6" hole and 9.0 ppg in the 4 1/8" hole. EXPECTED PRESSURES The expected pressure gradient in the West flank Hemlock is 0.455 psi/ft. The expected maximum bottom hole pressure at TD is 4,535 psi at 9,966'TVD. The expected maximum surface pressure with an oil fluid column and the well shut in is 914 psi. CASING PROGRAM A 6" hole will be drilled out of the existing 7" casing to liner point at 9,000'MD-KB. A 5" 18#/ft N80 FL4S liner will be run and cemented. A 4 1/8" hole will be drilled out of the 5" liner to TD at 10,247'MD-KB, 9,966'TVD-KB. A 3 1/2" slotted liner will be run and hung at 8,936'MD-KB. RECEIVED APR 1 I 1995 Oil & Gas Cons. Commission ~ K SI LINE S 355 3' x 3' x 3' x 3' 5 0S$ 3' x 3' X 3' X 3' X 3' 5 KSI 5 KS~ GA rE VALVE ILJSI'ABLE MANL~AL C~O~E · 3' 5 ,~SI ,,4OTE OPERA I'EO CHOKE /t6' IOKSI IIY©FIAULIC A©JUSTASLE ~'SSI]RE GAGE LINES D/GAS SEPAIIATO~ lINE INLE T-~ SI-IELL WESTERN E&? INC, MIDDt, E GROUND SHOAL FIELD PLATFORH "A" CIIOKE HAH[ FOLD vENIEO Ar cnOwN',,,,, Shell Western E&P. Inc. Platform "A" Solids Control/Mud System Desilter 1 6 Cone · S.and Trap Derrick Shakers · i Derrick Shakers mps To Mut To Mutu umps To De~asser To Deiasser IDegasser Mixers ~"~ ~-~/~" HOhE .5000 PSI STACK TOP OF DERRICK FLOOR i BOTTO~ OF ROTARY BEAM FILL UP LINE 13-5/8' 5000 PSI F-LAMGE BUND RAM 5OO0 PSI PIPE RAM SOO0 PSI ~--- ~3-5/8- 5000 _ ,, 13-5/8- 5000 PSI ~GE . RIG C[~ ~00R ' -! ~,p~ ! 1 ~995 .,,~,,.,:a._7 ,.t, 0~ & 6as Bons. Gomm'tssion ROOM FLOOR 50OO I DSA L 'F' ~~I FLkNG E SPOOL~ SHELL MINIMUM FlOP STACK REQUIREMENTS M~n. M,n. No II~m I.D. Nom~n.~l 1 Flowline ?" 2 Fill up. Lint ......... .2'I __ ..................... 4 Annulai ~ TWo ~i~l~ ~'t O"ne du~l hydtullic~ly ,,. - ., ) G~, v~,~ 3 I/8" ''8 ~l~"V~i~ Pow,'¢ 'Om~l~d ..... 3 ii~'';' ....... T L',n¢' i'o chok~ m~nilo[d ......... ., 0 O~l~ V~lv~ ' 2,1/18" T Ch,Ok v~;~ .... ' 2.~/~" ' ...... .................. 2 ~ing SPoo~ ................... . ~ ~'o~;v~d ~,,~,~;~ O~¢ c'o~o~ _ 2' x 2"x 2" c~o~ .... ._ ~ OPTIONAL .............. o~,~u . ._ DRAWING & CHECK LIST 104A SHELL CLASS 5M SURFACE IN'STALLATIONS NORMAL AIR/GAS" FOR AIR/CAS DRILLING CONFIGURATION A ANNUL_AR PREv£NfER BLINO RAM ~IPE RAM DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL A43-11LW 10. 11. 12. 1. Move to A43-11 (leg 1, conductor 3) and rig up. 2. Kill well. Test casing to 2,000psi. 3. Nipple up 5,000 psi BOP stack and test. 4. Pull tubing and completion equipment. 5. GIH with tubing & set bridge plug at 7,000'. 6. Set whipstock at approximately 7,000' and sidetrack. 7. Directional drill to 9,000'MD-KB using a 6" hole. 8. Log.. 9. Run a 5" liner to 9,000'MD-KB and hang off at 6,600'MD-KB. Cement liner. Clean out and pressure test liner. Directional drill a 4 1/8" hole to 10,247'MD-KB. Log. 13.- Run a 3 1/2" slotted liner ahd hang at 8,936'MD-KB. 14. 15. 16. Run packer and tubing. Nipple up wellhead tree. Displace the mud with diesel using coil tubing. REEEIVED APR 1 I 199 Alaska Oil & Gas Cons. Commission Yell ......... : A43-11LW (P1) ?ield ........ : MIDDLE GROUND ·SHOAL 2omputatlon,.: MINIMUM CURVATURE 3nits ........ : FEET ]urface Lat..: 60.79579387 N ;ur~ace Long.: 151.495859%6 W Anadrill Schlumberger Alaska District ~ ~~~,~ ~/~'~~f% ' - 1111 East 80th AVenue (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL P~ for SHELL WESTERN Legal Description ]urface ...... : 1628 FSL 430 FEL Sll T08N R13W SM ?ie-in/KOP...: 1712 FSL 627 FEL Sll T08N R13N SM Farget ....... : 1819 FSL 949 PEL Ell T08N R13W SM $~{L .......... : 2119 FSL 1799 FEL Sll T08N R13W SM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 232787.75 2485846.49 232591.84 2485934.60 232272.25 2486049.29 2~1~29,32 2486368.57 STATION MEAS INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH ?IE- IN/KOP 7000 5.00 276.00 ~000 5 02 276 06 ' 7100 10.93 284.27 7200 16.90 286.73 7300 22 . 89 287.93 7400 28.88 288.65 7500 34.87 289.14 6/100 CURVE 7.5-94 40,.$0 IURVE 6/100 7761 40.50 289.49 ~ARGET ~1 7769 40.00 289.49 7800 38.17 289,34 7900' 32.~8 '' 288.77 8000 26 19 287 98 6/100 CURVE 8069 22.06 287.20 PROPOSED WELL PROYILE VERT-DEPTHS BKB SUB-S 6993 6877 6993 6877 7092 6976 7189 7073 7283 7167 DIST 215 215 228 252' 286 7373 72'57 7458 7342 %53~ 74t6 7660 7544 7666 7550 7690 757~ 7771 7655 7859 7743 7922 7806 33O 383 .44-0 549 554 573 '.631' 679 7O8 Prepared ..... : 03/30/95 section at.,,: ~90.56 KB elevation.: 116.00 ft Magnetic Dc~n: 22.652 ~ Scale Factor.: 0.99998125 Convergence..: -i.305786i4 ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN# / RELATIVE-COORDINATES FROM-THE-WELLHEAD . 83.63 N 197.87 W 83.63 N 197.91 W 86.43 N 211.45 W " 92.96 N 234.58 W 103.14 N 267.03 W STATE-PLANE TOOL DL/ X Y FACE 100 · 232591.84 2485934,60 15R <TIE 232591.81 2485934.61 15R 6.00 232578.32 248~937.72 7R 6.00 232555.35 248~944.77 4R 6.00 232523,15 2485955.68 3R 6,00 116.86 N 308.45 W 133.97 N 358.38 W t5~..96 N .--412~5.0 W 189.20 N 514.93 W 191.00 N 520.00 W 197.39 N 538,14 .W 216;22 N 592,56 W 231.61 N 638,81 W 240.15 N 665,70 W 23~482.05 2485970.35 3R 6.00 232432.53 2485988,59 2R 6.00 · ... ~3-~-37'8.85 2486'0~8.'80 6.00 ......... %. 232277.28 2486047.38 LS 0.00 .: 232272,25 2486049.29 1771 6.00 6.00 6.00 6.00 ' 6.00 232254.26 2486056.09 177L 232200~28' 2486076.15 i77L 232~54.40 2486092.60 176L 232127.71 2486101.75' SHELL WESTERN E '& P 'INC .... : A4B- VERTICAL SECTI:ON VIEW Section at: 290.56 TVD Scale.' ! ~nch = ~4.00 fleet .... _ Oep St_ale.' ! inch = ~400 f:~et <KB> o- ~ ' Drawn ' 03/30/95 m m mm Too- - ', . Jnadr J ] ] . m mm m J ~ mmm ~ , . , Marker Iden~) rice'ion MD 8K8 SECTN INCLN ]400- - ~ '" A) TIE-tN/KDP 700D 6993 2~5 5.00 B) E~ 6/~00 CURVE. 7594 ~532 440 ~0.50 ; C) C~VE 6/100 776~ Z660 549 ~0.50 2300 .............. ~ ......... ~ .... D) T~ET ~ 7769 ~666 554 aO.O0 ~ E) E~ 6/100 CURVE 8069 7922 ~08 ~2,06 i ~ C~vE 6/$00 ~26 8345 B79 22.06 G) TARGET ~2 ~27 8346 879 22.00 2800 '' H) ~NO 6/100 CURVE 8543 836] 885 21.89 D C~VE 6/~00 d) 5' C~SING POINT ~2E ~7~6 ~028 22.00 J ........... K) T~GET 13 ~26 ~716 ~028 22.00 ~00 ................. ~ .... L) ~D 6/100 CU~' ~92 8778 ~05~ ~8.02 j M) BUILD 1/~00 9649 9403 ~254 · ~8.02 4200 , j N) ~ ~/100 BUILD 98~7 9590 ~3~8 20.00 : ~ ' 0) TARGET ~4 ]02~7 9966 1455 20.00 ~ i P) TO ]0247 '~966 ~455 20..00 ' ~ . . 5600 ,, ANADR!i AKA-DPC ~ . ~ NOT , ED FOR APPROV 7000 ~ J j-v~r ; m~l ~k I . .... ~C% ~ I I~i~ , , PL AN I ~. I : ~]~_ _ ......... , . 7700--- I ~oo gSO0 I ~o5oo .................. . ...... ~ ! . 0 700 {400 - Section Depactune , ..... . ......... (~nadrill (c)93 4431;Pi 81.52 20:38 ~ l) C~l '~1 ~PTt~t~t~CCl).T nj -1-1INCIUNU WO~4 90: IT qBGT-O£-~UW 03/30/95 ~age 2 STATION IDENTIFICATION ~ND 6/loo cu~w ~w ~ / ~o o CASING POINT ~ND 6 / i 0 0 CUm/E 3UILD 1/100 . ~ND 1/lO0 BUILD CARGET ~4 MEAS DEPTH 8526 8527 8543 8920 8926 8926 8992 9649 9649 9700 9800 9847 10247 10247 INCLN ANGLE 22.06 22.00 21.89 21,89 22.00 22,00 18.02 18,02 18.02 18.53 19.53 20.00 20.00 20.00 DIRECTION AZIMUTH 287,20 287.20 289.70 289.70 290.56 PROPOSED WELL pRoFILE VERT-DRPTHS ~ECT BKB SUB=S DIST 8345 8229 879 8346 8230 879 8361 8245 885 8711 8595 1026 8716 8600 1028 290.56 8716 8600 1028 390,56 8778 8662 105k 290,56 9403 938V 1~54 290,56 9403 9287 1254 290,56 9452 9336 1270 290.56 9546 9430 130~ 290.56 9590 9474 1318 290 , 56 9966 9850 1455 290,56 9966 9850 1455 RELATIVE-COORDINATES FROM-THE-WELLHEAD 290,88 N 829,63 291,00 N 830.00 292,85 N 835,56 340.27 N 968.01 341.00 N 970.00 341.00 N 970.00 348.9~ N 991,24 420,33 N 1181,5~ 420.33 N 1181.~5 425,95 N 1196,54 437.40 N 1227.07 442.96 N 1241.90 491.00 N 1370.00 491.00 N 1370.00 STATE-PLANE TOOL DL/ X Y FACE 100 231964.98 1486156.20 LS 0.00 2~1964.61 2486156.~2 98R 6.00 231959.10 2486158.30 6.00 231827,76 2486~08,72 71R 0,00 231825.79 2486209,50 LS 6.00 231825.79 2486209.50 LS 231804,7¢'2486217,95 231616.10 2486293,63 231616.10 2486293.63 HS 251601.25 2486299.59 HS 231570.99 2486311.73 2315'56,29 2486317.63 231429,32 2486368,59 231429,32 2486368,57 HS 6.00 6.00' O. O0 0.00 1.00 1.00 1.00 0,00 0.00 I I ANADRILL AKA-DFC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN ' ~HELL WESTERN E~ P INC" ' ii i i i ii i , i I _ i i ~ A43..-~ I'LW VERTICAL SECTIiON VI'EW- · - Section at: 290:.56 TVD Scale.' ~ inch = ~00 69oo- Dap Scale · ! inch : 400 feet ?~00' v--- I ' I awn : 0 0 .......... " · ,"" "" ! [. · ..... ,"' i"l'~'~c/'~/sc~2¢~,.g~c' - ~__ I ,.~ ~ [ Marker Identification MD ~BKB SECTN IN~N I ~ i m ~[~-m/KoP 7oo0 6~ 2~$ 5.oo I I B) END 6/100 CURVE 7594 ~532 440 40.50 i C) CURVE G/lO0 7761 ~660 549 4o.OO ) .............. ' B ~~ ' .~ DD TARGET ~1 7769 i666 554 40.00 "~~ I E) END 6/100 CURVE B069 ~922 708 22.06 ; I Fi CURVE 6/~00 ~2~ ~5 B79 , , ~ ,) ENOU~O0 Cu,vE m~ ~ eB~ e~.~ · '~ I) CURVE 6/100 ~20 ~71~ 1026 2~.89 , J~ $"C~S~N~PO~N~ ag~ ~?m ~o~ ~.oo ) .... ~ ..... i... ', ... . - ~ ~)T~GET ~ Bg~ ~?~ ~0~ e~.O0 I : ' M) BU[LO ]/~00 g64g 9403 1254 J8.02 )--- ' " O) TARGET t4 10~47 ~966 1455 20.00 " k P) TO ~0247 ~966 1455 20.00 I ,, , .......................... ,. .= ....... , .... = ....... t ~ -- I-.' ' ~' ~ [ , AN~kDR[LLA~-DPC ,,, m ~_ N,DT/,PPRDVE ) FOR ....... , ......... k. ....... t¢-...¢ ~ ...... :~:~HT,~,,_. ~=.,~, .- ~ · ~ ', ;"' ~~, · - ,...-. ....... ~¢~. ~.~ ~_ .... ' .........~ I ;m~¢°~ ' ' git &Gas ton~ ~ ' ~ ' I J ~ ' .................. ~ ~ ,, .~ ..,~ ~ ~ -400 -200 0 200 400 600 800 tO00 1200 . t400 t600 : t800 2000 2~00 2~00 , SBction Departure (,~2atLP=ml) (r:.lR.'t ~.4R'l:Pi Ri ,~2 ".f)."=,A ,Ntl nm qqT~OMN~ WON~ ~O:TT SGGT-O£-~UW '1 i i ~ ii i ii _ i i ii i i i Jll iii __ A43-t LW'(Pl) .~ PLAN VIEW CLOSURE ' 1455 teet at Azimuth 289.72 } i J : OECL INAT ION.' 22.652 E j, { ~{ i {' SCALE ' I inch = 200 feet · ...... I I i i A} 1'IE-IN/KOP 7000 84 198 ~ ~ ~ B~ END 6/100 CraVE 7594 ~53 4t.2 ~ i , I , cl CURVE 6/1~ 776~ I ~ I ; ' H) E~ 6/~00 CURV[ 8543 ~3 836 ....... i' ' ~ ................ I) C~RV[ 6/~00 89~ ~ ~[ 5' CASING POINT eg~ ; , ,,~ IARGET ~3 B926 34~ 970 LI END O/tO0 CUHVE BD92 , Mt BUILD t/tOO 96~9 ' '1 ; "1 END I/!00 BUILD 9847 I I OJ TARGE1 ,4 ,0247 49~ ,370 [ ' D ' ~ ' P) lO 10247 49, 1370 ~ -- I - '" ~ ~.. ~.__, .... : ............ ~ "~ ~ ; r~ , ~ '~E ~~'~-- ...... ~ ..... ~~ I : , o :; r A~ :ADRI~[ AK/,_DDt_, _ ._ , ' ~.. ~ .... ......... i .... . ..... ,..,._.._._....._.._._: .._..__.._.._ ....... - ..................... i ........ --=-.:- ".'~:"'~'~": ...... : .:~~. ': ....... ~::'-':'": .... -'"'"-~ o;.-- .. ~XEC~TION,, ..... PLAN ,,,,~ ........ ,_: : ..... : .... O- - j r ~ .... : _~_ _ ; , KB 1700 1600 1500 1400 1300 1~0 IlO0 tO00 n~a ~n 7nn nnn ~oo 400 300 ~0 100 0 I0~ <- NES~ ' EAS~ IA~ri)l Ici~3 ~43tlPl B1.5~ 10:37 AM !} i Ii i i .i~ i 6~'-- ooq , Ll~gr/8_ Facsimile Cover Sheet SHELL WESTERN E&P INC. WESTERN ASSET Company; Phone: Fax: From: Compa~',¥; Phone:. Fax: Da~e: Pages inctu_dln9 this page: Crummy. nm' Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. BOX 576 Houston, TX 77001 April 4, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF FORM 10-401 - APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOAL LATERAL DRAINHOLE WELL NO. A43-11 LW Enclosed, in triplicate, is the Application for Permit to Drill a lateral drainhole from Middle Ground Shoal Well No. A43-11 (AP! No. 10082-00). The lateral drainhole will be named A43-11LW. Operations are scheduled to begin approximately May 1, 1995. Note that the A43-11LW lateral will be the third oil completion in the southeast quarter section of Section 11, TSN, R13W. SWEPI hereby requests a variance from Rule 1 (b) of Conserva- tion Order #44 by way of Administrative Approval (Rule 6). If you have any questions or wish to discuss, please call Jeff Wahleithner at (713) 544-3344 or Bert Coxe at (713) 544-2235. Sincerely, ~ i~ ' ' ~,. ~. ~.~Nady Manager - Asset Administration Western Asset Enclosures AK401 .DOC- 1 RECEIVED APR 1 1 1995 Alaska 0il & Gas Cons. Commission Anchora ~, ./ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY, APPROVALS 1. Type of Request: Abandon X Suspend After casing ~ Repair well Change approved program ~ Operation shutdown Re-enter suspended well Plugging, Time extension ~ Stimulate~ Pull tubing ~ Variance Perforate Other 2. Name of Operator Shell Western E&P Inc. 3. Address P.O. BOX 576, Houston, TX 77001-0576 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 1628' FSL & 430' FEL Sll, TaN, P,13N, S.H. At top of productive Interval 8314' HD-KB, 8298' 1'VD-KB:1707' FSL& 782' FEL Sl1, T8N, P,13N,S.H. At effective depth 8700' HD-KB, 8675' 'I'VD-KB; 1735' FSL& 857' FEL Sl1, T8N, P,13N,S.H. At total depth 8798' HD-KB, 8771' TVD-KB; 1744' FSL& 878' FEL Sll, T8N, P,13N,S.H. 6. Datum elevation (DF or KB) 116' KB feet 7. Unit or Property name HIDDLE GROUND SHOAL 8. Well number A43-11 9. Permit number 10. APl number so- 733-10082 11. Field/Pool HIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 319' Surface 1609' Intermediate Production 8798' Liner 1635' Perforation depth: measured 8798 feet 8771 feet 8700 feet 8675 feet Size 24" 13-3/8" 7" 5" 8314' - 8609' true vertical 8298' - 8587' Tu~ng (size, grade, and measured depth) 2-7/8", 6.5~, N-80 EUE 8RD e 7184' HD-KB Packers and SSSV (type and measured depth) TIH SEAL UNIT ASSEMBLY ~ 7113' MD-KB Plugs (measured) Junk (measured) Cemented 1925 5X 1500 SX 126 SX Measured depth 319' 1609' 8798" 7100' - 8735' True vertical depth 319' 1609' 8771' 7093' - 8709' REEEIVED APR 2 4 1995 AIBska 0il & Gas Cons. Commission Anchora~¢, 13, Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation HAY 1, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended 17. I hereby certify that the foregoing is true end correct to the best of my knowledge. fl~uv_.,~]/~..~ '~ ,~,'! G. S. NADY Tit,e HGR ASSET ADHIN. Signed ~' ' I ' {. - ~ //~ I FOR COMMISSION USE ONLY Date 4/17/95 Conditions of approval: Notify Commission so representative may witness Plug Integrity / BOP Test ,"" Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Original Signed By David W. Johnston ' o77 Approved Copy Returned . Co)'nm~ssiOner' uate Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE vi/ELL PERMIT CHECKLIST GEOL AREA ADMINISTRATION ENGINEERING 1. Permit fee attached ................... .(Y~ N 2. Lease number appropriate ............... ~ N 3. Unique well name and number .............. Y N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ...... Y ~ 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. .~ 10. Operator has appropriate bond in force. ........ ~ ~ N 11. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval...Y 13. Can permit be approved before 15-day wait ....... [4. Conductor str±ng provided ................ 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23 If diverter required, is it adequate. 24. Drilling fluid program schematic & equip list adequate 25. BOPES adequate ..................... 26. BOPE press rating adequate; t&st to ~C~ psig.~ 27. Choke manifold complies w/API RP-53 (--~ay~.--~... 28. Work will occur without operation shutdown ....... 29. Is presence of E2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. Data presented on potential overpressure zones ..... Y /~/ 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ~'Y N 34. Contact name/phone for weekly progress reports .... ,"'. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: "V/jo - A:~ORMS~cheklist rev 03/94 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. _TS TAP~ ~EL ,~Z LI~ TA SCAN RECEIVEO PV V V V