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Home My WebLink About166-015 STATE OF ALASKA ►�l�s� ALASKA AND GAS CONSERVATION COMMIS80 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L Repair Well L Plug Perforations L Stimulate 2 Other Y G0 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: p 9Y \ Name: Development ❑� Exploratory ❑ 66- 15/94 -105 3. Address: 200 N. Loraine, Suite 800, Midland, Tx 79701 Stratigraphic❑ Service ❑ 6. API Number: v 50- 733 - 10079 -61 -00 7. Propely Designation (Lease Number): 8. Well Name and Number: ADL 18754 Middle Ground Shoal #A13 -01 LN 9. Field /kool(s): c L—+ MGS E, F, G Oil Pool P►� �JFJ + 0/ �! 10. Present Well Condition Summary: Total Depth measured 12,641 feet Plugs measured feet true vertical 9,911.00 feet Junk measured feet Effective Depth measured feet Packer' acker"" ° measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,280' 13 -3/8" 2,280'! jup NG� CO Intermediate 9,040' 9 -5/8" 9,040' I I Production 2,949' T' 7,762' - 10,711' Liner 1,989' 4 -1/2" 10,652' - 12,41' 2 1, Perforation depth Measured depth 9,203' 12,241' feet ` at&CO��n True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 3- 1/2 ",9.3 #,N -80 9,142' Packers and SSSV (type, measured and true vertical depth) Baker FHL 9,060' 11. Stimulation or cement squeeze summary: Intervals treated (measured): 9,203'- 12,400' Treatment descriptions including volumes used and final pressure See attached daily report. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf I Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 43 139 1138 1675 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations Attached 15. Well Status after work: Oil Gas L WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1 310-220 Contact Paul Figel, Engr. - Tel. N o. 432 - 620 -6743 Printed Name Maria Perez Title Regulatory An Signature �� Phone 432 - 620 -4325 D at e 10/18/2010 Form 10 -404 Revised 10/2010 RBDMS OCT 2 6 "! Submit Original Only j • Review Well Chronolgy • T Well Name: Middle Ground Shoal A13 -01 LN ENERGY ® API /UWI XTO Well ID Number District Area Field Name State County 5073310079 62214 South Permian Alaska Middle G round S ho al Al Kenai Peninsula Spud Date Ong KB Elev (ft) Ground Elevation (ft) KB- Ground Distance (ft) Location 4 /15/196 6 11 6.00 ---- - - - - -- - - - -- AFE Number AFE Type Total AFE Amount Total Field Estimated Cost AFE -Field Estimate 1001349 Remedial Workove ev;1 4 500,000.00 397,907.00 102,093.00 Rig Rig Number Rig Start Date Rig Type Daily O erations I Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 1.0 8/10/2010 8/11/2010 8,275.00 8,275.00 Lay hard line f/ A13 -01 LN to pti tank. Rig up Schlumberger coil tbg unit on A13 -01 LN Test BOP'S & lines to 250 & 5000 psi (Bob Noble w/ state of Alaska waived witnessing BOP test) P/u scale blaster - RIH 80 fpm .5 bpm pumping slick 3% KCL FIW 800 psi. Wash ea. GLM 3 times slow. Start washing 7" liner 10 fpm 1.3 bpm 3950 psi (Had some trouble getting into 4 1/2" Slotted @ 10662' CT depth. Wash to 10840' Injector started leaking on CT. POH tighten hydr. hose & change out packing. cmic Larry Driskill — --- -otal - --- cost t -- -- - - -- - - -- -- - -- n --- --- ---- - - - -- Rpt No. Start Date Report End Date Daily Cost T Cum Cos To Date Operaio Summary # 1 2.0 8/11/2010 8/12/2010 8,275.00 16,550.00 RIH w scale blaster (Did not see 4 1/2" liner top) Started pumping beads @ 4 1/2 LT. Hit bridge @ 10936' PUH to 10700' unable to get beads going due to filters & lines plugging. Went to slick 3% KCL FIW, Clean out to 12500, hole got tight. Work back to 12050, pump 10 bbl Flo -Vis pill PUH pipe free @ 12000', Pull to 9100' pump 10 bbl Flo -Vis, RIH @ 30 fpm w/ slick 3% KCL FIW. No bridges in 7" liner Had to shut do pump to get into 4 1/2 liner top, run thru 4 1/2" liner @ 17 fpm 1.1 bpm 3500 psi. Tag fill @ 12420' cmic Larry Driskill Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 3.0 8/12/2010 8/13/2010 8,275.00 24,825.00 Clean out fill f/12420' w/ slick 3% KCL FIW @ 2 to 4 fpm 1.13 bpm @ 3950 psi. CT stuck @ 12447' - Pump (3) 10 bbl flozan gel pills before coming free - PUH to 4 1/2 liner top @ 10662' started pumping beads to 11700' pressure went to 4000 psi @ .5 bpm. pump 2 acid pills, didn't help POH found inline filter plugged & ruptured disk missing, broke do tool found disk in jet nozzle. Change out scale blaster w/ 1.85 OD drift ring. RIH pumping slick 3% KCL FIW. At 11500' start pumping Xanthan gel containing 2.5% by wt. sterling beads @ 1.4 bpm 3100 psi @ 10 fpm cmic Larry Driskill Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 4.0 8/13/2010 8/14/2010 8,275.00 33,100.00 Finish pumping 100 bbl Xanthan gel containing 2.5% by wt sterling beads f/ 11500' to 12400'- Displace beads w/ 40 bbl flozan pill followed by 150 bbl slick 3% KCL FIW @ 1.2 bpm - Pump 30 bbl 10% DAD acid f/ 12350 to 10706' displace w/ 3% slick KCL FIW PUH to 10500 let soak for 30 min. Attempt to go in hole, unable to get into 4 1/2" Liner. PUH to 9100' Mix up 2# per bbl Flo -Vis - Cir back to 12514. Acid wash slotted liner f/ 12400' to 10706 w/ 32 bbl of 10% DAD acid @ .5 bpm @ 30 fpm & 12 bbl across 5 sets of perfs f/ 10311 to 9203'@ same rate. RIH to 12400'@ 50 fpm while pumping 2# per bbl Flo -Vis. At 12400 cir 50 bbl of 2# per bbl Flo -Vis & 100 bbl of 3% KCL FIW. SI the CT annulus start injecting 350 bbl of 10% DAD acid, make 1 pass across slotted liner f/ 12400 to 10706' & across 7" perfs 10311 to 9203' while pumping .7 -.9 bpm, 3300 to 3600 psi 500 to 1300 WH psi, Moving CT @ 2 -6 fpm cmic Larry Driskill Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 5.0 8/14/2010 8/15/2010 33,100.00 Finish Acid squeeze. Mix & pump 100 gal Nalco FC6085 Scale Inhibitor in 350 bbl of 3% KCL FIW. @ .6 to .8 bpm 3600 psiWhile making 2 passes across the 7" liner perfs 9203 to 10311' & 4 1/2 "slotted liner f/ 10706 to 12400'- Open CT annulus - POH w/ CT- Rig do Schlumberger. Start Gas lifting, taking returns to PTS tank cmic Larry Driskll Rpl No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 6.0 8/15/2010 8/16/2010 364,807.00 397,907.00 Blow do coil w/ nitrogen, Rig do Schlumberger CT unit, BOP'S & lubricator. Put production choke on & line to PTS tank out top of tree. Flow well into PTS tank, Turn on gas lift & monitor well, While cleaning pits & preparing to move Equipt to on shore & Platefom C (Boat Monday) cmic Larry Driskill Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 7.0 8/18/2010 8/19/2010 397,907.00 Cont to flow well into PTS tank. Have recovered 1270 bbl. Csg press @ 665 psi. pH of fluid @ 4.7. Rot No Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 8.0 8/20/2 8 /21/2010 397,90 Fluid @ 5.2 pH. F well in p rod header. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Dale Operation Summary # 1 9.0 8/22/2010 8/23/2010 397,907.00 Put well in test. 42 BO, 245 BW. Inj gas @ 1408 mcf. Csg press @ 625 psi. Lifting on orifice. www.xtoenergy.com Page 213 Report Printed: 10/18/2010 T� Review Well Chronolgy • E N E R G Y Well Name: Middle Ground Shoal A13 -01 LN API /UWI XTO Well ID Number District Area Field Name State County 50733100 62214 South P ermian Alaska Middle Ground Shoal Alaska Kenai Peninsula Spud Date Ong KB Elev (ft) Ground Elevation (ft) KB- Ground Distance (ft) Location 4/15/1966 6_00 i Daily Operations Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 10.0 8/28/2010 8/29/2010 397,907.00 Well Test: 49 BO & 181 BW. Inj 1132 MCF lift gas. Csg P @ 5 80 psi. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 11.0 9/2/2010 9/3/2010 397,907.00 Well Test: 44 BO & 148 BW. Lift Gas @ 1135 MCF. Csg Press @ 5 7_5 psi. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 12.0 9/7/2010 9/8/2010 397,907.00 Well Test: 43 BO & 147 B Lift Gas @ 1207 MCF. Csg press @ 675 psi. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 13.0 9/12/2010 9/16/2010 397,907.00 Well SI due to CB1 down. Rpt No, Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 14.0 9/16/2010 9/17/2010 397,907.00 Rtn ga lift. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 15.0 9/17/2010 9/18/2010 397,907.00 Well test: 38 BO & 163 BW. Inj Gas @ 1354. Csg Press @ 710 psi. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 16.0 9129/2010 9130/2010 397,907.00 Well Test: 43 BO, 138 BW & 139 MCF. Inj gas 1126 MCF. Csg Press @ 675 psi. FINAL RE PORT. i I I i I� it i i i i' i i I www.xtoenergy.com Page 3/3 Report Printed: 10/18/2010 E E R G Y Current Completion PLF 7 -19 -10 MGS A13 -01 LN KB: 38' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 8 Tbg: 3 1/2" 9.2# N80 BTC @ 9,142' API No.: 50- 733 - 10079 -61 Set 10 -15 -94 Spud Original A13 -01: 4 -15 -66 Sidetrack LN: 8 -28 -94 24" Conductor Csg @ 319' GLM MD TVD PORT Psc Pso #1 2020 1887 12 900 950 Surf Csg: 13 3/8" 61 #. Set @ 2,280'. #2 4153 3249 12 880 915 #3 5612 4200 12 860 887 Cmt w/ 3,420 sk. #4 6854 5042 16 835 876 #5 7742 5748 16 815 846 #6 8444 6352 20 790 822 #7 8979 6824 20 Orifice Intermediate Csg: 9 5/8 ". Window @ 8,803'. (Original set @ 9,040') Cmt w/ 1,400 sk. Surf - 123' : 47# P110 Baker "FV -6" SSV (2.813" ID) @ 310' 123 - 5,132' : 40# N80 Otis X Nipple (2.75" ID) @ 9,025' 5,132 - 6,594' : 43.5# N80 1 Jt 3 1/2" 9.2# N80 BTC 6,594 - 7,837' : 47# N80 Baker "FHL" Packer @ 9,060' 7,837 - 9,040' : 47# P110 1 Jt 3 1/2" 9.2# N80 BTC Otis XN Nipple (2.625" ID) @ 9,107' 1 Jt 3 1/2" 9.2# N80 BTC Baker WL REG @ 9,142' Drilling Liner: 7" 26# L80 LTC @ 10,706'. TOL @ 7,762'. Cmt w/ 700 sk. Baker Hy -Flo Hangar @ 7,762' Perf w/ 6 spf: 9 5/8" Isolation PKR @ 7,749' GN -GO: 9,203 - 29' GR -HC: 9,604 - 18' GR -HC: 9,630 - 60' GR -HC: 9,844 - 57' HE -HF: 10,262 - 311' A13- 01LN(1) TD @ 13,417' was Plugged Back from 11,229 - 11,879 w/ 120 sx. Redrill 6" OH for A13 -01 LN(2). 92894 Slotted Liner from: HK HR Slotted Prod Liner: 4 1/2" 11.6# N80 BTC Set @ 12,641'. TOL @ 10,652'. Baker Hy -Flog Hangar FILL: 12,424' MD (7- 13 -10) TD: 12,641' MD (9,911' TVD) ~ • • ~~Q~[~ 0~ Q~Q~~Q /,~,..,E..~o~~ Maria Perez Regulatory Analyst ~ .; ~ ~ ~ ~ XTO Energy, Inc. ~,:j~~~i~;. <,I,1F.~ = ~ °~ 200 N. Loraine, Suite 800 ~~~' 1'' Midland, TX 79701 Re: MGS Field, MGS E, F, G Oil Pool, MGS A13-OlLN Sundry Number: 310-220 Dear Ms. Perez: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. DATED this ~~ay of July, 2010. Encl. • TO ENERGY July 20, 2010 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7~' Ave., Suite 100 Anchorage, Alaska 99501 Re: Form 10-403, Request for Sundry approval Objective: Coil tbg clean out barium scale and acid stimulation.. Middle Ground Shoal #A13-O1LN `b~ ~ Q ~ Jr' MGS E, F, G Oil Pool - _ Cook Inlet, Alaska API 50-733-10079-61-00 XTO Energy Inc. hereby submits its Application for Sundry Approval for coil tbg clean ~ out barium scale and acid stimulation. Attached is the following information for your files: 1. Form 10-403 Application for Sundry Approval. 2. Proposed job procedure. 3. Present wellbore schematic If you required additional information, please contact me at A/C 432-620-4325. Sincerely, ~~ Maria L. Perez, Regulatory Analyst Copy to: Paul Figel, Engineering Manager 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 • ~~~Y~{.~ J~~~ 2 ~ zoo STATE OF ALASKA ~,~~~~~ ~'{ ~ ~j~ Cam, ~,~~jggj~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~nchjr~ge APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ® ~ Alter Casing ^ Other: ^ 2. Operator Name: 4. Current Well Class: nni~F Drill Number. XTO Ener Inc. Development ® Exploratory ^ 66-15 94-105 3. Address: 200 N. Loraine, Suite 800 Stratigraphic ^ service ^ ~ ber: Midland, Texas 79701 so- 733-10079-61-00 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 ® Middle Ground Shoal A13-O1LN ` 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 18754 ~ MGS E, F. G Oil Pool 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): 12 641' ~ 9,911' • 12,463' Casing Length Size MD TVD Burst Collapse Structural Conductor surface 2280' 13-3/8" 2280' Intermediate 9040' 9-5 8" 9040' Production 2 ' 7" 7762'-10 7 11' Liner 1989' 4-1 2" 10 652'-12 241' Perforatiq~ De th MD ft~: Perforation Depth TVD (ft): 1 0 Tubing Size: Tubing Grade: Tubing MD (ft): 1 P rfs ,3 ,203 -1 10 652'-12 241' lotted Liner ~ 3-1/2" 9.2;'~ N80 BTC 9142' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FHL 9060' 12. Attachments: Description Summary of Proposal ® 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Au uSt 1St thru 25th, 2010 Oil ® Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Maria Perez Title Re ulator Anal st Signature Phone Date 432-620-4325 7/20/2010 COMMISSION USE ONLY Sundry Numb ti it t er , ~ a~~ ~ . . ness ve may w a Conditions of approval: Notify Commission so that a represen Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ Other. ~ ~ S'~ ~ ~ ~ ~`' t0 SO ~ D ~ s..t, , Subsequent Form Required: ~ ~ _ ~ p APPROVED BY ^~~~~ Approved by: MMISSIONER THE COMMISSION Date: Form 10-403 RevisedDl/2 ~~ J o(~ ~,~~ ~~ubmit i~~p~ to ~RiG1NA~ F ~`a,,~ o ` \ ~,Zt/t~4o • • ~~ ENERGY XTO Energy Inc. MGS A13-O1LN COOK INLET, ALASKA Coil TBG Acid Stimulation Procedure • WELL DATA: SURFACE CASING: 13 3/8" 61#. Set @ 2,280'. Cmt w/ 3420 sx. INTERMEDIATE CASING: 9-5/8" 40-47#, N80 & P110 Cmt'd w/ 1400 sx. Window for current well cut @ 8,803' DRILLING LINER: 7" 26#, L80, LTC @ 7,762 - 10,706'. Cmt w/ 700 sx. SLOTTED PROD LINER: 4-1/2" 11.6# N80 BTC 10,652 - 12,641' TUBING: 3-1/2" 9.3# N80 BTC @ 9,142' Baker FV-6 SSSV @ 310' (2.813" ID) Otis X Nipple @ 9025' Baker FHL Pkr @ 9060' Otis XN Nipple @ 9107' (2.625" ID) Baker WL REG @ 9142' PERFORATIONS: GN-G0:9203-29' GR-HC: 9604-18' GR-HC: 9630-60' GR-HC: 9844-57' HE-HF: 10,262 - 311' OPEN HOLE: 10,706 - 12,641' BHST: 168 Deg F BHP: 2700 psi (estimated) MAX DEVIATION: 53 deg @ 3800' SMALLEST ID: 2.625" @ 9107' XN Nipple PRESENT STATUS: Prod @ 59 BOPD, 113 BWPD OBJECTIVE: Coil tbg clean out Barium Scale & Acid Stimulation. • Last WL run on 7-13-10 encountered scale @ 12,424'. • AFE # 1001349 • Heat FIW to f100°F • SD gas lift 2-3 days prior to MIRU CTU. 7-19-10 • XTO Energy Inc. MGS A13-O1LN i 2 Materials Required: • 20,000 gal (476 bbl)10% HCL DAD Acid (25% xylene) • 500 bbl Gel Pill (2#/bbl Flozan + 3 gal Myacide GA25) (Provided by MI) • 1200 bb13%KCL FIW Water - 100 gal J313 Friction Reducer (SLB) - 12,000 lbs Powdered KCL (10001bs KCL /100 bbl FIW for 3%) (Provided by MI) • N2 bottles to purge reel after job or N2 unit • 3,000 lbs Soda Ash (Provided by MI) • 100 gal Nalco EC6085 Scale Inhibitor Equipment Required: • 1.5" CTU • 1 ea HP Triplex Pump • Filter Skid (3-5 micron) • SLB to Provide Acid Tanks: 2 ea 5000 gal & 5 ea 2000 gal. • 250 bbl PTS Flowback Tank - Mud Pump to be tied into tank to pump load to A44-11 Disposal Well - Insta112" line from tank top to production header for gas lift @ EOJ • Return line w/choke manifold to 250 bbl PTS Tank & to Production Facilities - Manifold to contain a sample catcher to monitor fluids pH - Send "clean" returns to Production Facilities - Send live acid and or fluids containing scale or solids to PTS Flowback Tank DAD Acid System to contain these additives: • 10% HCL • 250 gpt Xylene • 5 gpt A261 Corrosion Inhibitor • 8 ppt A153 Inhibitor Aid • 20 gpt L58 Iron Reducer • 4 ppt A179 Inhibitor Aid • 15 gpt U74 Dispersing Agent • 5 gpt W60 Anti-sludge • 5 gpt W54 Non-Emulsifier • 2 gpt F 103 Surfactant 7-19-10 ' 4 t • XTO Energy Inc. MGS A13-O1LN PROCEDURE: 1. MIRU Schlumberger 1.5" Coil Tbg Unit. RU a filter skid between the mud pits & HP triplex. RU the PTS tank to handle all returns. Install press gauges on the CT, CT Annulus, & 3-1/2" prod tbg annulus. e~up ScaleBlaster Tool. Contact the AOGCC 24 hrs prior to BOP test. Press test all lines & BOP's to / ,0 psi. Max Press = 4,000 psi. CTU operator to ensure all tools to be calipered before RIH. Smallest - 2.625" XN Nipple @ 9107'. 2. Conduct a pre job safety meeting with all SLB & XTO platform personnel. CLEAN OUT HOLE: 3. Open the CT annulus. RIH w/ CT @ 80 fpm while pumping @ 0.5 BPM slick 3% KCL FIW. Slow rate to 5 fpm when passing over the 7 Gas Lift Mandrels (See Attached WBD) and make 2 passes. Cont DH to EOT @ 9142'. 4. Once in the 7" Csg, Jet Wash the perfs: 9203 - 29', 9604 -18', 9630 - 60', 9844 - 57' & 10,262 -311' @ 10 fpm @ 1.4 BPM w/ slick 3%FIW. Use acid only when necessary to get past tight spots. Increase CT rate & decrease pump rate across blank pipe. 5. Once in the 4-1/2" Slotted Liner, switch to xanthan gel containing 2.5% by wt Sterling beads. Keep CT rate @ f 10 fpm & pump rate @ 1.4 BPM. Wash down to top of fill @ 12,424' . Lower CT rate to ~6 fpm & try to wash through fill to TD of 12,641'. 6. Tag up @ TD (12,641'). Circ hole clean w/ 20 bbl Flozan pill followed with 150 bbl slick 3%FIW @ max BPM. ACID SPOT & SOAK: 7. Lay 1300 gal (30 bbl) 10% DAD acid from 12,641 to 10,706' while PUH using slick 3% FIW to displace. PU CT to 10,500' & SD. Let acid soak for 30 min. 8. RIH @ 30 fpm to 12,641' while Circ slick 3%FIW @ 1 BPM. At 12,641' pump 20 bbl Flozan pill followed with 40 bbl slick 3%FIW. ACID WASH PERF'S: 9. Acid wash the slotted liner from 12,641' to 10,706 with 1350 gal (32 bbl) 10% DAD acid @ 0.5 BPM, moving the CT @ 30 ft/min. Cont PUH to perfs in 7". Use a total of 500 gal (12 bbl) acid to jet wash the 5 sets of perfs from 10,311 - 9203'. SD pumping while pulling between perf sets. 10. RIH to 12,641' @ 50 fpm while pumping 3%FIW @ 0.5 BPM. Circ hole clean w/ 20 bbl Flozan gel pill followed with 150 bbl slick 3%FIW @ 1BPM. Do NOT mix any friction reducer to FIW beyond this step. 7-19-10 i . XTO Energy Inc. MGS A13=01LN q ACID INJECTION JOB: 11. SI the CT annulus. Inject 14,000 gal (333 bbl) (Leave 2600 gal Acid for Perfs) 10% DAD acid while making 1 pass across slotted liner from 12,641 to 10,706' while pumping @ 0.5 BPM and moving the CT as slow as possible ~3-5 ft/min. SD pumping acid @ 10,706'. 12. PUH to perfs in 7" csg. Keep CT annulus closed & inj acid per schedule: ZONES Interval Net Pa Acid Vol, Gal Acid Vol, BBL HE-HF 10262. - 311' 49 900 21.4 GR-HC 3 9844 - 57' 13 300 7.1 GR-HC 2 9630 - 60' 30 600 14.3 GR-HC 1 9604 - 18' 14 300 7.1 GN-GO 9203 - 29' 26 500 11.9 Total 2600 61.9 13. Mix 100 gal Nalco EC6085 Scale Inhibitor in 350 bbl 3% KCL FIW (no friction reducer). Over displace acid with 350 bbl 3%FIW + Scale Inhibitor while making 2 passes across the perfs 9203 -10,262' & slotted liner 10,706 - 12,641'pumping @ 0.5 BPM and moving the CT as slow as possible ~5 ft/min. 14. Open CT annulus. POOH with coil tbg @ 100 fpm. Close the Swab valve. Bleed off press. RD CTU. 15. Slowly start up gas lift taking returns to the PTS tank. Cont to flow into PTS tank until pH is neutral (7). Switch returns into production header & start testing well. Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. Paul Figel Engineering Manager Kyle Hammond Vice President Operations 7-19-10 ~ - ~~ EitiERGY Current Completion PLF 7-19-10 MGS A13-01 LN Cook Inlet, Alaska Leg 1, Conductor 8 API No.: 50-733-10079-61 Spud Original A13-01:4-15-66 Sidetrack LN: 8-28-94 24" Conductor Csg @ 319' Surf Csg: 13 3/8" 61#. Set @ 2,280'. Cmt w/ 3,420 sk. Intermediate Csg: 9 5/8". Window @ 8,803'. ~%~ (Original set @ 9,040') Cmt w/ 1,400 sk. Surf - 123' : 47# P110 123 - 5,132' : 40# N80 5,132 - 6,594' :43.5# N80 6,594 - 7,837' : 47# N80 7,837 - 9,040' : 47# P110 Drilling Liner: 7" 26# L80 LTC @ 10,706'. TOL @ 7,762'. Cmt w/ 700 sk. Baker Hy-Flo Hangar @ 7,762' 9 5/8" Isolation PKR @ 7,749' A13-01LN(1) TD @ 13,417' was Plugged Back from 11,229 -11,879 w/ 120 sx. Redrill 6" OH forA13-01LN(2). 9-28-94 Slotted Prod Liner: 4 1/2" 11.6# N80 BTC Set @ 12,641'. TOL @ 10,652'. Baker Hy-FIo2 Hangar /~ KB: 38' Water Depth: 73' MSL Tbg: 3 1 /2" 9.2# N80 BTC @ 9,142' Set 10-15-94 GLM MD TVD PORT Psc Pso #1 2020 1887 12 900 950 #2 4153 3249 12 880 915 #3 5612 4200 12 860 887 #4 6854 5042 16 835 876 #5 7742 5748 16 815 846 #6 8444 6352 20 790 822 #7 8979 6824 20 Orifice Baker "FV-6" SSV (2.813" ID) @ 310' Otis X Nipple (2.75" ID) @ 9,025' 1 Jt 3 1 /2" 9.2# N80 BTC Baker "FHL" Packer @ 9,060' ~~ 1 Jt 3 1 /2" 9.2# N80 BTC Otis XN Nipple (2.625" ID) @ 9,107' 1 Jt 3 1/2" 9.2# N80 BTC Baker WL REG @ 9,142' Perf w/ 6 spf: GN-GO: 9,203 - 29' GR-HC: 9,604 - 18' GR-HC: 9,630 - 60' GR-HC: 9,844 - 57' HE-HF: 10,262 - 311' Slotted Liner from: HK-HR FILL: 12,424' MD (7-13-10) TD: 12,641' MD (9,911' TVD) . . MGS FIELD WELLS CHANGE WELL STATUS FOR WELLS WITH LATERALS FEBRUARY 16, 2006 The following wells status was changed from SQZED to I-OIL. These wells had laterals drilled against them and production was assigned to all laterals in Cook Inlet when the wells were first drilled. Since then, AOGCC changed the policy about lateral wells and assigning production against lateral API numbers. This policy is like the lateral wells on the North Slope. Today I notice wells producing in the MGS field with a status not conducive to the well status and changed it to I-OIL. All the wells show oil production over the years. The status date reverted back to the date the well was completed as an oil well. The following wells were corrected: MGS A12-01 MGS A13-0l MGS A14-0l MGS A22-14 MGS A23-0lR MGS A31-l4 MGS A41-1l PERMIT 177-055 PERMIT 166-015 PERMIT 167-079 PERMIT 185-068 PERMIT 187-093 PERMIT 177-031 PERMIT 185-174 , -'.ð.~.!io&I\:,;'. ("" .!jç~~~'f!i;...\,.¿ C '5 All production has been assigned back to the original well API number, no production is assigned to a lateral well API number. 2;1 ~ /11 () fill ' > ..~A.ÆJ¿- IVlè Jt "M14û TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 4, 1999 William Miller Cross Timbers Operating Company HCO1 Box 485 Old Wik Road Kcnai, AK 99611-9704 Dear Mr. Miller, Re: Administrative Abandonment Action Middle Ground Shoal Wells A33-11 Permit # 85-235 A22-14 Permit # 85-068 Al4-01 Permit # 67-079 Al2-01 Permit # 77-055 A31-11 Permit It 77-031 A 13 -01 Permit/tr-66-015) A41-11 Permit # 85-174 This letter reflectS the lateral well that replaced the original well by well number, permit number and API number: A12-O1LN (permit # 94-120, API It 50-733-10081-62) permit was approved 9/29/94. A13-01LN (permit # 94-105, API It 50-733-10079-61) permit was approved 8/05/94. AI4-01LN (permit # 94-119, API It 50-733-20067-61) permit was approved 9/27/94. A22-14LS (permit # 94-071, API# 50-733-10085-62) permit was approved 5/13/94. A31-14LW (permit # 94-044, API It 50-733-20305-62) permit was approved 3/23/93. A33-1 ILS (permit # 93-180, API# 50-733-20383-61) permit was approved 11/30/93. A41-11LN (permit # 94-087, API# 50-733-20378-61) permit was approved 6/28/94. The replacemem well incorporates a lateral with the existing well bore. The lateral along with the original hole will be used for production of hydrocarbons. A review of both well files indicates administrative abandonment (SQZED, AOGCC stares) of the originating well bore is appropriate according to current AOGCC procedures for wells Where additional permitted laterals are drilled from an existing well bore. Production will be reported to the original APl wellbore (-00. -01 or etc) and not to the lateral API wellbore (-60, -61 or etc). 20 AAC 25.005(e) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, AOGCC databases require each conductor have only one permit number and API number. Administrative abandonment of the original permit only eliminates duplication in the databases. Information for the original well and its replacement will be maintained in their respective files until plugged and abandoned according to 20 AAC 25.105. Please notify other cognizant personnel in your organization so that the well will be correctly identified on subsequem reports and applications submitted to the Commission. Chairman Memorandum State of Alaska Oil and Gas Conservation Commission To.' Re: Well File: A33-11 Permit # 85-235 Al2-01 Permit # 77-055 Al3-01 Permit # 66-015 Al4-01 Permit # 67-079 August 04, 1999 A22-14 Permit # 85-068 A31-11 Permit # 77-031 A41-11 Permit # 85-174 Administrative Abandonment Action Middle Ground Shoal Wells This memo will remain at the front of the subject well file. The following lateral wells replaced the original wells listed above. This letter reflects the lateral well that replaced the original well by well number, permit number and api number: A12-01LN (permit # 94-120, API# 50-733-10081-62) permit was approved 9/29/94. A13-01LN (permit # 94-105, API# 50-733-10079-61) permit was approved 8/05/94. A14-01LN (permit # 94-119, API# 50-733-20067-61) permit was approved 9/27/94. A22-14LS (permit # 94-071, API# 50-733-10085-62) permit was approved 5/13/94. A31-14LW (permit # 94-044, API# 50-733-20305-62) permit was approved 3/23/93. A33-11LS (permit # 93-180, API# 50-733-20383-61) permit was approved 11/30/93. A41-11LN (permit # '94-087, API# 50-733-20378-61) permit was approVed 6/28/94. The replacement well incorporates a lateral with the existing well bore. The lateral along with the original hole will be used for production of hydrocarbons. A review of both well files indicates administrative abandonment (SQZED) of the originating well bore is appropriate according to current AOGCC procedures for wells where additional permitted laterals are drilled from an existing well bore. 20 AAC 25.005(e) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, AOGCC data bases require each conductor has only one permit number and API number. Administrative abandonment of the original permit only eliminates duplication in the databases. Information for the original well and its replacement will be maintained in their respective files. The operator has been notified of this action. new permit number, API number and well data. Statistical Technic ia~L~.~_~/~ j~ Reservoir Engineer Commissioner All future correspondence with the AOGCC should reflect the Statistical Technician Petroleum Geologist ALASKA OIL AND GAS CONSERVATION COMMISSION ~,WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 6, 1993 *Revised July 21, 1994 Paul Huckabee, Prod Engr Shell Western E&P Inc. 601 West 5th Av, Suite 800 Anchorage, AK 99501 Re: No Flow Verification MGS Well #A-13-01L PTD 66-015 Dear Mr. Huckabee: At your request, on October 1,1993 our inspector Lou Grimaldi witnessed a no-flow test on Middle Ground Shoal well A-13-01L. Gas lift to the well was shut off at 1;30 pm 10/1/93. The well was then opened to the test separator operating at atmospheric pressure. The well died and made no fluid; gas flow was estimated at 240 mcf/d. At 5:00 p.m., after observing the well as "no-flow" for 3 hours, Lou concluded that subject well was not capable of unassisted flow. Note: The short string has an SSSV nipple at 293'. The SSSV has been pulled and replaced with a modified Otis PS plug with prong (equalizing). The Commission hereby authorizes removal of the subsurface safety valve from MGS well A-13-01L on the cOndition that the low pressure sensor and surface safety valve must be maintained in good condition and, if for any reason, the well again becomes capable of unassisted flow, the subsurface safety valve must be reinstalled and maintained. Sincerely, Blair E. W~~o 'zell PI Supervisor xc: Morris Dunkley/C.V. Willoughby * This revision is necessary because the original letter dated October 6, 1993, incorrectly specified well "MGS well #A-33-1L (PTD 85-0068") as the "nO-flow" well. Please destroy the original letter and replace it with this one. MEMORANDUM ' STATE ALASKA ALAS~ OIL AND GAS CONSER VA TION COMMISSION TO: David Joh~ Chairman '~ DATE: October 4, 1993 FILE NO: 9S2JJAAB. DOC THRU: Blair Wondzell P.I. Supervisor FROM: ~ou Grimaldi Petroleum Inspector PHONE NO.: 279-1433 SUBJECT: No Flow test Shell well# A13-1L Platform "A" Middle Ground Shoal PTD # 66-15 Thursday, October 1, 1993 I verified the No flow status of Shell well # 13-1 (lower). The well had it's gas lift shut in, and opened up to the test seperator. The well died off and made no fluid, gas flow was at approximately 240 SCF per hour as observed on a four inch orifice meter with a half inch orifice plate. SUMMARY; I witnessed the successful No Flow test on Shell well # 13-1(loWer). Attachment'None ;' I ~N'M ~~d g Shell Western E&P Inc. An affiliate of Shell Oil Company 601 West Fifth Avenue Suite 800 Anchorage AK 99501 June 16, 1992 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL A13-01L Enclosed are duplicates of the Subsequent Report for the recently completed tubing soak/wash on Middle Ground Shoal well A13-01L. The work was completed on May 19, 1992. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263'-9646. Very Truly Yours, S. B. Brown-Maunder Sr. Environmental Technician Alaska Operations SBBM/dlw Enclosures RECEIVED J UN 2 2 1992 Alaska 0il & Gas Cons. CommissiOn Anchorage SBBM~061092A. WP5 REPORT OF SUNDRY WELL OPERATIONS ~1. Operations performed: Operation shutdown __ Stimulate Plugging__ Perforate Pull tubing__ Alter casing__ Repair well __ Other X 5. Type o! Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Development X 116' DF feet Exploratory 7. Unit or Property name 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 Stratigraphic Middle Ground Shoal Service 8. Well Number 4. Location of well at surface Conductor 8, Leg1, 1630'FSL and 440'FEL from SE Corner A13-01L of Sec. 11, T8N, R13W, SM 9. Permit number/approval number At top of productive interval 9159'(M.D.) 1612'FSL and 365'FWL from SW Corner of Sec. 66-15/92-121 1, T8N, R13W, SM 10. APl number At effective depth 1905'FSL and 858'FWL from SW Corner of Sec. 1 T8N, 50-733-10079-00 R13W, SM ' At total depth 1910'FSL and 872'FWL from WS Corner of Sec. 1, T8N, 11. Field/Pool R13W, SM "G" Pool, Middle Ground Shoal 12. Present well condition summary Total depth: measured 10,850 feet Plugs (measured) true vertical 8577 feet Effective depth: measured 10,806 feet Junk (measured) true vertical 8535 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2280' 13-3/8,61# 2600 sx 2280' 2079' Intermediate Production 9040' 9-5/8", 40-47#,P-110&N-80 1400 sx 9040' 6885' Liner 1894' 7", 29#, N-80 350 sx 8956'-10,850' 6807' Perforation depth: measured 9159'.- 10,624' (10 intervals) true vertical 6995' - 8363' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 EUE 8RD @ 10,512' Packers and SSSV (type and measured depth) Guiberson RH-2 @ 8060', Guiberson RH-1 @ 88~,~({~ 13. Stimulation or cement squeeze summary ~}UN 2 2 1992 Intervals treated (measured) Tubing soak/wash Alaska L)it !Treatment description including volumes used and final pressure 23.8 bbls 25:75 xylene:7.5% HCl soak foll~rl~l~8 bbls 5% HCl jet wash 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf . Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 186 0 40 760 90 Subsequent to operation 170 0 42 675 100 15. Attachments: MIT test form 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~- OilX Gas__ Suspended__ Service 17. I hereby certity that the torego~ng is true and correct to the best et my Knowledge Signed~-'0' ~+~ Title staff Production Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DAILY REPORT WELL: A13-01L DAILY SUMMARY - 5/18/92 - MOVING & R/U ON LEG #1 LOCATION. - CONDUCT PRE-JOB SAFETY MEETING. DISCUSS PROPER ACID BLENDING PROCEDURES. - R/U & TEST BOPE, TEST FLOW LINES. - R/U & FUNCTION TEST MILL BHA #1 (SEE BELOW). - RIH W/BHA #1 @ 2000 HRS CIRCULATING @ 12 GPM. - BEGIN MILLING SCALE @ 7838', MILL HARD SCALE @ 7928', BREAKTHROUGH SCALE @ 7984'. NO SCALE OBSERVED TO 9200'. PUMP 5 BBL GEL SWEEP, CHASE & POH WITH BHA #1. XO BHA. - R/U NOZZLE BHA #2 (SEE BELOW). - RIM WITH NOZZLE BHA #2 AT REPORT TIME. BHA DATA: #1: 2.25" WAVE MILL, 1.75" PDM, HYD DC, DBLCV, CT CONN #2: 2.25" SWIRL NOZZLE, EXTENSION, DBLCV, XO 5/19/92 - RIH WITH NOZZLE BHA #1 TO 9200'. PUMP 23.8 BBLS OF 25:75 PAD ACID FOLLOWED 3 BBLS FIW TO DISPLACE 5.8 BBLS PAD ACID ACROSS SCALED TUBING INTERVAL. SOAK 30 MINS. PUMP 6 BBLS FIW TO DISPLACE PAD ACID OUT OF CT. SOAK 30 MINS. PUMP 6 BBLS FIW TO DISPLACE PAD ACID. SOAK 30 MINS. PUMP 6 BBLS FIW TO DISPLACE PAD ACID. SOAK FOR 30 MINS. TOTAL PAD ACID PUMPED 23.8 BBLS. - LOCATE NOZZLE @ 9200'. PUMP @ 1 BPM 5% HCl WHILE HOISTING NOZZLE @ 50 FPM. JET ACID WASH FROM 9200' TO 7800' WITH 28 BBLS TOTAL ACID VOLUME. - RIH & LOCATE NOZZLE @ 9200'. PUMP 5 BBL SWEEP, TO DISPLACE ACID TO SURGE TANK FOR NEUTRALIZING. RETURNS CAME BACK @ 0- 1 Ph. CIRCULATE BOTTOMS UP UNTIL Ph OF FLUIDS ARE CLEAR. OBSERVE 100 PPM OF H2S. PUMP SSI TO BRING LEVEL DOWN. POH. - PROCESS CAPTURED (LOW Ph FLUIDS) IN SURGE TANKS TO NEUTRALIZE. RIG DOWN, OPERATION RELEASED TO A42-11 FOR MOVE ON LEG #3 @ 1500 HRS 5/18/92. - BHA DATA: #1: 2.0 SWIRL JET NOZZLE, DBLCV, CT XO #2: 2.7" MILL, 2.5X6.059" UDRMR, 2.375" PDM, HYDDC, DBLCV, CTXO REC£1V D J UN 199 Alaska Oil & Gas Oons. Anchorage S BBM/A13 -0iL. WP5 Shell Western E&P Inc. An affiliate of Shell Oil Company 601 West Fifth Avenue Suite 800 Anchorage AK 99501 May 5, 1992 State of Alaska Alaska Oil & Gas Conservation Commission ATTN: Lonnie Sm£th 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Smith: SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. A13-01L Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing unit clean out and acid/solvent wash tubing operation on MGS well A13-01L. The workover is anticipated to begin on May 15, 1992. If you have any questions, please call Mr. PaUl Huckabee at (907) 263-9646. Very Truly Yours, S. B. Brown-Maunder Sr. Environmental Technician Alaska Operations S BBM/PTH/dlw Enclosures SBBM~050592C .WP5 RECEIVE Alaska Oil & Gas Cons. AL/-,,., OIL AND GAS CONSERVATION COMMIS '~ APPLICATION FOR SUNDRY APPROVAL% 1. Type of Request: Abandon Alter casing Change approved program 2. Name of Operator Shell Western E&P Inc. 3. Address 61:)1 West 5th Avenue, Suite 800 Anchorage, AK 99501 4. Location of ~vell at surface At top of productive interval At effective depth At total depth Suspend__ Operation shutdown Re-enter suspended well Repair Well Plugging __ Time extension Stimulate -- Perforate Other X Pull tubing Variance !5. ]-ype ot Well: Development X Exploratory Stratigraphic Service Platform A, Leg 1, Conductor 8, 1630'FSL & 440'FEL from SE Corner of Sec. 11, T8N, R13W, SM 9159' (M.D.), 1612'FSL & 365'FWL from SW Corner of Sec. 1, T8N, R13W, SM 1905'FSL & 858'FWL from SW Corner of Sec. 1, T8N, R13W, SM 1910'FSL & 872'FWL from SW Corner of Sec. 1, T8N, R13W, SM 12. Present well condition summary measured 10,850 feet true vertical 8577 feet measured 10,806 feet true vertical 8535 feet Length Size 6. Datum elevation (DF or KB) 116' DF feet 7. Unit or Property name Middle Ground Shoal '8'. Well number A13-01L 9. Permit number 66-15 10. APl number 50-733-10079-00 11. Field/Pool MGS/"E, F, & G" Pools Total depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Cemented 2280' 13-3/8, 61# 2600 sx 9040' 9-5/8", 40-47#, P-110&N-80 1894' 7", 29#, N-80 Perforation depth: measured 9159' - 10,624' (10 Intervals) true vertical 6995'- 8363' Tubing (size, grade, and measured depth) 1400 sx 350 sx 2-7/8", 6.5#, N-80 EUE 8RD @ 10,512' 1" macaroni tubing fish top @ 9291' Measured depth True vertical depth 2280' 2079' 9040' 6885' MAY - 7 1992 Alaska 0il .& Gas Cons. Commissi0a . ~Anchorage Packers and SSSV (type and measured depth) Guiberson RH-2 @ 8060', Guiberson RH-1 @ 8896', SOG SSSV nipple @ 329' 13. Attachments Description summary of proposal X__ Detailed operations program 14. Estimated date for commencing operation 05/15/92 BOP sketch 16. If proposal was verbally approved Plug integrity BOP Test Location clearance Mechanical In~grity Test__---Subsequent form requi-~d 10- 15. Status of well classification as: Oil X Gas Suspended Service Name of approver Date approved 17. I hereby~.c~ertify t~at the foregoing is true and correct to the best of my knowledge Signed/'/(~{,/.,..-~ ~'~" Title Staff Production Engineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may w~ness lJAppr°val No.~_/~/ Approved by order of the Form 10-403 Rev 06/15/88 Commissioner Date/,,/~v. SUBMI~IN T~R IPLICA--~E APPLICATION FOR SUNDRY APPROVALS FORM 10-403 ATTACHMENT DESCRIPTION SUMMARY OF PROPOSA~ MIDDLE GROUND SHOAL WELL NO. A13-O1L The oil production rate in MGS A13-OIL has declined from 220 BOPD in January 1992 to 190 BOPD in April. This indicates an annual decline rate of 41% over the last 4 months. Wireline operations on April 9, 1992 discovered a scale obstruction in the tubing at 7807~ (181~ above the gas lift orifice). Lab analysis indicates HC1 acid solubilities in the range of 80 - 90% and approximately 10% organic material. Documentation in the well files indicates asphaltene deposition has been a problem previously in this tubing string. The latest test was May 5, 1992 at 236 BPD Gross, 22% cut, and 184 BOPD clean. A 40 BOPD production increase is expected from successful clean out of the wellbore and acid/solvent wash of the tubing. .Proposed Operations Summary 1. Fill wellbore via the annulus with Filtered Inlet Water (FIW). 2. Rig up Coiled Tubing Unit (CTU), acid/solvent treatment materials & equipment, and return fluid processing materials & equipment. 3. Clean out wellbore to below the sliding sleeve at 9183' with downhole motor and bit/mill assembly. 4. Acid/solvent wash the tubing via CTU with a 7-1/2% hydrochloric (HCl) acid and Xylene dispersion mix. 5. Neutralize all return fluids prior to sending to production facilities. 6. Return well to production via gas lift. RECEIVED MAY - 7' 1992 Alaska Oil & Gas Cons. Commission Anchorage Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 March 18, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen. SUBJECT- SUBMISSION OF THE REPORT OF SUNDRY WELL OPERATIONS MIDDLE GROUND SHOAL WELL NO. A13-OIL Enclosed, in duplicate, is the report of Sundry Well Operations for MGS Well No. A13-OIL. The workover included a coil tubing unit acid/solvent wash to remove scale and/or asphaltene obstruction. Operations were completed February 19, 1991. If you have any questions, please call Ms. Susan Murnan at (907) 263-9614 or Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, ~.?~.0. W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures REEEIVED [v~AR 1 9 t99'~ Alaska Oi~ & Gas 6ons. 6ommissio~ Anchorage AOGCC~SUNDRY.DOC · AL' ~ OIL AND GAS CONSERVATION COMM', ~_N'" ~ j~ REPORT .iF. SUNDRY WELL OP 'RATIOI ,! 1. Operations performed: Operation shutdown Pull tubing __ 2. Name of Operator Shell Western E&P Inc. __ Stimulate__ Plugging __ Perforate __ Alter casing__ Repair well Other 5. l-ype' ct Well:' Developmen! X 'Exploratory Stratigraphic Service 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 At top of productive interval At effective depth 4. Location of Well at surface Conductor 8, Leg 1, 1630'FSL and 440'FEL from SE corner of Section 11, TI~'N, R13W, $.M. 9,159'(M.D.) 1,612'FSL and 365'FWL from SW corner of' Section 1, T8N, R13W, S.M. 1,905'FSL and 858'FWL from SW corner of Section 1, T8N, R13W, S.M. At total depth 1,910'FSL and 872'FWL from W$ corner of Section 1, T8N, 12. Present well condition summary 6. Datum elevation (DF or KB) 116' DF feet 7. Unit or Property name Middle Ground Shoal 8. Well Number A13-01 L 9. Permit number/approval number 66-15/90-591 10. APl number 50-733-10079-00 11. Field/Pool "G" Pool, Middle Ground Shoal Total depth: Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner measured 10,850 feet true vertical 8,577 feet measured 10,806 feet true vertical 8,535 feet Length Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 2,280' 13-3/8,61# 2,600 sx 2,280' 2,079' 9,040' 9-5/8", 40-47#,P-110&N-80 1,400 sx 9,040' 6,885' 1,894' 7", 29#, N-80 350 sx 8,956'-10,850' 6,807' Perforation depth: measured 9,159'- 10,624', 10 Intervals true vertical 6,995' - 8,363' Tubing (size, grade, and measured depth) 2-7/8", 6.5~, N-80 EUE 8RD @ 10,512' Packers and SSSV (type and measured depth) Guiberson RH-2 @ 8,060', Guiberson RH-1 @ 8,896', SOC SSV @329' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. ECI-IVE Prior to well operation Subsequent to operation ^laska Oil & Gas Cons. Commission Anr~hnro~(~ Reoresentative Daily Averaae Production or tnjectic~r{"~'~.-- OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 121 145 95 870 100 216 0 54 650 90 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys nJn I I Oil X.~_ Gas__ Daily Repo .rt of Well Operations I Suspended__ 17. I hereby certity that trm toregoing is true anc~ correct to the best ct my Knowlectge Service Form 10-404 Rev 06/15/88 U - - 0" ~)U SUBMIT DATE 2/17/91 2/18/91 2/19/91 RECEIVED k~AR 1 9 t~9~ Alaska Oil & Gas Cons. Comm~SSiO~ /~chorage DAILY REPORT OF WELL OPERATIONS A13-O1L DESCRIPTION Equipment accepted and begin rigging up at 1230 hrs. Safety meeting held at 1500 hrs. At 1530 hrs, pressure test CTU at 5000 psi for 5 minutes. Encounter and repair leak at CTU swivel. Retest CTU to 5000 psi for 5 minutes. Test all and return line 5 to 140 psi. RIH with coil tubing at 1745 hrs. Start pumping at 1805 hrs. Tag up at 7233' and start drilling. Tag bridges from 7884'-9124'. Continue drilling bridges. At 9124' mix 8 bbls gel and clean hole. At 9150', getting sticky so POOH at 0440 hrs Out of well at 0550 hrs. Freeze protect CTU, mix brine and pump through at 0630 hrs. At 0725 hrs, rig off well head, remove mud motor. At 1300 hrs JWL on location. Walk through with Bill Osborn. Halliburton changing out valves and cast fittings. Set up rate test on air pump (acid pump). Pump 10 gallons HCL to Tank 1 and circulate at .45 BPM at 1745 hrs. Repeat HCL circulation. After no further acid action, start transfer on "clean" fluid into Tank 2. At 2230 hrs, finish transfer of fluid and circulating at .5 BPM. Mix soda ash to neutralize remaining acid in Tank 2 (pH 3) to pH of 8 at 2350 hrs. Continue neutralizing and start pumping through production header at .5 BPM. At 0645 hrs finish pump down Tank 2. Notify onshore operator, Kevin C. Note: Tank 1 has 6-8" heavy sludge remaining and Tank 2 has 4-6" heavy sludge remaining. At 0700 hrs, rig down Haliburton pumping unit and rig up ARI pumping unit. Review psi testing requirements to done with all personnel, review safety permits. At 1240 hrs start to psi test. Found CTU frozen at the end. RIH to 500' to thaw CTU. AT 1400 hrs psi test to 5000 psi for 5 minutes. Test check valves, were OK. At 1415 hrs, RIH with jet wash gun to 9100'. Pump 5 bbl gel and sweep hole (production header). At 1735 hrs, gel to surface and switch to Tank 2. Test all surface lines to 150 psi. Start pumping HCL/Xylene mix. Chase with 58 bpm FIW at 4600 psi. At 1825 hrs, displace first 7.5 bbls and soak. At 1855 hrs, displace second 7.5 bbls and soak At 1935 hrs, displace third 7.5 bbls and soak. Premix caustic and ssII. Pump 5 bbl gel pill. Chase with FIW. At 2055 hrs, acid to surface and start ssII for H2S control. Pump to Tank 2. Returns cleaned up. Switch to 031491 production header SOOH. 11,900# (down from 21,000# at start of job). Out of well at 2215 hrs. Shut pumps down, secure well. Start to rig down on A13-O1L. Circulating tank with caustic to neutralize. Rig down Coil Tubing Unit from A13-O1L and rig it up on A43-11. Continue to circulate and neutralize Tank 1 with approx- imately 150 bbls. Hanging production jewelry on A13-O1L. RECEIVED k,~AR i 9 1~9] Alaska OJi& Gas Cons. Comrnissto,q Anchorage 031491 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 July 27, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT: SUBMISSION OF THE APPLICATION FOR SUNDRY APPROVALS MIDDLE GROUND SHOAL WELL NO. A13,01L Enclosed in triplicate is the Application for Sundry Approvals for well No. A13-O1L, Middle Ground Shoal. The surface location is Platform A, Leg 1 Conductor 8. Estimated date for commencing operation is August 1, 1990. If you have any questions regarding this report, please contact Paul Huckabee at (907) 263-9646 or Val Jones at (907) 263-9614. Very Truly Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/vj Enclosure k ': ~AOGCC\O72790A. DOC STATE OF ALASKA ALAS,... IL AND GAS CONSERVATION COM~,, SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name "of Operator 5. Datum elevation (DF or KB) SHELL WESTERN E&P I NC. 116' DF 3. Address 601 West Fifth Avenue~ Suite 800~ Anchorage~ AK 99501 4. Location of well at surface - Conductor 8, Leg 1. 1630' FSL and 440' FEL from SE corner of Section 11, T8N, R13W, S.M. At top of productive interval . 9,159' (M.D.) 1,612' FSL and 365' FWL from SW corner of Section 1, T8N, R13W, S.M. At effective depth - 1,905' FSL and 858' FWL from SW Corner of Section 1, T8N, R13W, S.M. At totaldepth - 1,910' FSL and 872' FWL from SW corner of Section 1, T8N, R13W, S.M. 11. Present well condition summary Total depth: measured true vertical 10,850 feet Plugs (measured) 8,577 feet 6. Unit or Property name Middle Ground Shoal 7. Well number A13-01 L 8. Permit number 66-15 9. APl number 501733-10079-00 10. Pool Middle Ground Shoal feet Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10,806 feet Junk (measured) 8,535 feet Length Size Cemented 2,280' 13-3/8", 61# 2,600 sx 9,040' 9-5/8",40-47#,P-IlO&N-80, 1400 sx 1,894' 7", 29#, N-80 350 sx measu red 9,159' - 10,624' true vertical 6,995' - 8,363' , 10 intervals Tubing (size, grade and measured depth) 2-7/8", 6.5#, N-80 EUE 8RD ~ 10,512' Packers and SSSV (type and measured depth) Guiberson RH-2 ~ 8~060'~ Guiberson RH-1 @ 8~896'~ SOG SSV @ 329' 12.Attachments Measured depth True Vertical depth Description summary of proposal [] 2,280' 2,079' 9,040 ' 6,885 ' 8,956' -10,850 ' 6,807 ' -8,577 ' .,: ~'[ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation August 7, 1990 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that t...~_he for~loing is true and correct to the best of my knowledge Signed /'-- Title Manager, Alaska 0perations Commission Use Only Date 8/1/90 Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel ~'~,_~/-",,,.~ /'// ORIGI[ 81GNED BY Approveci C;ol~ ...................... . Returned LONNIE C. SMITH ~. '" ! o~ .-_~.0 by order of - v~.~ ~'~-I, I'11 ~ ~, (..), U [ the commission Date Form 10-403 Rev 124-85 Submit in triplicate MIDDLE GROUND SHOAL WELL No. A13-OiL COILED TUBING ACID/SOLVENT WASH TUBING PRESENT STATUS: Well oroducing from ON-GO ~ t,__ough ~he HR-HZ. Last Test 7/09/90- 162 BOPD + 24 BWPD, i3% cuT. Bridge 'in ~ubing Tagged 7,/02/90 '~ 7820' !168' above bottom gas ii=~ mandrel ~ 7988', OBJECTIVES: Coiled Tubing Univ. Acid'So~venz wash tubing r.o :Lemove scale and/or asmnaitene MECHANICAL DETAILS: See ~t~ .... ~' '~ t~c___G ~.;e _ schemas!cs. REMARKS OR SPECIAL INSTRUCTIONS: ?, NOTE: l" Macaroni ~ubing fish Left in hole in August 1968. Top of fish ~ 9291' . NOTE- Control tine leaks Dummy SSSV in ~ . · p~ace RECOMMENDED PROCEDURE SI gas injection. Close crown valve. RU $iickline Unit to recover SSSV. Test lubricator to .~500 psi. RiH and retrieve dummy SSSV ~rom SOG nipple at 329'. POOH. RD Slic~iine. Hold safe~y meeting with Arctic Recoil and other platform .£ personnel to discuss the proposed operations. Emphasize the concerns with H2S during acidizing operations and the handling of Toluene. RU Arctic Recoil CTU with CTU assist pump. ?est CTU stack to 5000 psi. 4. Call out 20+ bbls Doweii Acid Dispersion (DAD) consisting of 25% Toluene + 75% 7-1/2% HCL via Doweii-Scniumberger {D-S) with the following additives- - 0.4% A-250 Corrosion Inhibitor, - 1.5% U?4 Dispersing Agent, - 0.2% F75N non-Ionic Surfactant, - 20#/lO00gai L-58 iron sequestering agent 5. RU circulation (reverse and conventional) return line manifold to allow injection of NALCO Visco 3631H2S scavenger into the return MIDDLE GROUND SHOAL No. A13-O1L COILED TUBING ACID/SOLVENT WASH TUBING fluids at (or near) the wellhead. RU return line manifold to Take returns to an enclosed, isolated Tank. r~ '~he returns tank, add 5 gals D-S D47 Antifoam additive met !000 gallons of tank capacity (DO NOT put this additive in ,he acid system '~o be pumped downnoie!) . Refer to Attachment No. i and follow the "Guidelines for Handling Backflowed and Circulated Fluids" for ail returns. NOTE: Because the operaticns may result in a significant quantity of solvent in the return fluids, The Onshore Operator should be notified and instructed ro divert- t, he transfered fluid ro the holding tanks. This .'~ill .=~ilow dilution of The workover fluid prior to processing uhrough rhe ?iant. 7. RU Piitered Inlet Water !F!W) source line to access riW downstream of ~UN ~ _ .~ ~.0 c, oa_~rr dee ~il~ers. NOTE: 3e ~ue~are~ ~o blend in 0 $% ~aCl2 to ail FiW wa~=~ wni'e ~umDin~ ?.U 'ow rate injection 'pump ro SSSV control line ro maintain a greater pressure on the control line than ,on the coiled ~ubing/2-?.'8" ~uDing annulus during c.iean out and acidizing operations. 9. .... 7IH with ="-i,'~"~ co=~ed, tubing wi~%-.~ standard wash nozzle to the tubing obstruction at 7820' . Establish circulation with FIW + 0.5% CaCi2 (blend in 0.5% CaCl2 to ail FIW water while pumping). Clean out to top of fish {~ 9291'). NOTE: Coiled tubing length = 12500' !-~/&".. _ coiled tubing capacity = ,~i.~2~. bbls/1000')~12500' = 14.05 bbis Annular capacity to 9291' = (0.00427 bbi/ft)*9291' = 39.67 bbls i0. Reverse 20 bbls 25:75 DAD (25% Toluene + 75% 7-1/2% HCL) followed by 21 bbls FIW (+ 0.5% CaCi2) to sweep the annulus taking ~ 1 bbl DAD into the coiled tubing. Maintain a greater pressure on the SSSV control line than on the coiled tubing/2-?/8" tubing annulus during acidizing operations. The top of the DAD should be at ~ 4908' in the annulus. SD pump and let acid soak for at least 30 minutes. Pump circulate 22 bbis F!W (+ 0.5% CaCi2) down the coiled tubing to move DAD to upper part of tubing and sample return acid. TaKe returns to an enclosed, isolated tank. Measure DH o~ return - fluid to see if acid is spent. Monitor return fluid for H2S and treat with NALCO Visco 3631 as needed. Neutralize return acid. ~dd D-S D47 Antifoam additive to the returns tank as needed to page 2 MIDDLE GROUND SHOAL No. A13-01L COILED TUBING ACID/SOLVENT WASH TUBING prevent foaming overflow. SD pump and let acid soak for at least 90 minutes. ..~ acid,~s not spent, _~everse 2~= bbis FIW (~ 0.5% CaCi2) to sweep ~he annulus taking ~ 1 bbi DAD into the coiled tubing. SD pump and~et acid soak ~or at ~east .30 minutes. 13. Pump circulate a minimum o; 55 bols FiW (+ 0.5% Cae!2) down the coiled tubing to displace DAD. Take returns to an enclosed, isolated tanK. Sample return acid. Measure pH of return fluid To see if acid is spent. Monitor return fluid for H2S and treat with NALCO Visco 3631 as neeaed. Neutralize return acid. Add D-S D47 Antifoam additive ~o ~he _eturns ~ ~' ~a..~ as needed to prevent foaming overflow. !4. POOH. RD CTU. Open well ~o ~'omuction. Establish gas injection for gas lift. RU Siickiine Unit. ?est _'aO'~ica~or xo .~500 esi. R!H and install dummy SSSV ~n SOG nipple a~ ~29' POOH. RD Siickiine. '6. After well performance stabilizes, production test well via the test separator. Recommended: ~_9 ,~ ?/~'/~ Concurred : work Ph # 263-9646 home ph # 344-5857 Approved: Date: cc: ANCHORAGE Manager Alaska Ouerations - R. G. Blackburn Division Drilling/Production Engineer - V. E. Unger Kenai Production Office - B. N. Osborn Platform "A" Operations Foreman - R. V. Hili/J. W. Landess/Tracy Environmental Technician - S. S. Brown-Maunder Anchorage Engineering File Room - Category (6) HOUSTON WOODCREEK .. C. M. Kidweil - WCK 1178 R. G. Lippincott - WCK !140 S. M. Logan - WCK 1162 E. W. Kitchen - WCK 1136 ORIGINAL TO: Woodcreek File Room - WCK 4100 page 3 MIDDLE GROUND SHOAL No. A13-O1L COILED TUBING ACID/SOLVENT WASH TUBING ATTACHMENT No. 1 PROCEDURES FOR HANDLING BACKFLOWED AND CIRCULATED FLUIDS Ail backflowed and circulated fluids must be routed Through ~ne test separator prior to being sent to ~he Onshore Facility for discharge. Emulsion breaker should be added as required. Bottle testing is recommended to determine ~he concentration of breaker. Monitor fluids for HIS and add appropriate scavenging chemicals as required. Note: Ensure any ac±d ~reatmenr ~luids that are circulated or backflowed are neutralized prior to sending to the production separator. 7o satisfV EPA recuirements, ir rne amount o= =2uid exceeds 250 bbis ~t ..... one t~me, the Onshore ,"ue~_ror= m~.. t ~aKe sammies o.~ ~-='='~ comoietion . ~nd,'or well ~reatmen~ fiulGs a~ uhe onshore discnarqe ilne. Samples must be sent to C&G laos i~.. Anchorage for o~ 'grease_-~,. and oH~ analysis. The Onshore Operator should label samples with description of fluid and date, such as: "Fluid returns from AiS-O1L acid treatment - :~/xx/90" Notify Onshore Operator when the fluid is being sent. Use the following calculation to determine when the samples need to be caught. Pipeline Delay = "A" Pipeline Capacity (bbi) Gross Daily Prod "A" (bbi) = Workover fluid slug (bbi) x 24 hfs = hfs Onshore Facility Delay - I000 bbl Gross Daily Prod "A", "C", and "BaKer" (bbl) x 24 hfs = hfs Total time between slug shipment and sample time = hfs NOTE: Because the operations ma}, result in a significant guantity of solvent ~n the return fluids, The Onshore Operatcr should be notified and instructed to divert the transfered fluid to the holding tanks. This will allow d~lution of the workover fluid prior to processing through the plant. page 4 A B E F G H I J K M N O , ! 9 10 11 12 13 COMPLETION EQUIPMENT DETAIL SHEET MGS A13-O1L 8/13/87 NO. ITEM ,, LONG STRING A. SOG NIPPLE B. CAMCO KBM MANDREL #1 C. OTIS "X" NIPPLE D. CAMCO KBM MANDREL #2 E. CAMCO KBM MANDREL #3 F. CAMCO KBM MANDREL #4 G. CAMCO KBM MANDREL #5 H. CAMCO KBM MANDREL #6 I. CAMCO KBM MANDREL #7 J. CAMCO KBM MANDREL #8 K. OTIS "X" NIPPLE L. GUIBERSON RH-2 PACKER M. GUIBERSON RH-1 PACKER N. OTIS "X" NIPPLE O. OTIS "XX" SLIDING SLEEVE P. OTIS "N" NIPPLE Q. BOT SHEAR SUB APPROXIMATE TVD. MD. PSI OR 329 329 2026 2201 2727 3301 2792 3407 3342 4299 3860 5102 4361 5851 4857 6595 5437 7364 5957 7988 5986 8022 6019 8060 6752 8896 6986 9147 7017 9183 8211 10481 8256 10512 CASING 13 3/8", 61# @ 2280' w/2600 sx 9 5/8", 40-47#, P-110 & N-80 @ 9040' w/1400 sx 7" 29#, N-80 LINER @ 8956-10859' w/350 sx PBTD = 10,806' TD = 10,850' TUBING LONG STRING 2 7/8", 6.5#, N-80 EUE 8RD @ 10512' PERFORATED ZONE GROSS INTERVAL LONG STRING GN-GO 9159-9185' GR-GS 9503-9546' GS-HC 9682-9708' HC-HD 9836-9876' HC-HD 9908-9949' HE-HF 9983-10022' HI-HK 10141-10179' HK-HN 10189-10287' HN-HR 10287-10438' HR-HZ 10454-10624' NOTE' FISH IN HOLE; DUMMY GLV, 2 GLV, TEMP. & PSI BOMB Shell Western E&P Inc. Q 601 West Fifth Avenue * Suite 800 Anchorage, Alaska 99501 June !1, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 9950] SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, T8N, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, TSN, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at tota] depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC RECEIVED Alaska Oil.& Gas AnChorage HIDDLE GROUND SHOAL P1 atform "A" WELL/CONDUCTOR LOCATIONS Leg I - Center of Leg I @ 1627'N & 435'W from SE corner of Sec.11, T8N, R13W, S.M. ~ A 12-01. I 1632'N & 437'W from SE cOrner A 11-01 2 1632'N & 432'W " " " A 43-11 3 1630'N & 430'W " " " A 34-11 4 1625'N & 430'W " " " A 34-14 RD 5 1622'N & 433'W '" " " A 22-14 ~ 6 1622'N & 437'W " " " A 12A-01 7 1625'N & 440'W " " " A 13-01 8 1630'N & 440'W " " " Leg 2 - Center of Leg 2 @ 1681'N & 372'W from SE corner of Sec.11, T8N, R13W, S.M. A 42-11 9 A 44-02 10 A 42-14 11 A 41A-11 12 A 11-12 13 A 11-13 RD 14 A 31-14 15 A 44-11 16 1685 1685 1683 1678 1675 1675 1678 1683 N & 378'W N & 374'W from SE corner N & 370'W " " " N & 368'W " " " N & .368'W " " " N & 371'W " " " N & 375'W " " " N & 378'W " " " II II II Leg 3 - Center of Leg 3 @ 1620'N & 321'W from SE corner of Sec. 11, T8N, R13W, S.M. Le9 4 - Center of Leg 4 @ 1566'N & 383'W from SE corner of Sec.11, T8N, R13W, S.M. A 33-11 25 A 14-01 26 A 12-12 27 A 24-01 28 A 13-12 29 A 33-14 30 A 41-11 31 A 23-01 32 1571 1571 N & 381'W 1568 N & 378'W 1564 N & 378'W 1561 N & 381'W 1561 N & 385'W 1559'N & 388'W 1569'N & 388'W N & 385'W from SE corner II II II II II ti II II II II II II II II II II II Oil & Gas Cons. Anchora~ SBBC/mgs A I . . I T911 S.M. ~1 [ · s · · · . . · ' 'e · · · · · · · · · · ~ . · : ADL 18754 , .:i .,*' i · · , el · . ,: , , . ,~ . . e! '' · LAT. 60e 47' 44.906" ~ ~ '~.~.~,,~o ~' "~"*' /'." ZONE 4 .. .... ~,.,.. ,, .......... ,, ..... , ,, .,, IG IS 14 13 I II ' , .. ~ ~ ~ ~ · . -~ .~ ~. ". ... . . Zl t2 t~ .' . ~4 19 . , ' ~ I' · . e ~~ ~1~/ . , , .~ . i , L_ , , ,, 28 2~ ~ Z6 25 30 * . . ;- ~. . '% ~ : :;. LOCATIO~ OF ' -:JU~i~ 1~[~) SE~ CONTAINEO DRILLINO ~l~ka ~il & Gas Cons. ( ~mmlssion P R 0 O U C I N T 8 N S.M. ~ glic~ofa~ SHELL MIDDLE GROU;~D SHOAL · ~ T 7 N S.M., t , PLATFORM A" COOK IHLET, 0 4003 90~ 12000 APPLIC,,'-,,TIOtt BY SHELL OIL CO. LOS ,ANGELES, CALIFORhlIA ti I0 T. 8 N., R.13 W., S.M. I 18754 14 LEG NO. 14 ADL 2 I II 12.. LEG NO. I x = 232,783 Y = 2,485,845 1627' I',1 ~ 455'W FROM THE SE COR. OF SEC. II, T8N, R 13W, SM. LEG NO.2 LEG NO, 3 P L A ~I£ ¢ O 0 t? D ItCA X= 232,846 X: 232,896 Y = 2,'t85,897 Y= PUBLIC LAND 1681' N B~ 372' W FROM 'THE SE COR. OF SEC. II, TSN, RISW, SM. D ~'S C /F I P ~ / 0 /t/ 1620'N 8~ 321' W FROM THE SE COR. OF SEC. II, TSN, RISW, SM. LE6 NO. 4 X = 2:32,833 Y = 2,485,783 1566'N 8, 383'W FROM THE SE COR. OF SEC. II~ TSN,RI3W, S.M. GEODETIC CO0/?DINA TE$ I1 LAT.- 60°47'44.839'' LAT.- 60°47'45.368'' LAT.' 60°47'4q. 768" LAT. - 60°47'44.244" I! LONG.- 151° 29'45.112''- LONG.-151°:;'9' 43.94Z" LONG.-151°29' 42.~899'' LON$.- 151°29' 4,4.154" ~=~3~,',,~",,~"'~'~1~._":'~'~'~3'1~~ .... ~ -- - ' .,.~'¢.~ . .I,~ ,,~ ',-,~..,~,.~"~c~ , ~' ~, I' I ~'I c/"' ,~ ' ' : [}~.,~ :r'i'~ .,'. H.A.D. .., R ~...,~LE I= = I000 t, --- '' ' -~ 1[ I I ~ wi-,, T~ '~ · - .... '. ! S,,E~.L 0,~. C~,,.~, ,-~l,~ -. ~...., ~,.-.. .. li-i?':r~- ~.,*,~ ',.,'1965 I! . ti t-' ~ I b {,.) - Z [ I"t'~"~'~l~¢~l~lS':I~'~"~";'~l~l'l~ ' ' "~ ~l .... ~ ' ii LOCATIO~N OF January 8, I974 SU~JECT:.::..~..:,. DO~IHOLE STORM CHOKE FA I LURES;. ::." .:,/~;'. '"' 'S~HELL ~S P~ORM "A"~ WE'LL' "'z'~ : - --., -. . · ~.. ..... :.-~>~,. .--. .......... - . . .... - . ,-~, . ~.: -,'?: .~.,...... ~ype. "H"' s~o~:.:-choke:-, in ,el'I.:' ~.' :l t.-I tO",:~.leak ve~ si igh~ly...Also, ,the'Type:~?,::]:'~::.:. ~.~::: ::"fl~'s~°m']::c'b°ke]':~i~""~el l'L'~;'::t3;l']YPPer':'fa~i:'led~:fo.'~lose and the Type. -K-.:StO~m ' .">:'-"::- choke in' ~.l i"-~. 43'11 · failed 'fo close. ~'- ..... -. :. . :.~.-....-:..._:.~ ..:..-:.. -.:._ . -.]. .. _- ~ ~ ".. . ..... '.... , ?:. -. ., ~.]~; November.26, 1973~ ~b ~ro~e, '~la~fo~ "A" for~an~ cal led and advised me~] - tha~ th~y.-fiad 'p~led ~he storm choke ou~ of ~etl ~. Il-I, repaired I~, and , . .. reran: it in ~he ,el I.. That s~orm choke no~ operates properly withou~ leakin The~tt and'als° pul led the sto~ choke from t~ell No. 13-1 U~Pe~ repaired i~, reran' i~-n~, opera~es properly. The Type 'K" s~o~ choke in ~el I ~b.. 43-II ~as pul led,-cleaned~ and re~an, tt opera,ed irratical Iy and therefore ~as put led a second ~ime- The sa~ choke ~as'. cleaned~ checked and rerun. Again it ope~a~ed i~ra~icat ly' and ~as pul I~' a-,th, ird ti~e. The choke ~as sen~ to Anchorage ~here they disassembled -i~ and: found a sheared pin ~hich a.llo, ed only pa~ial clos:ure. 'Par~s for this TyPe.~?K~.stor~ choke ~ere ordered by air on November 16, I973. D~ember. 28, 1973 - ~b- ~ro~e again called ~o give ~ a report on the Type "K" ~~ c~Oke-f°P~el ! .No. 43-I;t. 'The par~s were recet.~ed and the.~.repaired choke was installed in the. well on - · - December 21, 1973. It was tested and It operated properly. On December 24, 1973, the valve.'ctosed during-a routine platform shut-in but would not reopen. On December 25,. 1973, th{s ~pe "K" storm choke was again pulled from the well and when disassembled' it was found that the pin that had ~ust been replaced was- broken again.- Now, two Type 'K" storm choke replacements have been ordered for this well. Bob will advise me when these arrive and one is installed so t can witness its operation~ ~ JCM:pj ' ' SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE, ALASKA 99501 August 9, 1966 Subject: Well Completion Report Middle Ground Shoal A-13-1 State of Alaska Division of Mines and Minerals Oil and Gas Section 3001 Porcupine Drive Anchorage, Alaska Attention Mr. T. R. Marshall , Jr. Gent lemen: Please find enclosed the following information pertaining to our well MGS A-13-1: Well Completion Report - submitted in duplicate Well History Directional Survey Composite Dual Induction Laterolog, 2"/100' - print and sepia. RI:m Enc lo sure s Yours very truly, · A. MacDougall ~/ Division Production Manager RECEIVED DIVISION OF MINES & MINERALS ANCHORAGE Form SUBMIT IN DUPLIC~_ ;~ STAT]~ OF ALASKA (Seeotherin: structions on CJI AND GAS CONS~:RV~kTION COMMJSS~O~ reverse side) WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF .W~LL: ozi, '~ (;As. WELL WELL [--~ D~¥ E~ Other b. TYPE OF COMPLETION: NEW ~ WORK WELL OVER E~ DEEP- PLUG EN [~] [~] DIFF. BACK RESVR. E~ Other Shell Oil Company ~. ADDRESS OF OPERATOR 430 7th Avenue, Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with a~y ~.tate requirements)* Atsurface Conductor 8, Leg 1, Leg 1 at 1627' N and 435' W of .S~. Corner of Section 11 T8N, R13W, Seward Meridian At top prom Interval reported below ' At 9159' 5,280' N and 1,129' E of surface At total depth Effective: July 1, 1964 5. LEASE DESIGNATION AND SERIAL' NO. ADL 18754 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AOREEMFJNT NAME ---- $. FARM OR~ LEASE NAME M2ddle Ground Shoal WELL NO. A- 13-1 5551' N and 1649' E of I 14. PER~IT NO. DATE ISSUED .. . ...... surface. I 66-15 I 4/15/66 15. DATE SPUDDED [16.DATE T.D. REACHED 17. DATE COMPL. (Ready to prod.) [ 18. ELEVATIONS (DF, RKB, RT~'GR, ETC.):* 4/15/66 I 6/15/66 6/27/66 I 116' D.F. 20. TOTAL DF~, MD & '~¥~ / 21. PLUG, BACK T.D., MD & ~ 22. IF MULTIPLE COMPL., 23. INTERVALS 10,850 ' (8536,~ ~o~ ~* ,~, ~ Dual D C. ,I I/V I 0,ss0' 10., FIELD AND POOL, OR~',~WILDCAT Middle Ground S,hOal .. 11'. SEC., T., R., M;'b OR BLOCKAND SURVEY ~ oR. AR'~A ' :Sect;iOn 1, TOWnship 8N, Range ~'!.3W, Seward:.Meridia~ .. r~ .. . 2,: 1;2. BO'I~OUGH .. ['13. S~TE Kenai [ At:aska · 19. ELEV.__CAS~a~AD ROTARY ~OOLS CABLE ~OOLS 10,806' (8494') 24. PRODUCING INTERVAL(S), OF THIS COMPLETION TOP, BOTTOM, NAME 6 ' 6 ' 9159'-10~ .24 (954 -8323') Lower Zone 26. '~'xrm ELECTRIC AND OTHER LOGS RUN 28. 29, 31. AUG11 1966 DIL~ BHC~ P-ML, GR-N, CBL cAsiNo SI,.E I WEIGHT. LB.Z,T./ DEPTH SET 13-3/8" ] 61 ] 2280' ~-5/8" 40 9040' I DIVISION OF MINES & MINERAL,S 'ANCHORAGE CASING RECORD (Report all strings set in well) HOLE SIZE 18-5/8" CEMENTING RECORD 3420 sacks 12-1/4" 1400 sacks LINER RECORD SIZE J TOP (MD) J BOTTOM (MD) SACKS CEMENT* 7" / 8956' 1i6; T0', 350 PERFORATION RECORD (Interval, size and number) 4 holes/ft. 9159 '-9185 ' 9503 ' -9546 ' 9692 ~'-9708 ' 9836'-g876' 9908'-9949' 9983'-10,02:~' 10,141'-10,179' 10 189'-10,438' 10¥65~ '-10,626'. SCREEN (MD) ---- 30. SIZE .. '25. WAS DIRECtiONAL SURVE:Z': 27. WAS 'WEt, L CORED ' . ~ TUBING RECORD -: .:i DEPTH SET (MD) .. 10,545' ., 2-7/8" rACKER. SET '(MD) 8896' 82. ACID, SHOT DEPTH iNTERVAL (MD) FRACTU~.E, CEMENT SQUEEZE, ET~0,1. AI~IOUNT AND KIND OF. MATERIAL '.USED 33.* PRODUCTION ' DATE FIRST PRODUCTION J PRODUCTION M~TI-IOD (.Flowing, gas lift, Pumping--size and ty~e of pum~) [ WELL STATUS (Producing or 7 / 3 / 66 F lowing j s~ut4n) P roduc ing DATE OF T~ST ~ 7/5/66 10 1/2 64/64" ~s~ ~o. J - ~ 381 140 . 1'2 368 ~W' w~O ~% [ CASINO PRESSURE J CALCULA~DS0 psig 80 psig 24-mooa. >aaw~ j OI~B~L.871 j ~as--~cr.320 J W*~a27BBL. ~ OIL GRAVITY-API (CORR.)36°, A.P.I. TEST WITNESSED BY Vented ~5. LIST OF A~ACHMENTS hereby IIGNED c~.~y> that the/~/l~foregotng and attached information is 7mplete,~ and correct as determined from all available records '-'°- ~' e~'~-~*~-~-4~ ~__ [ TITLE~/Division//, Production Manager DATE . ~-' 9--""- ~/~(~ (See Instruchons'andS c - · pa es for Additional Data' on Reverse Side) INSTRUCTIONS General: This form is demgned for submitting a complete and correct well completion report and 10g on all'types 6f lands ~nd lea~es to either a Federal agency or a State agency, or' both, pursuant to applicable Federal and/Or State laws:and regulations. Anynecessary special instructions conceruing the use of this form and the number of copies to'be submitted, particularly w. ith regard to local, area, or regional'procedures and practices, either are shown below or will be issued 'by, or may be obtaine~l from, the local Federal and/or State office. See instructions on items 22 and 24, and 33, below regarding separate-reports for separate completions. If not filed Prior to the time this summary record is submitted, 'copies of all.currently available logs ' (drillers, geologists, sample and core'analysis, all types electric, etc.), forma- tion and pressure tests, and directional surveys, should be athached hereto, to the extent required by applicable Federal. and/or State laws and regulations. All attachments should be listed on this form, see item 35. - Ifem '4: If. there are no applicabl~' State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State or Federal office for specific instructions~ ~ · Ifem ]8: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachment~: I~ems 22 a~d 24: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 22, and in item 24 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if. any) for only the interval reported in item 33. Submit a separate report (page) on ,this form, adequately identified, for each additional interval to' be separately produced, showing the additional data pertinent to such interval. -... Ifem 29: "Sacks Cement": Attached supplemental records for this well should show. the details of any multiple slmge cementing ~'nd the location Of the Cementing tool. ifem 33: Submi~ a separate completion report on this form f.o.r each inter~al to be separately produced. (See instruction for items 22 and 24 above.) . . . ~7. SUMMARY OF-POROUS ZONES': ' "~- ---' ............... " ' · " SHOW' ALL IMPORTAN~I' ZONES OF POROSITY AND CONTENTSi ~tEI~EOF; CORED IN'~ERVALS; 'AND ALL DRILL-STE~'°TESTS~ INCLUglN~ 38. : ' ~ GEOLOGIC MARKERS DE~H INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN;': PLOWING AND SHU~-IN PRESSURES, AND RECOVERIES .. - FORMATION.. TOP ~ BOTTOH DESCRIPTION, CONTENTS, .'~TC. " · - ' TOP - . NAME · . ': ' . -' . MEAS. DEPTH TRUE V~RT. DEPT~ . . : ,~. ',,.. : ...... ' .: . r . · : .) ' · . . . . .. : ~ - ' - : - ' . x . '.-. . '"~ . . , . .~ . :. ~ ~ ,- ~... : . . - . ~ ~ .:. · /- . , : . -:, _. . . - , .. .~. ~_ ~ : .. . . ~ . · , . . . , , . . ~ · ,, SUBMIT IN DUPLIC~ ~ * Effective: July 1, 1964 STATE OF ALASKA (See otherin: s~ructions on OIL AND GAS CONSERVATION 'COMMISSION reverse side) 5. ·LEASE DESIGNATION "AND SERIAL ADL 18754 WELL COMPLETION OR RECOMPLETION REPORT AND LOG * ~a. TYP~' OF ~LL: OIL ~ ~S. ' --- WELL W~LL ~ DRY ~ Other b. TYP~ OF COMPLE~ON: 7. UNIT AGREEMENT NAM~ NEW WELL ~ WORK : OVER ~ DEEP- E N ~ PLUG -- -- BACK ~ DIFF. nESVR. ~ Other ~ FAR~ Oa LEASE 2. NtME OF OPERATOR She~~ Com~ an-- . 3. ADDResS OF O~E.RA~OR 9 WELL NO. . A-13-1' 430 7th Avenu~ . .~ghora e . Alaska ...... ~o.~m~-.~ ~0o~, 4. LOCATION OF WELL (R~rt location clearly and~nce with a~y ~tate requirements)* X~su~ace Conductor 8, Leg 1. Leg 1 ~ 162~' N and ~jS:~ of SE /' ~d.dle Ggou~d Sh0al Corner of Sec~2on 11, TSN, RlJ~, S,~. ~.~ srC.,T.,R.,~,, At top prod. interval reported below °R~,A~EA 8099' (~.D.) ~902' N and 842' E of surface Section 1, To. ship 8N, ~t total dep~ Range .13W, sewa~d:,~eridi; ~ ..... ~ 6-15 ] 4/15/66 ~ . Kenai ~ ~..~ AlaSka 24. PRODUCING INTERVAL(S), OF THIS COMPLETION~TOp, BOTTOM, NAME (MD AND TVI~ L, ~ L ] V L 8099'-8870' (6010'-6688') Upper Zone AUG 1i 1'966 26. T~rpE ELECTRIC AND OTHER LOGS RUN DIL BHC. P-ML GRTN, CBL 9.8. CASING RECORD (Report all strings set in well) 9040' [ / sacks 13-3/8" 61 2280' -118'5/8" "i.~' '1400 sacks 9-5/8" 40 _ '12'1/4" ~ 29.. LINER RECORD , SIZE ~ TOP (MD) BOTTOM (MD) I SACKS CEMENT* .7W-'- / 8956' --I' 10,850'-I 350 3 -' ------------- --'- /' - 1. PEaFORATION RECORD (f~terval, size and number) Yes 4 holes/ft. 8099'-8144' 8177' ' · , -8230 , 8267 '-8297', 8360 ' -8394 ' 8402 ' -8464 ' 8754 ' -8767 ' -8773 '-8786' 8855' ' , -8870 33.* DATE FIRST PRODUCTION 30. TUBING RECORD ~ SCREEN (MD) S,ZE I D~r~ .`sET (~D) PACKER'S~T" (MD) -- -- 2- 7/8"-I 8060' ~" 8060.,' :: - . -,, 32. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETc.. DEPTH ~NTERVAL (MD) [ AMOUNT AND KIND OP MATERIAL USED PRODUCTION 7/3/66 DATE OF TEST 7/ 4/66 PRODUCTION METHOD (.Flowing, gas lift, pumping~-Ls---~-~ and type o! Flowing HOURS TESTED t CHOKE SIZE PROD'N. FOR OIL---BBL. GAS--MCF. 12 100/64" TEsT ~ERIOD I ~- 776 348 WELL STATUs ~ shut-in) ' r roduc ing WATER BBL. IGAS~OIL RATIO 29 448 FLOW. ~II~g ~?~,~S. I CASING PRESSURE 145 psig 70 psig CALCULATED IOIL----BBL. GA3 MCF. 24-HOUR RATE ~ 1552 I 696 WATER BBL. 58 OIL GRAVITY-API (CORR.) 37:. 1°API' 34. DISPOSITION oF OAS (gold, used for ~ vented, Vented 3~. LIST OF ATTACHMENTS TEST WITNESSED BY Well History, Comppsite D I.L. ~yro Survey 36. I hereby cg~ify that the foregoing and attached lnfo~rmatlon is complete and correct as determined from all available records ~-.~ T/-,., "~ /20 ( ee Instructions paces For Additional Data on Reverse Side) · INSTRUCTIONS . · lSencral: This form is designed for submitting a complete .and correct or both, pursuant' to applicable Federal an(l/or State Jaw's 'and .regullJtions. Any'necessary special, instruction0 concerning the use of this form and tile number of copies to be submitted, particularly with regard to local, area, or' regional procedures and practices, either .are' shown below or will be issued by, or may be obtained from, the local Federal and/or State office. See .instructions on items 22 and 24, and 33, below- regarding separate ·reports for separate completions. If not filed 'prior to the time this summary record is submitted, 'copies of all curren.tiy available logs (drillers, geologists, sample and core analysis, all types electric, etc.), forma- tion and pressure tests, and directional surveys, should be attached hereto, to the extent required by applicable Federal and/or State laws and regulations. All attachments should be listed on this form, see item'35 .... ll¢m 4: If there are no applicable State requirements, locations' on Federal o~ indian land Should be described in accordance with Federal requirem, ents. Consult local State or Federal office for specific instructions.- .... l~¢m 18: Indicate which elevation is used as reference (Where not otherwise shown) fOr dePth measurements given in other Spaces on this form :and ~n any :attachments. I~ems 22 and 24: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item' 22, and in it~em 24 show the producing interval, or intervals, top(s), bottom(s) and name(s) (~ any) for only the interval reported in item 33. Submit a separate report (page) on this form, adequately identified, for each additional interval to be 'separately produced, showing the additional data pertinent to such interval. l~,m 2?: ",~ac/~s C'emet~t": Attached supplemental records.-for this well should show. the details of any multiple stage cementing and the location of the cementing tool. .l~,m ~!~: Submie a separate completion report on this form for each interval to be separately produced. (See instruction for items 22 and 24 above.) ... . · · 37. SUMMARY OF.POROUS ZONES: . ' SHOW ALL IMPORTANT ZONES OF'POROS-IT¥ AND' CONTENTS T~HEREOF; CORED INTERVALS ;' 'AND ALL: ORILL-STE~ ~ESTS, INCLUDING 38.' ' G~OLOGIC MARKERS DE~H INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN~ '~LOWING AND SHU~-IN PRESSURES, AND RECOVERIES FORSIATION ~OP J BOTTOM · : ~ _... · DESCRIPTION, CONT~NTSr'ETC. -'~: . " TOP ~ ' .... NAME ' ' : " jl ' ~ ' '- MEAS. DEPTH J TRUE VERT. DEPT~ : ~. . - : .: . - ; . -; ] .. , .. .,' - , - ,,~ ~ .,[' . ~ .. , : - . ~ .' :' ., , . .. . . . -. _ .: ~ . . [ .. .... .......... . . .._ .~ /~. . ...... . .. '. . · ..] ~ . :. - . .. -' ; .'.. ~ ' , I C- - ' : ' '" : '- '' ' -; ~ ~ ' .~ : . . .. .. . , · { · _ . '~ , '-. r · . . . . . .. ~ . . . . - .... ' . -~ '~'[... ~ ' .~ - ~ ', . , ' , .... , . - , .. , .. _ . - . -. ... ..... ~ :, '~ ' ' ~ "t; :i . ' . ....... - . . . , , . .: .. . . . ~ . . . . . . . .. . ~ : . . . . .~ ., 15 319 16-17 322 18 893 19 1690 20 -- 21 -- 22 -- 23 -- 24 12285 25 26 2663 322 893 1690 2285 2285 2285 2285 2285 2663 3548 4-26-66 DIVISION OF MINES & M~NF-.RAL$ -. ^NCHOP-,AGE Surface Location: Conductor 8, 2.75' S, 3.27' W of Leg 4}1. Leg ~l @ 1627' N & 435' W from S.E. Corner of Section 11, Township 8N, Range 13W, Seward Meridian Depth Reference Derrick Floor, Elevation 116' (MLLW) Spudded well A-13-1 at 22.00 hrs. Drilled to 322' with 12-1/4" bit. Drilled and turbodrilled 571' of 12-1/4" hole. Drilled 797'. Circulated and conditigned hole for 5 hours dUe, to loss of mud. 'Turbodrilled and drilled 595'. .Opened hole from 322' to 1681' from 12-1/4" to 18-5/8". Opened hole from 12-1/4" to 18-5/8" to 1844'. LOST CIRCULATION. Lost approximately 200 bbls. mud. Mixed in lost circulation material and regained full returns. Opened hole to 2280'. Conditioned mud. RAN 1.3-3/8" CASING: CASING SHOE AT 2280'. CEMENTED CASING WITH 2600 SACKS OF CLASS A CEMENT and displaced with 2030 cu. ft. of mud. Lost 1/2 mud returns. Cemented outside casing through 1" pipe at 360' with 500 sacks cement. Cemented between 13-3/8",casing and conductor at 150' through 1" pipe with 320 sacks Class A cement. Flanged up BOP, pressure tested blind .: rams OK with 1500 psi. ¥' Drilled out cement from 2215' to 2260'. Pressure tested hydril and pipe , rams OK with 1500 psi. Drilled to 2663'. Drilled 885' of.12-1/4" hole. Drilled to 3762'. LOST CIRCULATION. Pumped pill of lost circulation material. Still no returns. Pulled to 2262' and circulated and mixed lost circulation material. Pulled to 1431' and conditioned mud.. Ran in and drilled to 3785'. Continued to lose some mud. Pulled to 2200' while mixing mud. 3548 3785 ' Cook Inlet ......... '"' '- '"::"- ~ ................. ~ DIVISION OF MINES & MINERALS Apri!., 1966[ (Cent'S) 27 ~ 3785 ~ 6296~ Drilled 511~ w~th full returns. TSN, R13W 28-3b 4296 5700~ Reamed from 4136' to 4296'. Drilled 1404' of 12-1/4" hole May, 1966 1 5700 i. 5948 Drilled 248'. Twisted off at cross-over sub while pulling out of hole Left 213' of FISH in hole with top of fish at 5735'. ~ ~948'! 616~~ Ran t~ hole with Bowen Over§hot, bumper sub and hydraulic Jars, to : 5720'. Circulated tools clean. Engaged fish and pulled loose with ~ 30,O00f~ pull. Drilled 214'. · 3-4 6162 ! 6723 Drilled 561' of 12-1/4" hole 5 6723 ~i 6838 Turbodrilled to 6762' Drilled to 6838' Broke pin in driltrol Left I 68' F.ISH in hole with top of fish at 6770'. 6 6838 i 6962 Ran in hole with Bowen socket, grapple and jars. Circulated and ! washed over fish, pulled out of hole and recovered fish· Reamed from 6780 '-6838' Drilled 124'. 7-8 6962 i' 7366 Drilled and reamed 404' of 12-1/4" hole. 9 7366 ~ 7460 Cleaned out 20' fill. Reamed and stuck turbodrill. Pulled loose and ~: ran survey to re-orient tool. Lost survey in pipe, tripped to ~: recover· survey tool. Oriented survey tool and reamed fr~om 7336' t~" ~ ~ 7366'. Drilled .94' . 10 7460 I 7545 Turbodrilled 37'. Reamed from 7475' to 7497'. Drilled 48'. 11~'12 ....7565 I 7824 Drilled', turbodrilled and ,reamed 279' of 12-1/4" hole. ~ '' 13 -- . ! 7824 Pulled out with tight spot at 2300'. Oriented turbodrill and reamed 28' ~ i ' to bottom· Circulated and raised mud weight due to, hole caving. Reamed ~ j ' ' from 7800' to 7824'. LOST CIRCULATION at 7824'. Mixed and pumped lost ~ I circulatiOn material· -- ~_-~-~-_~:j~. ? `:~.-~.::.~`:.;:``~`~.~:~-.~-~`:7~``::~2~.--~.~.`:~.~z-~:..::.~.~.:~"~.~;:£~`~:~L.-.~%~.:.~r::~:;;~;~.;~. 18-5/8" 319.' 2280' 13~'3/8" 2280' 12~" '2280" 78241 Middle'Ground Shoal Cook Inlet 15-25 7824 26 8880 27 -- 28 9031 3O 31 June! 2-11 6-11-66 8880 Drilled, turbodrilled and reamed 1056' of 12-1/4" hole. 1 T8N, R13W 9031 = Drilled 151'. Wiped and conditioned hole for Schlumberger log run. Broke pin on drill collar while pulling out of hole at 4100'. Left 147' FISH in hole. Started running in hole with Bowen overshot, hydraulic jars, and bumper sub. 9031 9050 9050 -- I 9050 i 9050 1966 i: 9050 i 9265 9265 i10,57~ A-13-1 Finished running in hole to 8864' and cleaned out 20' of fill. Found top of fish at 8884'. Engaged fish and pulled out.of hole. Rigged up Schlumberger and ran D.I.L. Stopped at 5320'. Ran in hole with drill string. Circulated ho~ clean. Ran Schlumberger. DUAL INDUCTION LATEROLOG RUN 1~ 2280'-9040'. RAN BOREHOLE COMPENSATED SONIC LOG RUN 1, 2280~9025' ~ND PROXIMITY- MICROLOG RUN 1~..2278-9028'. Ran in hole with drilling assembly. Reamed and drilled to 9050'. LOST PARTIAL CIRCULATION. Worked drill collars through tight hole from 9050' to 9035'. Regained full returns. Circulated and conditioned mud for running casing. Wiped hole to shoe of 13-3/8" casing and found tight hole from 9000'-8910', 5100'-5050' and 2619'-2450'. Ran back in to bottom and conditioned mud. RAN 9-5/8" CASING - SHOE AT 9040' . (123'-47# Pll0, 5009'-40# N-80, 1462'-43~ N80, 1243'-47# N80, 1203'-47# Pll0). CEMENTED CASING WITH 1400 SACKS CLASS A CEMENT WITH 1% CFR-2, 200 cu. ft. water ahead and ~ c~] ~. water behind. Bumped plug with 2000 psi. Had good returns. ~ Flanged up BOPE. Rigged up Schlumberger and RAN SPERRY-SUN GYRO SURVEY. Tested blind rams - test OK with 2000 psi. Drilled out cement from 8940' to shoe at 9040'. Tested cas'lng, pipe rams, and hydril with 2000 psi. Tests good. Drilledl 215'of 8-1/2" hole. Drilled 1309' of 8-1/2" hole. L8-5/8": 319 ' :2280': 13-3/8" 2280' L2-1/4" 2280~9050" 9-5/8" 9040 8-1/2" 9050'10,574' ........ ~L, ~u~u uu. ~t. diesel oil. · 'tm~pecl IJ> bbls. oil down casing. Dropped plug, set packer at 8896' Tested packer with 1800 psi on casing. Set: packer at 8060'. Sheared Brown Oil Tool shear sub with 3800 psi. Ran wireline 1-1/2" O.D. tool to 10,550'. .Released rig at 5:00 A.M. 6127[66. ............. , ............... ena. .. ~ '18-5/8" 319'2280' 13-3/8", 2280' 12-1/4" 2280.' 9050~ 9-5/8" 9040' 8-1/2" 9050' 10,850' 7": 8956'-10,850' ' ~ PBTD 10,806 ' . RECEIVED OF MINES. & MIINERAI.$ ANCHORAGE D~4-12 state, of Alaska Department of Natural Resources DIVISION OF MINES AND M/~ Sec~ ..... 1 (!1)..~ ......... Petroleum Branch INDIVIDUAL WELL RECORD T. 8N R. 13 W S ..... Met idian Permit No. 66-15 Operator= . Shell Oil .C...om..~a_ny .......... Lease No, ADL 18754 or Owner ~S~ ; , ................ Loc. We 11 NO, --A-!3-1 Are a , Spud Date_.4:-.15~,66 .......... Drilling ceased Suspended Abandoned __ U. - 1552 Completed (F-GL-~) . 6~27-66 __. IP _L'.:~? _821 . _ B/D, 696 100 70 Issued 4-15-66 Location (Surface).!627, FSL Top Pro4uction Interval 550' FWL and 1300' FSL sec, 1 8000 MD (Bottom) _66Q'FWL and..1.980' 1898' FSL and 1214' F~ Sec,, 1 10~850 MD Gas_3~0 ............. M~/D, Bean_ 6.4...~./64 CP 80 ....... psi, TP 80 .: ...... psi Casing ~ __ size_ .... De?t.~_ Sx Omt Perf: 807,6 ~.~_ holes wsn Plugs: .10...850,.10,806, 3100 (?) 8099'-8144' ,8:' 177 '-8230'i .... ~ ' ': -- 8402 ~-8464 ~ ~ 8754 ~'8767 :~e S/~'_ 9oso~ ~oo ezz~'-~zee,; 8ess'-e~zo',; 8956 '- , -' 9159"85" ;9503"'46 ~ ~ 10~850 9836 ' -76 ' ;9908 ' 49'; 9983' -10~ 022 ~C~u~ [__ 10.4~4'-10.624' ~o~zc ~o~~o~s e ~o6o, - ...... ' P~ODUCTI~ HOrIZOnS Surface Mest Tested. ~e Dep~ Contents --.::- -. =- _H~ock ....... 9159 0il ~ Total Depth 1_~0850' Elevation 116' D~ F. 37,1° 3.6 Gray ___ 36.,0 ,~__~_API Cut_~% Year ' WELL STATUS Ja~.~ Feb Ma~ Ar__~_~__~ay June July Aug Sept Oct Nov Dec · Remarks: ~Cpntracto~,: Santa Fe Dri_!l~ng Company · , w--~~ E su~v~ ' ' dU~ ~ SURVEY TIME * ra COURSE TOfAL AitUN ~ OBSERVE~ EORR I C ¢ I E., F_ E, E E E .31,¢ (,,- ~'~.~,3. 9'./.S. ~ ......... ?. 7(,,. - 55.Z3. -[ g,g. 61. 7s.47. 75,12. 7,~. ?I . -~' ? $ . 7~,31. ¢37. Z?. z~' :. 41.5 l · . ee4~. 30 . : ,.5'~, '7'7 4sT. zt..! ZT. ~8. . . _ . 7/z.76, _ ~ '7Z ¢0 ' .. , ..~' eC£ - . . · I j ANGLE j DIRECTION OF INCLINATION ~IEASURED COURS DISPLACEMENT TOTAL DISPLACEMENT DEPTH OF ~NCUN j 'b~V MEASURED CORRE~_TiMErED I CC~J R~E TO rAL _._4-.I~ o 3coo VERTICAL DEPTH COURSE ]OTAL I AT I O1'4 i O I~SERVE'D ~I,$7 2so~.~z.~ ~- ' ', · ~o.,53 ~s.7~, 1~z'-44! ~¢.~g3 29Z5'.77 £~'/4t 'A,,/. O~i' ~ ' A/ /o ~_.,, ,&/ /o ,.N J D--_E j_ _ i CO~'R CORRECTED NORTH SOUTH I , t 08 E. 78.30 ;Ixl 07 E 77.01 ...... ~N' 08. E_ 7~.~ ......... · .~ O7 ~ 7?.Z~. ~ . . i ~'AST WEST NORTH SOUTH I EASt WE~JT ~o 7'0 _ //,// ?,7& 7.. 47_ .. ,~07.~3_.' CUSTOMER WELL. NO FIELD JcOUrSE i !,'v' // ."~i 3° ~N? o3 .~ i/v' /z..~'l. .i,v. o ~ .E. ~ /z ,~ ._.~,V. o9 E. A,/ /2. ~i A/ o~ E MEASURED courqsE tglSPLACEMENT NOF~TH SOUTHEAST WEST 75.10 . , I1.~0 7q~Z~:-'-~ .... -.11,7~. . ~ ~,i~ .~ ;12.77.._ I z?, .&.~. ~, qx. //,, >.¢ TOTAL I.~ISPLA( EMENT ?t,~/ ..... ~ ~/. ~,(,,. _. .~ 1.,., .. ._ 37(,~.71 '< !~ '~ 51 5'141, tz.. SURVEY TABULATION SHEET I MEASUI~ED CORRECTED DEPTH TIME COI.,IIt~::~C.t TOTAL VERTICAL SURVEY .,o. ,,,o DATE MEACJURED COURSE DISPLACEMENT TOTAL DISPL~ACEMENT NORTH SOUTH EAST WEST NORTH · SOUTH EAST WEST ! : i/O&3,tO. . :34- STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LAND FI F' F' I I~- E LEAS~ ~.M~EE ADL18754 LEASE BE UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS State ........ _A__~ ~_s___k_ a. _ ..................... Borough ......... _K_e__n_ a_ .~ ........................ Field .... _M_ i__d__ .d__l_e_ __._G_r. _o___u__n_d~__S_h_ .@__a..1._ ............................. Th, e followir~ is a eorreot report of operatior~s and. prodz~e*ion (inet~dir~ drillir~ and produein~ wells) for tAe rnor~tl~ of ...... __J__ug__e_ ............................ 19_6_.6_ ............................................................................... ........................... ............................... ........ ......... ....... Phor~e ................ _2_.7_.2__7_9_.5._~1_. .................................................. ~l~ent' s title ._D__ '_!Y. '_%_s_*9__n____P__r__q_d..u_c__~_%__o_.n.__..Y~___n__a_~g_r SEC. AND S..A._S Dr: Raj Ma( Pe~ ;o%. BA~gELS O~ O~L CU. F~. or OAS (In'thousands) ho eeo 10,8 logs. r ~o. 10,850' at 8956', ou~h 4 holes '. 4]holes / foc lowing: 8390-839~', ', 8754' ~1~9-9185' , ', 9692' ~9~3-10,022 ' 179 ' 2J7/8" tub dual pac] ~d~ shUt-in (]ALLONS OF GASOLINE RECOVERED cemented 8099-81 8767', 8 ,9708', 9 10,189- :er at 8( BARRELS OF WA~ER (II none, so state) with 35 REMARKS (If drilling, depth; if shut down, oause; date and result of test for gazoliae content of ga~) sacks. $4'., 817 '-8230'. 773-8786 , 836-9876 10 438' ~ :,454-10,624' 50 ' and ingle packer j U 'NOTE.--There were ................................................ runs or sales of oil; ................................................ M cu. ft. of gas sold; runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. Forn~ No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATIO. N COMMISSION Effective: Suly 1, 1964 LAND [2F f I E:E L~^SE ,U,~R ADL 18754 LEA~E ~R ~NIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS State Alaska Boro.gh Kenai Middle Ground Shoal .......................................................................................... Field ............................................................................... Tke followin~ is a eorreot report of operatior~s and production (inel~dinff drillinff and prodUein~ wells) for the month of ___: .... __lyi_a~v ............................ , 19__6.6 .............................................................................. ./l~en~'s address .......... _~_~__O____S__e__v__e_n~h__&v__e__n_u_e ..... , .............. Company .... ~__$h~J~___OJ_L_C~mp_arry ..................... · Anchora~.e~ Alaska , . ' ~ ' ' Siffned ...............~_~_ '_j~q~___~_~ .... : ....... Phone .......... 272-9541 .4~e~t's title Division Production Mana.g. er TwP. BAaEELS or Orr. ~ or ],g (In thousands) .G.S. A- 4" hole 5 1' 8" cas ing " 9031- GALLONS OF BARRELS OF GASOLINE WATER (If RECOVERED none, so state) , ran I~gs. with 1~00 sacks RE~VIARKS (If drilling, depth; if shut down, oause; date and result of teet for a~sollne content of gas) NOTE.--There were ................................................ runs or sales of oil'. ............................................... M cu. ft. of gas sold; · runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines &' Minerals by the 6th o£ the succeeding month, unless otherwise directed. Shell ,Oil C~np.,auy- 130 Sev~h Avenue ,L~ecrolmm .Supervisor Form No. P 4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LAND [~FFIIZE LEAS~ N"M.~R ADL 18754 LEASE mR. UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS 'State ......... _A___l__a.._s__k_ .._a_ ..................... Borough .........._K__e_. .n_a_ '_z. ........................ Field ........ ~ ~ _d__d i_ _9_ . G__r?__u_.n_ __d___.S_~_o__a__! ......................... TI~e followir~ff is a eorreot report of operatior~s arid prod~etior~ (ineludir~ drilli~ and Pr°dueinff wells) for t~e montk of ............. A~_~ ................... 19.~_, ~ ~ . ~,~, ~ ~aa,e~ ........ ~P__~~__3~s~ ........ , .............. Co~p~% .... ._.~__~_~_3_~_9_~9.~:~'_ ................. · ~chorage~ Alaska . · Siffned .: .~ / ~' )~ Phone .... 27 2- 9541 ' Jye~t,s title ~v E s ion~:~~_~ c Eon ~ana.~er ~t. WELL I D~rs. - M.G.S d ~o .~m. ~'1~-~. d 1r8-_5~8." hc~le 319'22.8 0d113.~1/8" c~as±ng at: 2 d ~2-176'~o]1e 2285-57 -1 ,ith 2600 slacks. OlVIS ECEIVED MAY 41966 ON OF MINES & MINERALS ANCHORAGE 'NOTE.--There were .......... ..N...o. ....... i ........................ runs or sales of oil'. ................. ~Q ......................... M cu. ft. of gas sold; ............................... · ..N..o.. ....................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 April 19, 1966 Subject: Middle Ground Shoal Field Shell Oil Company-Platform Well A-13-1 - State Lease ADL 18754? APR g 11966 State of Alaska Department of Natural Resources Division of Lands 344 Sixth Avenue Anchorage, Alaska 99501 DIVISION OF MINES & MINERAL~ ANCHORAGE Attention Mr. Erle Mathis Gentlemen: Please be advised that on April 15, 1966, Shell Oil Company, as operator for the Shell-Atlantic-Standard of California group, spudded the captioned well.from conductor 8, leg 1 of Platform A. The location of Platform A is 1627' N, 435' W of SE Cor., Section 11, T8N, R13W, S.M. The well will be directionally drilled to a location falling in the~of Section 1, T8N, R13W, which is included under our leas~e~~%~8~'54. Yours very truly, TSC:m T. S. Cate Division Land Manager %% 1966 Stets A..13-1 It Lit .the detb~ .of h 011 and h ~~ C0nl~tt.e that SPp~l tho proposal to th~. mt.tr. Anchor&se, AXasdui 99~0~ Dlvimton Land l~ena~ Shell Ot% Compauy &30 Seventh Aveuae ~Se) Alaska 99501 Ded~ ~mmaa ,~. Mazai~il, dF. l~t:zolema Super~iaoz '/ . Znc. Divo of Hines and Hinerals. DIVISION OF KII~S AND ~S Thomas lt. ~shall, Jr'. Petroleum Supervisor April 18, 1966 Filins Fee Enclosed is check lgo. LA &1512 for $50.~ and approved ~plicati~ for permit from Shell Oil' Cm~any for lilS State A-13-1. Eric SHELL OIL COMPANY 4:~0 7TH AVEN U E anchorage, ALASKa ggS01 Subject: Cook Inlet, Alaska Middle Ground ShOal Field Shell Oil Company Platform A Well A-13-1 Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Attention Mr. Thomas Marshall Gentlemen: Enclosed for your consideration please find Application for Permit to Drill, in triplicate, dated April 12, 1966, along with our check No. LA 41512 for $50.00 as filing fee. This application refers to Well A-13-1, a develx~nt well to be directionally drilled so as to produce from the~N~4;-SW/~ of Section 1, T8N, R13W S.M. (ADL 18754). ~x~ Z~ ' Since we propose to spud this well within a week, we ask your earliest handling of this application. Also, at your convenience, please forward the writer two copies of the Oil and Gas Conservation Regulations.. Thank you for your cooperation. Yours very truly, TSC:m Attachments T. S. Cate Division Land Manager RECEIV['9 APR 13 1966 DIVISION OF MINES & MINEJ~k$ ANCHO~GE FOTm P--1 · CTATp' NC AtASKA - ('Other.instructions 'on ~.~..~ vr - , ' reverse side) -: GAs cO,NsERVATION 'COMMISSION ,~, ' APPLICATION FOR~'PERMIT TO' DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRIL.L .1~ DEEPEN [-] PLUG BACK: []' .~ b. TZPE OF WELL ,.. '. OIL MULTIPLE WELL WELL ~ OTHER ZONE r ZONE ~. NAME OF OPERA~R a. a~RE~ or o~a~o~ At ~urfaee 1627 ~ff#I,' 'Co~d'Uc'fi0r #8 of P'Iat'fo At proposed prom zone Please see #23 below 14. DISTANCE IN MILES AND DIRECTION FROM NEAREBT TOWN OR POST OFFICE$ Effective! 'J~!y '1; 1964 5. 'LEASE DESIG'NATION AND SERIAL NO. ADL .i8754 IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT AGREEMENT NAME 18 miles N.W. of Kenai 1§.. DISTANCE FROM PROPOSED* 16. NO. OF ACRES IN LEASE 17. NO. OF ACRES ASSIGNED LOCATION TO NEAREST TO. THIS WELL PROPERTY OR LEASE LINE, FT. (Also to nearest drlg. unit linei if any) 3300' 3746 acres 160 acres is. DISTANCE FROM PROPOSED LOCATION* M.G.S. #1 19. PROPOSED .DEPTH 20. ROTAE¥. ;OR :CABLE TOOLS TO NEAREST WELL, DRILLING, COMPLETED, On APPLIED 'OR, ON THIS LEASE, FT. (Suspended) 225'_+ 10,500_+' Rotary 21. ELEVA~ONS (Show whether DF, RT, GR, etc.) [ 22[.~ APPROX. DATE WORK WILL STARTs 116' D.i. [ 4-18-66 23. PROPOSED CASING AND CEMENTING PROGRAM sIZE OF HOLE WEIGHT PER FOOT SETTING DEPTH ~UANTITY OF CEMENT . Section. 1,.TSN, R13W, S.M. 12. B.Ol%OUGH SHt 13. STATE Kenai I Alaska SIZE OF CASING 18-1/2" 13'3/8" 12-1/4" ' 9-5/8" 8-1/2" [7" 61.0# 2350 '_+ 40-47{~ 9000'.+ 29# 10,500-+' 2600~ sacks 700-+ sacks 600_+ sacks Well 13-1 wi'il be drilled directionally from Platform A, Leg #1, Conductor #8, to a point in the NWl/4 SW1/4 of Section 1, TSN-R13W, S.M. Sub-surface location of the producing interval is as follows: Top of interval - 550' E, 1300' N of SW CDr. of Section-8000' (M.D.)-6050' (TVD) Mldpoint of Interval - 600' E, 1600' N of SW CDr. of Section-9225' (M.D.)-7165'(TVD). Bottom of Interval - 660' E, 1980' N of SW CDr. of Section-10,450' ~.D.), 8315' (TVD The well will be completed to produce from separate tubing strings, the upper interval being 8000-8800' and the lower interval being 9040-10,450'. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true v~rtical depths. ' Give blowout preventer program, if any. _ . 24. I hereby ~e.~.r.~in~e and Cg~rect. S,,NE, ~~~~ TITLE Division Land Manager hATE 4.12-66 (This space for Federal or State office use) PERMIt' NO. ~¢ --/ ~ CONDITIONS OF APPROVAL, IF ANY: // TITLE APPROVAL DATE THOMAS R. MAIL, HALL, JR. Executive Secretary Alaska oil & Gas Conservation Committee RECI IVEO *See Instructions On Reverse Side APR 13 1966 DIVISION OF MINES & MINERAt, B ANCHORAGE DRILLING, GASING AND BLOWOUT PREVENTION PROGRAM WELL A-13-1 MIDDLE GROUND SHOAL PLATFORM A COOK INLET~ ALASKA le e me e e . Ye Se e Move rig over 24" sub-conductor #8, leg #1. Install 20", 2000 psi Hydril preventer. Drill 18-1/2" hole to 2350~', and run 2350~' of 13-3/8", 61.~, J-55 casing. Cement with 2600~ sacks,of A.P.I. Class "~' cement - last 200 sacks treated with 2% CaC12. Land casing and flange up 12", 3000 psi preventer stack consisting of Double Shaffer Gate and G. K. Hydril. Test B.O.P., riser'and casing to 1500 psi. Drill.12-1/4" hole to 9000~_' and run 9000~_' of 9-5/8" (9000-7800', 47# P-110; 7800-6600', 47# N-80; 6600-5100', 43.5#, N-80; 5100' to casing head, 4~ N-80). Cement with 700 sacks Class G cement. Land casing and flange up 12" 3000 psi B.O.P.E. on 10", 5000 psi riser system. Test casing and B.O.P.E. to 2000 psi. Drill 8-1/2" hole to 10,500~' and run 7" 29#, N-80 .liner to 10,500' and hang at 8900'. Cement with 600 sacks A.P.I. Class G cement. Cle'an out cement and perforate 8000-8060' 8250-8330' 8650-8800' 9040-9070' 9375-9425' and at intervals be~r~een 9650-10,450' , · Run two strings of 2-7/8" tubing with single packer at 8850~' and dual packer at 7950'~. Displace mud in tubing with diesel oil and put well on production. TSC:m 4-12-66 RECEIVe',9 APR 13 DIVISION OF MINES & MINERAL~ ANCHORAGE ADL': 18754 II 14 I I I I ! i I ! I I I I I I I , I t ! 1 .. 12 I' A'1:5- I PI.;tBI~/C L 41110 OE$Ct~IPTIO/V ' LOCATION OF LEG NO. N & 455~W OF. SEC. I I,T8 N~ R 1:SW, S.M. LOCATION OF PRODUCING ZONE , , WELL A- 1:5-1 I I I i I I I I I BY IFf" E.B.M.,.' 1966 SHELL- ATLANTIC R,'l:$:W. S.M.' DIVISION OF MINES & NUNERAI~ OIL coMpANY Z-21-112 A-13-1 IN SEC. I INLET-.STATE OF ALASKA 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. ~ COMPANY SHELL OIL COMPANY ''REC-E.tV t) I ~1 II I~11 ..... . ..... :. .. AUC11'""" , ,- o - WELL · A-,3-i '' ". ' M R U ANCHORAGE ...... I=1 _Ii;I I-tIFIELD - I DDLE G 0 ND SIlO. AL ' .. ,~'T':. -,.,'"~_.....i' :: -',-:· · · . ' !g}/ I fi--. o~J 14 J& 3,27' WEST OF CENTER LEG ~.. BSL, PI, IL,' · ! =zq.6 !1627' NO. '& 435' 'WEST OF SE CORNER. GRN, CBL,. Ou~0 C . ' (SM) ~ Permanent Datum: _ _.!~_'._ff., ............. ' _, E~ev .....! 16.' i' I Log Measured From -- D_ ,.F _, ....... , .......'Ft. Above Perm. Dafum Drilling Measured FrOm D, F, ' G.L.' .... I ' v ' ' i''1 , ' ,,," ii , ' J'~'~ No. 10NE '.TWO 'J'.THRE E ~ o6 so -~'J ..~ o8 5o ~ 1'08 54 D~eepp~_-E~LDriller 'J903 I' h,.',L.%-ge-r- 1-.9 od4' . ~ 06 S2 I Btm. Log Interval J9040 '.". 10648 ~ 0850 J To Log Interval .12~80 P _ . 9040 . 0648 ' Casing--Driller Jl.'t.~ @ 278'0 9~ @90.40 9-~ @ 9040. @ ' I_Casing.-Lpgge_r J2~§o , ~ ,' go40' go40 IBitSize 112-~ "/ 8½. --~8-~ JT)~pe Fluid in HoleJFRESH N/ .- XP-20' -XP-20 J ~CflUSTIC' ' - I Dens. J Visc. pH J Fluid' Loss Source of Sample Rm (~' AReas. Temp. Rmf ~? Meos. Temp. Rmc (~) Meas. Temp. Source: Rmf Rmc R.m (~) BHT '1'i-~ Since Circ: Max: Rec. Temp. .Equip. J Location Recorded By _ .. Witnessed By 76 'l 47 1l_..o CIRCULATED · i.8 .@ 82.°,F 1.,i7 @ 65°F 2'.r86 ,~ 68 °F ivlJ H 0,60 @ 157'F ,1½ HRS, 157 °F. C 18 01' ,,/~LA"SKA COLLJNS ' MUE H_L.. BERG ER~ 74 [ 55 ~o,9 '-~ ;IRCULATED C ,1.91 ~61 °F 1-,-[? @ 6'1 ' °F 2.83 @ 65 °F .0..8i @145°F 5 HR .145 76 / 51 I R CU'L'i~Y-E D'_' . 1.93('~ 65-°F .2.~,97,@ 68" ~F · M-~;;' ! i~ S F Jj 4 HRS ~ O' · 1 54 °F I~LASKAJK'AU'FFMANC 1, .8 O JALA SKI C180 KAUFFHAN I4CKEHANEY ' ' J,IDEN ~ ~" ~- - ' ~111 i IIIIIH III i ..... i · i I J mi . . ~ °F .! @ °Fi I ..... .. .,~ . 4000-- 4100 4200 4300 .. 4400 58OO _ . 59OO 6000' ' 6100 6200 6300 · . i 710~ 7200 · 7300 3400 7500 7600 78oO. · 7900 8000 mOo .: 8200 · e~oo . o ~oo o o ~;o ° ° °°°i'~ 9100 9200 ~'ro-~o,o"i~' ,,' 9~Oo ·., 9400 · · J~ '9500 9600 9700 9800 9900 I0000 I0100. 1 ' I 10400 .. .' 10500 i. 1'0600 [t 10700B L ill- 2 10600 t,