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204-236
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg J Z DATE: Monday,October 23,2017 P.I.Supervisor '(I i U` (1 7 SUBJECT: Mechanical Integrity Tests t HILCORP ALASKA LLC C41-23RD FROM: Matt Herrera MGS C41-23RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MGS C41-23RDAPI Well Number 50-733-20163-01-00 Inspector Name: Matt Herrera Permit Number: 204-236-0 Inspection Date: 10/20/2017 Insp Num: mitMFH171023090616 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C41-23RD ' ;Type Inj W •TVD 8612 " 1 Tubing; 3550 3550 3550 3550 - i PTD 2042360 Type Test SPT Test psi 2153 " IA 124 2253 - 2240 2235 0.5 BBL Returned: 0.5 " OA 0 " 0 0 0 - BBL Pumped: � Interval 4YRTST P/F P Notes: SCANNED F-P Monday,October 23,2017 Page 1 of 1 • From: Patricia Bettis To: Well History File: PTD 204-236 Date: January 13, 2017 Re: Well Name Change At the request of Hilcorp, the well name for MGS C41-23LN was changed to MGS C41-23RD, effective January 13, 2017. SCANNED JAN 2 6202 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 'º- 0 ~ - ~ 3 &> Well History File Identifier Organizing (done) ~WO-Sided 11I11111111 III" III o Rescan Needed 1111111111111111 III R,SCAN v} Color Items: o Greyscale Iterns: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date 7/ I:J-j () 7 Date 7 ¡1~/07 ~ 00 + cJ () = TOTAL PAGES g 0 (Count does not include cover sheet) /5/ o Other:: BY: 8 /51 llif Project Proofing BY: ~ 111111111111111111I 151 rYlP Scanning Preparation BY: Date: p Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY 8 Dale 7/1:)./ D7 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO /51 W1 f NO BY: Maria Date: 151 11I111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 111111111I111111111 10/6/2005 Well History File Cover Page.doc 0 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 25,2013 TO: Jim Regg 2 � Ibl i I 13 P.I.Supervisor SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C41-23LN FROM: Jeff Jones MGS C41-23LN Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,3E2— NON-CONFIDENTIAL Comm Well Name MGS C41-23LN API Well Number 50-733-20163-01-00 Inspector Name: •leffJones Permit Number: 204-236-0 Inspection Date: 9/16/2013 Insp Num: mitJJ130924183511 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2042360 YP J __ p T T o o T e In TVD IA o 0 C41 23LN W 8612 0 2330 - 2290 • X280 i e Test sPT est psi 2153 • F OA PTD TYP - _ __ 1 Interval IN1TAL IP/F P Tubing 3450 3500 3500 1 3500 I Notes: Initial MIT. I well inspected,no exceptions noted. , Wednesday,September 25,2013 Page 1 of 1 f STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well 0 Plug Perforations ❑ Perforate 0 Other U Eliminate tbg x csg Performed: Alter Casing ❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ annulus pressure Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator XTO Energy 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development J Exploratory 0)04-236 - 3.Address: 9127 S Jamaica St,Englewood,CO 80112 Stratigraphic❑ Service Z 6.API Number: 50-733-20163-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0018756 . Middle Ground Shoal C41-23LN . RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MGS E, F, G Oil Pool ' AUG 2 9 2013 11.Present Well Condition Summary: AOGO Total Depth measured 14,410 feet • Plugs measured NA feet C true vertical 9,178 feet Junk measured NA feet Effective Depth measured 12,460 feet Packer measured 11,617 feet true vertical 9,697 feet true vertical 8,615 feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1653' 10-3/4" 1653' 1584' 3130 psi 1580 psi Intermediate 9622' 7" 9622' 7249' 8160 psi 7020 psi Production 2780' 5" 12039' 8751' 10140 psi 10490 psi Liner 2562' 3-1/2" 14410' 9178' Slotted Slotted Perforation depth Measured depth 12280-14370 feet - „ ', yz 0�' w 0' £01w True Vertical depth 8758-9184 feet Tubing(size,grade,measured and true vertical depth) 2-7/8",6.5#,L-80,EUE,8rd;EOT©11,635'MD,8,621'ND Packers and SSSV(type,measured and true vertical depth) 5"TIW HB-BP Perm Pkr @ 11,617'MD,8,608'ND;'X'Nipple©341'MD,341'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13. Representative Daily Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A 106 0 psi 3450 psi Subsequent to operation: N/A N/A 100 0 psi 3450 psi 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development[] Service R/. Stratigraphic ❑ Daily Report of Well Operations yes 16.Well Status after work: Oil El Gas ❑ WDSPL❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP p SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-260 Contact Sandra Haggard Email Sandra Haggardxtoenergy.com Printed Name Title Regulatory Analyst Signature ter` Phone J `�J1 ~,_q 72 Date 4/4g//.3' 1 Form 10-404 Revised 10/2012 vl W t./i,13 Submit Original Only 101141-/b11 � ", 0c5rb TO • •• ENERGY RECEIVED AUG 292013 AOGCC August 26, 2013 Alaska Oil and Gas Conservation Commission Attn:John Norman, Commissioner 333 W.7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Re: Form 10-404, report of sundry well operations Objective: Pull tubing, Repair Well and Perforate Middle Ground Shoal#C41-23LN sirWater Injection Well Middle Ground Shoal Field E, F&G Oil Pool Cook Inlet,Alaska API 50-733-20163-01-00 XTO Energy hereby submits the report of sundry well operations to pull the tubing, repair well and perforate. Enclosed are the following attachments: 1. Form 10-404 Report of Sundry Well Operations 2. Workover Daily Activity Report 3. Current Wellbore Diagram If additional information is required, please contact me at 303-397-3672 Sincerely, z3it, Sandra Haggard, Regulatory Analyst Copy to: Bola Adeyeye, Operations Engineer, Office: 303-397-3606 • Daily Activity and Cost Summary_s41? hAucro ENEFIGY Well Name: Middle Ground Shoal C41-23LN API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 TO8N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Jobs Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date COMPLETIONS Recompletion Tubing Change to Repair leak 11/27/2012 00:00 11/28/2012 00:00 Objective Summary 15 �y:operis Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 11/27/2012 11/28/2012 0000-2400 Set out welding shop koomey house and welding shop equipment,center rig over leg 2 Rig up jacks and move rig south over leg 1 Remarks#2 Rig move costs divided 5 ways for next 5 workovers Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 11/28/2012 11/29/2012 0000-2400 skid rig to leg#1.Remove 10"flow line from pump room and walk way between shop,clean and re-install.cut out washed out 4"high pressure mud line valve on#1 pump,trouble shoot crown beacon light,rig up rig lighting move jacks to pull rig East. Remarks#2 Rig move costs divided 5 ways for next 5 workovers Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 11/29/2012 11/30/2012 0000-0600 Set in welding shop equipment,set koomey house,set south side shop 0600-2400 Wind 30 mph,wait on moving North side shop no major crane work.weld in new 4"valve on#1 mud pump high pressure line,cleaning on platform,plumb in jet lines to 10"flow line,connect steam and air lines between South side welding shop and pits,work on lighting in derrick,trouble shoot electrical on rotary table,screw down tin on pits and South side welding shop.(walls)work on high pressure mud line pressure sensors,and mud pump rod oiler systems. Remarks#2 Rig move costs divided 5 ways for next 5 workovers Weekly safety meeting with drilling crews Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 11/30/2012 12/1/2012 0000-1200 High winds preventing crane operations for welding shop,finish installing 4"valve on mud line,clean 6"choke flow lines,With 2900 crane transfer equipment-iron racks,mud matieral,filter skid and filters,backets etc to pipe rack and to leg 2 clearing south side platform for rig skid. 1200-1800 Wind starting to diminish Continue transferring equipment to pipe rack,set North side welding shop,make up service lines,install hand rails on pipe rack,set walk way to west crane,and stairs from pipe rack to main deck welders fab and work on pit suction lines for new isolation valve. 1800-2400 Wind pick back up 30 mph-crane work minimal,make up firewater line at welding shop, hang tin on welding shop(walls) Remarks#2 Rig move costs divided 5 ways for next 5 workovers Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 12/1/2012 12/2/2012 0000-0400 High winds continue crane work minimal.Prep for skidding,transfer equipment to pipe rack from south side decks.service rig jack unit. 0400-1200 Start skidding rig East towards leg#4 Install BOP trolly beam extension.hang choke house, installing handrails,remove work over hatch on leg#2 install production hatch,weld step to crane walk around,replace valve in pump room breaseway,work on steam piping in subase,installing isolation valves on steam heaters. 1200-1800 Transfer change house and parts house from leg#4 to leg#2 clear deck on leg#4 repair pit room exaust fan guard,replace suction valve#5 pit,fab stand for N2 back up for man riders,trouble shoot wiring for rotary table,replacing steam lines in subase.transfering equipment from Leg#4 to pipe rack and leg#1  1800-2400 Continue transfering equipment off leg#4 set Install work over hatches on Leg#4 Rig up air to rig for using tuggers,hang blocks to trouble shoot leak on weight indicator,lay out electrical cables accross deck,and re-route around to north side of rig.Set in poorboy gas buster in choke house. Remarks#2 Rig move costs divided 5 ways for next 5 workovers Construction Summary#3 www.xtoenergy.com Page 1/8 Report Printed: 8/28/2013 Daily Activity and Cost Summary_sls I tlGY Well Name: Middle Ground Shoal C41-23LN APIAJWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 TO8N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) iOr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 12/2/2012 12/3/2012 0000-1200 Continue stringing electrical cables to North side of rig.Rig up to skid top section rig South, set drilling line spool on main deck,attempt to skid top rig sub South,trouble shoot and repair jack, break pony sub loose,work on steam lines in subase,work on suction lines in mud pits,set West crane boom stand and weld down on leg#2 re-terminate wiring for rotary table,change out contact blocks and switches on iron roughneck.working on replacing hand rails,and cleaning decks. 1200-2400 Jack upper subase South,set choke manifold in choke house,hook up vent lines,close choke house roof,hang steam heater in choke house,hook up electrical rig floor,work on suction lines in pit#3 remove 2900 crane boom stand off leg#4 rearange and clean up decks,weld up hand rails on south side stairs going to production level,Attempt to jack rig East,work on rig jacking unit. Remarks#2 Rig move costs divided 5 ways for next 5 workovers Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 12/3/2012 12/4/2012 0000-0630 Work on rig jacking unit.organize equipment on decks 0630-1000 Skid rig East towards leg#4(pulling rig)install new suction line pit#3, 1000-1230 Move jacks to push Change out bad bladders on Koomey unit bottles. 1230-2400 Skid rig to leg#4(problems with jacks and grippers)replace leaking steam line in pump room hallway Remarks#2 Rig move costs divided 5 ways for next 5 workovers Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 12/4/2012 12/5/2012 0000-1800 Skidding rig attempting to center over well,(problems with jacks,grippers and power unit- had to move upper jack to lower skid)string electrical lines and plug in rig.Rig is skidded as far East as necessary 1800-2400 Move jack to upper section skid and center over C 41-23LN make up storm clamps,work on replacing hand rails on south side deck. Remarks#2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 12/5/2012 12/6/2012 0000-1200 Rig up steam and air lines to rig,tighten storm clamps,remove lower jacks from skid,and scope in upper jacks,rig down jack unit.Skid koomey house over,make up trolly beam in welding shop.Attempt to take on drill water,line on platform plugged,Back load boat. 1200-2400 Work with welder on handrails South side platform,Remove hose for taking water from boat,put in shop to thaw.Fix steam heaters in subase and rig floor,run air control line for koomy remote on rig floor,pick up electric cables off pony sub deck,work on steam lines in pits,clean up welding shop.Set beaver slide. Remarks#2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit.(day 2) No drilling Electrician Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 12/6/2012 12/7/2012 0000-1200 Install landing from doghouse artic entry to beaver slide,orginize decks,clear water and ice from boat transfer hose and PT hose,good test.cleaning in welding shop,pump room.welder working on hand rails beaver slide,pipe rack.Repair seals on spear hydramatic side drawworks,fix leak on dead man for hook load,Work on accumulator, 1200-2400 Continue assisting welder with hand rails,on platform,install water hose on North side for taking on water.install knee braces under dog house,pressure up koomey check for leaks,continue cleaning and orginizing decks and rig Remarks#2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit.(day 3) No drilling Electrician Construction Summary#3 www.xtoenergy.com Page 2/8 Report Printed: 8/28/2013 • •io Daily Activity and Cost Summary_sls I: PI Li Y A Well Name: Middle Ground Shoal C41-23LN API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 TO8N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) ]Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 j 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations '; ;;., x Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 12/7/2012 12/8/2012 0000-1200 Stage equipment for back load,clear rig floor,palitize 3-1/2 tools,work on steam heater in pits,screw down tin on south side pit wall,start rig engine check DC power,House keeping on platform. Welder work on hand rails and stairs. 1200-2400 Assist production electrition work on rig electrical,(gas sensor,480 for iron roughneck,and communication)hang 2"hose on stand pipe,ajust drawworks brakes band rollers,work on hand rails and plate on back deck work on choke manifold,unload boat,tak on 29000 gal water. Remarks#2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit.(day 4)release rep No drilling Electrician Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 12/8/2012 12/9/2012 0000-1200 Work on choke manifold,(vent line on poorboy,flow lines outlets on choke)lay out koomey lines install 2"demco on circ stand pipe,set cat walk,organize decks. 1200-2400 Removing and changing plate on pony sub,Work on koomey lines,cleaning in celler,put up rig floor drain hoses,hang 10"hall way work on choke flow lines.Service 3900 crane(VVest)orginize decks. Remarks#2 Rig move costs divided 5 ways for next 5 workovers No drilling Electrician 24hr shut in on well,built to 240psi,Slickliner rig up to pull lower dummy from GLM in A.M.on 12-9-12 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 12/9/2012 12/10/2012 0000-1200 Work on hanging 6"flow line off poor boy,cleaning in pump room,celer,and rig floor.lnstall 4"flow line from choke to mud pits.Replace fresh water line valve in pits,organize decks,assist welders 1200-2400 Hang 6"choke flow line,from rig to pits,Cleanining and orginize celler,decks,pump room, Assist electrician trouble shooting electrical problems with drawworks and rotary table,test mud pumps Good assist welders,prep for back load. Remarks#2 Rig move costs divided 5 ways for next 5 workovers No drilling Electrician,Production electrician came from A trouble shoot electrical problems. Slickline pull dummy from GLM#10 10667'SLM(was unable to latch on to pull from GLM's#12 or#11) well has 500psi shut in. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 14.0 12/10/2012 12/11/2012 0000-1200 Dress elevators and slips for 2-3/8"pipe.move rig jack,rig up lazy susan under cuttings auger,finish make up 4"high pressure mud line,put 50 bbls FIW in pill pit for testing lines,work on installing plate on back deck pony sub,Assist production electrician trouble shoot power problems for drawworks,and rotary table.work on 10"flow line,assiat production take on 14000 gal fuel. 1200-2400 Back load boat.assist electricians repair drawworks and rotary table.finish 10"flow line,lay plate on back deck pony sub,build stairs for pony sub,cleaning and orginizing sub,and decks, assemble derrick board on rig floor. Remarks#2 Rig move costs divided 5 ways for next 5 workover Production electrician came from A trouble shoot electrical problems. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 15.0 12/11/2012 12/12/2012 0000-1200 hang derrick board south side derrick,turn on water to rig,clean&orginize decks,R/U circ line to choke manifold,circ.&check for leaks,Trouble shoot blockage in choke manifold. 1200 Cont.trouble shoot&remove blockage in choke manifold,remove fluid in pit#3&start repairing leak in suction line Remarks#2 Rig move costs divided 5 ways for next 5 workover Production electrician working with new drilling electrician. Construction Summary#3 www.xtoenergy.com Page 3/8 Report Printed: 8/28/2013 • Daily Activity and Cost Summa rY_s# Well Name: Middle Ground Shoal C41-23LN APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 TO8N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) 1Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 ; 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 16.0 12/12/2012 12/13/2012 0000 Repairing leak in suction line in pit#3 0900 Transfer brine from storage tanks to pits 0930 PJSM,Kill well w/10.3 ppg CaCl2 @ 4 bpm, 1600 psi tbg pressure,holding 700 psi back pressure,8.4 ppg returns,9.5 ppg returns after 1500 strokes,pumped 430 bbls(80 bbls over calculated volume) 1700 Monitor well-OK 2000 R/D circulating lines 2100 Set BPV&N/D tree&set out same Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 17.0 12/13/2012 12/14/2012 0000 N/U BOPs,changed out double gates Remarks#2 Replaced double gate rams with Cameron Type U because we needed the better variables Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 - e 18.0 12/14/2012 12/15/2012 0000 Cont.N/U BOPs,Test gas detectors, 1400 Test BOPS,250/2500 annular,2507500t,all other equipment Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 19.0 12/15/2012 12/16/2012 0000 Finish BOP test 0200 R/D test equipment&blow down lines 0400 M/U landing jt&pull hanger to rig floor,seals pulled free @ 90k,Up wt.83k 0500 Circ.&wt.up U 10.5 ppg 0730 Monitor well-OK 0830 L/D 2-7/8"Tbq and jewelry,NORM=2 2230 Change elevators&tong jaws 2300 Brine flowing out Tbg.,R/U and circ., 10.0 ppg brine returns, Remarks#2 287 jts 2-7/8"tbg Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 20.0 12/16/2012 12/17/2012 0000 Cont.Circ 2-3/8"Tbg and weight up light brine,5.7 bpm @ 910 psi,monitor well-OK 0100 POOH,L/D 75 jts 2-3/8"Tbg&seal assembly,NORM=2 0430 Set wear ring 0500 Trouble shoot and repair iron roughneck clamp mode 0700 M/U milling assembly,strap,rabbit&p/u DP 2330 Trouble shoot&repair iron roughneck spinners Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 21.0 12/17/2012 12/18/2012 0000 Cont.repairing spinners on iron roughneck 0130 Cont.RIH w/milling assembly,P/U DP,Tag Pkr @ 11,633' 1130 P/U Kelly&break circulation 1200 Milling on Pkr f/11.633'-U 11.635',Up wt. 150k,Dn wt 75k,Rot wt 100k,Tq 2000 ft/lbs, 1700 psi @ 3 bpm 1800 DP twisted off,wait on Overshot Remarks#2 Construction Summary#3 www.xtoenergy.com Page 4/8 Report Printed: 8/28/2013 • Daily Activity and Cost Summa rY_se E EHGY Well Name: Middle Ground Shoal C41-23LN API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 TO8N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 22.0 12/18/2012 12/19/2012 0000 Cont.wait on fishing tools 1030 M/U Overshot,Latch fish @ 40'retrieved 1 jt. Run#2 TOF @ 71',retrieved 15jts DP Run#3 TOF @ 499',no fish Run#4 Latch fish @ 499',POOH,Break,inspect&make-up all connections Remarks#2 UD 5 bad jts.DP Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 23.0 12/19/2012 12/20/2012 0000 Cont.POOH,break,inspect&make-up all connections 1900 Wait on mud motor&tools . Remarks#2 Check rotary torque values Repair kelly spinner Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 24.0 12/20/2012 12/21/2012 0000 Wait on mud motor&tools 1200 M/U BHA&RIH,break circ @ 4000',9000'&10,000' 2200 Milling Pkr @ 11,635',Up wt 150k,Dn wt 85k,Rot wt 105k,Tq 3600 ft/lbs @ 20 rpm, 1100 psi @ 2.8 bpm Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 25.0 12/21/2012 12/22/2012 0000 Milling Pkr @ 11,636',Up wt 150k,Dn wt 85k,Rot wt 105k,Tq 3600 ft/lbs @ 20 rpm, 1100 psi© 2.8 bpm 0530 Push Pkr down hole U 11,823', 0600 Circ Hi-Vis sweep,Mill partially plugged,finish circ bottoms up 1030 POOH(wet) 2200 M/U Spear&RIH Remarks#2 Production using AC/DC Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 26.0 12/22/2012 12/23/2012 0000 Cont.RIH w/spear 0830 Spear Pkr 0_11,823', Up wt 135k,Dn wt 75k, 1250 psi @ 1.1 bpm 1000 POOH,retrieved all 35'of fish 2200 Pull wear ring 2230 R/U&test BOPS Remarks#2 Production using AC/DC Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 27.0 12/23/2012 12/24/2012 0000 Cont.Test BOPS 1100 Set wear ring 1200 Blow down choke&kill lines&manifold 1300 M/U mill&mud motor,R/U Weatherford to JAM tbg 1330 Weatherford trouble shooting equipment 1700 P/U 2-3/8"flush joint tbg Remarks#2 Production using AC/DC Construction Summary#3 www.xtoenergy.com Page 5/8 Report Printed: 8/28/2013 ! aiIy Activity and Cost Summary_sfs ;f11.1°F.HGI Well Name: Middle Ground Shoal C41-23LN API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 T08N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) 1Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 28.0 12/24/2012 12/25/2012 0000 Cont.P/U&JAM 2-3/8"tbg 0100 RIH w/clean-out assembly to 10,74]' 1100 Slip&cut drlg line 1230 P/U Pkr assembly&XN nipple 1330 RIH t/11,896' 1500 Mill @ 12,087'to 12,087',Up wt. 145,Dn wt 85,700 psi @ 1.5 bpm 2300 UD 6 jts DP&RIH t/12,151' Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 29.0 12/25/2012 12/26/2012 0000 Circ.&RIH t/14,050' 0900 Unplug mill,motor will not work 0930 POOH Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 30.0 12/26/2012 12/27/2012 0000 Cont.POOH&change out mill&motor 0330 RIH w/Clean-out assembly#2 U 3-1/2"liner 1800 Stage in hole,circ.as needed 2130 Wash&ream f/14,050'-t/14,214',Up wt.150k,Dn wt 70k, 1250 psi @ 71 gpm Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 31.0 12/27/2012 12/28/2012 0000 Cont wash&ream f/14,214'-t/14,373',Up wt. 150k,Dn wt 70k,950 psi @ 71 gpm 2300 Pump Hi-Vis sweeps&chase w/30 bbls of 2 micron filtered CaCl2 10.5ppg Remarks#2 • Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 32.0 12/28/2012 12/29/2012 0000 Spot 30 bbls of 2 micron Filtered CaCl2 10.5ppg f/11,000'-t/14,373' 0100 POOH 11,500',strap out 0630 Drop ball&open circ sub,circ out sweeps,minimal scale in returns 0900 Cont.POOH,SAM,lay down 2-3/8"tubing 2200 R/U to run perf guns,PJSM,pick up guns Remarks#2 Construction Summary#3 www.xtoenergy.com Page 6/8 Report Printed: 8/28/2013 • Daily Activity and Cost Summary_sis I NEli(GI Well Name: Middle Ground Shoal C41-23LN APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 TO8N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily- )peratiot Rpt No. Report Start Date Report End Date Operation Summary#1 33.0 12/29/2012 12/30/2012 0000 P/U perf gun assembly 0900 P/11 14 jts 2-3/8"tubing 1030 RIH with puns on 2-7/8"DP 1830 14410'no tight hole,P/U 145K-S/O 75K pull up place bottom shot, 14370'and top shot 12280' drop ball,rig up and pump 1.2bpm 400psi ball on seat 1915hrs with 44.5 bbls pumped,pressure up guns went off 3000psi 1930 Monitor well,change out drill pipe belly finger in derrick,fill trip tank,build pill,well static pump pill 2130 POOH with guns Remarks#2 Recieved verbal waiver from Mr.Chuck Scheve of AOGCC to run completion with out doing weekly BOP test that is due on 12-30-12(1500hrs 12-29-12) "New Perforations" Guns-RDX,2.5",2 shots per foot,60 degree phasing(2180 holes) 12280'-12430' 12550'-12640' 12730'-12860' 12900'-13220' 13260'-13370' 13570'-13640' 14150'-14370' Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 34.0 12/30/2012 12/31/2012 0000 POOH with pert gun assy,lay down 2-3/8"space out tubing,lay down and inspect guns,all shots fired 1800 pull wear ring 1830 clean rig floor,rig up to run completion.PJSM,(2 hours working on tongs.) 2130 Pick up packer assy,RIH picking up 2-7/8"1%Cr L80 6.5#EUE 8rd tbg,straping and drifting. Remarks#2 Recieve 13000 gal.diesel fuel from boat(67534 gal on board) Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 35.0 12/31/2012 1/1/2013 0000 RIH with completoin string_pickinq up 2-7/8"tubing,SLM and Drift 1330 Tag top of 5"liner @ 9277',attempt to work into TOL,unsuscessful 1800 Rig up to POOH racking back tubing. 2300 POOH Remarks#2 receive 14000 gal diesel fuel. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 36.0 1/1/2013 1/2/2013 0000 POOH with completion string,lay down&inspect WLEG,lay down packer. 0800 Rig up to test BOPE set test plug. 1000 Test BOP's 250/5000 psi,Hydril 250/2500 psi,accumulator function test,test gas alarms 1700 Rig down test assembly,clean floor 1800 Pick up packer assembly,RIH 1830 Work on#5 cat starter,warm up ACDC 1930 RIH with packer assy. 2000 Work on power tongs. 2130 RIH with packer assy.7265'@2400 hrs Remarks#2 On 12-29-12 had spoken with Mr.Chuck Scheve of AOGCC to skip weekly BOP test due to running completion.We agreed to test BOP's if we had problems and had to come out of hole.Notified state by E-mail of up coming test today at 1600 hrs Monday 12-31-12 Construction Summary#3 www.xtoenergy.com Page 7/8 Report Printed: 8/28/2013 • Y •aily Activity and Cost Summary_Is : LRU Well Name: Middle Ground Shoal C41-23LN API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201630100 TO8N-R13W-S23 Middle Ground Shoal 204-236 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date ;Total Depth(ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 t5�ii1;f Operations Rpt No. Report Start Date Report End Date Operation Summary#1 37.0 1/2/2013 1/3/2013 0000/RIH with packer F/7265'to 9278'tag top 5"liner. 0130/Work into top of liner(had to turn pipe to line up mule shoed end to enter,and had to bounce it past at every large OD on pkr assy,and first 3 collars of tubing.5"liner has good sized lip bent over, catching on tubing collars when picking up more pipe) 0600/Pick up hanger,(drift would not fit through pup bucked up into hanger,rig up and remove pup, nose rolled in of pup. 0900/Land hanger,pick up 3'rig up to circulate.(P/U 85K S/O 58K) 0930/Circ packer fluid,2 bpm,450 psi 1400/PJSM,acid pickle-1st pickle 12 bbls acid 16.5 bbls FIW(1.5 bpm-500 psi)pressure climb,rate drop,rev.out acid.2ed pickle, 10.5 bbls acid,52 bbls 10.5 ppg brine,reverse out.(1.5 bpm-500 psi) 1800/Land tubing hanger run in lock pins,drop bar,wait 30 min. 1900/Set Packer-Pressure tubing to 1000osi hold 15 min(monitor 25 psi drop)pressure tubing 4000psi hold 15 min(monitor 50 psi drop)attempt pressure on annulus full comunations,pressure up on tubing with test pump 5000psi,(small indication 4700-4800psi of setting)pressure up annulus 2150 psi hold 30 min no bleed off. 2200/Pull landing joint,set BPVblow down mud lines,rig down flow back iron to PTS tank Remarks#2 11636'WLEG 11630'XN nipple 2.205 ID 11607'TIW 5"HB-BP permanent packer 11597'X nipple 2.313 ID 341'X nipple 2.313 ID Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 38.0 1/3/2013 1/4/2013 0000 Clean and clear off rig floor and celler of unneeded equipment,Injecting fluid from PTS tank and trash fluid from pits,and storage tanks,cleaning in celler drains plugged,work to unplug drains,remove drilling nipple,choke and kill lines,4 bolt BOP's cleaning and organizing decks and equipment prep for back load. 1200 Continue working on celler drains,and cleaning celler deck,wellhead room.install BOP lifting cradle lift stack and move to side,pull and lay down riser,continue prep for back load.mop up well head room. 2130 Lower tree,nipple up and test hanger void 5000psi,good test,test tree componets 5000psi good test. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 39.0 1/4/2013 1/5/2013 0000-1200 Clean up tools from wellhead room,rig up slick line,run#1 retrieve packer setting bar,run #2 pull RHC plug,rig down slick line.back load boat,rig down flow lines from rig to pits,and high pressure mud line. Remarks#2 Release rig from C41-23LN at 1200 hrs. Construction Summary#3 www.xtoenergy.com Page 818 Report Printed: 8/28/2013 • Jflro 1-22-13 ACB ENERGY CURRENT Completion MGS C41-23LN WIW " KB:35' Cook Inlet,Alaska Water Depth:73'MSL Leg 4,Conductor 28 API No.:50-733-20163-01 ' Sidetrack:1-20-05 Original Spud: 12-17-68 el '070 Tbg:2-7/8"6.5#L80+1%Cr 8rd EUE Surf Csg: 10 3/4",40.5#J55 BTC. Set:01/04/2013 Set @ 1,653'. Cmt'd w/1,350 sx. 4'Pup Jt 2-7/8"6.5#1%Cr 8rd EUE @ 337' 2-7/8"X Nipple(2.313"ID)8rd 9 Cr @ 341' 4'Pup Jt 2-7/8"6.5#1%Cr 8rd EUE @ 342' 7 369 jts 2-7/8"6.5#1%Cr 8rd EUE 0.,/ 2-7/8"X Nipple(2.313"ID)8rd 9 Cr @ 11,604' 6'Pup Jt 2-7/8"6.5#1%Cr 8rd EUE @ 11,605' Intermediate Csg:7"29#L80 BTC. ' Anchor w/Seals 8rd(13 Cr)@ 11,611' Set @ 9,622'.Cmt'd w/335 sk STG 1 & 5"TIW HB-BP Perm Pkr(13 Cr)@ 11,617 392skSTG2.DVTooI @2,515'. 10'MOE(13Cr)@11,613' t// X-Over MOE to 2-7/8"8rd(13 Cr)@ 11,623' 1 6'Pup Jt 2-7/8"6.5#1%Cr 8rd EUE @ 11,624' #9∎Zt ��4, 2-7/8"XN Nipple(2.205"ID)8rd 9 Cr @11,630' *oljgo ' WL REG @ 1 ,635 2-7/8"6.5#1%Cr 8rd EUE @ 11,631' Drilling Liner:5"18#L80/P110 STL. r Set @ 12,0319' TOL @ 9,259'. PI TIW"LX"Liner Top Pkr. /, Cmt'd w/220 sk. �/ N a reeer 4,r ��/ Perforate Slotted Liner(12/29/2012)(2.5"TCP RDX 4 guns,2 SPF,60 deg phasing,2,180 shots total): 12,280'-12,430' 12,550'-12,640' 12,730'-12,860' 12,900'-13,220' 13,260'-13,370' 13,570'-13,640' 14,150'-14,370' Production Liner:3-'/i'8.8#L80 STL Slotted. Set @ 14,410'.TOL @ 11,848'. Blank Sections: 11,848 12,258' Liner Across:HR,HN,HK,HI,HE&HC. 12,442-12,540' 12,664-12,730' 13,192-13,225' 13,378-13,544' 13,672-14,097' 14,377-14,410' TD: 14,410'MD(9,178'TVD) J _" • ana 1L "atgF STATE OF ALASKA . ALARA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS (ie 1. Operations Abandon U Repair Well U Plug Perforations U Perforate 0 Other U Performed: Alter Casing ❑ Pull Tubing is Stimulate - Frac El Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Stimulate - Other ❑ Re -enter Suspended Well Li 2. Operator XTO Energy 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory 0 204-236 3. Address: 9127 S Jamaica Street Stratigraphic 0 Service 1151 6. API Number: Englewood, CO 80112 50- 733 -20163 r' CO --On 3j 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0018756 . Middle Ground Shoal C41 -23LN 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A MGS E, F & G Oil Pools 11. Present Well Condition Summary: Total Depth measured 14,410 feet Plugs measured NA feet true vertical 9,177 feet Junk measured NA feet Effective Depth measured 14,377 feet Packer measured 11,617 feet true vertical 9,177 feet true vertical 8,612 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,653' 10 -3/4" 1,653' 1,584' 3,130 psi 1,580 psi Intermediate 9,622' 7" 9,622' 7,249' 8,180 psi 7,020 psi Production 2,780' 5" 12,039' 8,751' 10,140 psi 10,490 psi Liner 2,562' 3 -1/2" 14,410' 9,178' Slotted Slotted Perforation depth Measured depth 12,258 - 14,377 feet SCANNED MAR 2 7 2013 True Vertical depth 8,765 - 9,177 feet Tubing (size, grade, measured and true vertical depth) 2 -7/8 ", 6.5 #, L80 1% Cr, EUE, 8rd w /EOT @ 11,635' MD & 8,623' TVD Packers and SSSV (type, measured and true vertical depth) TIW HB -BP Permanent Packer @ 11,617' MD & 8,612' TVD; no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 100 3,500 psi 3,500 psi Subsequent to operation: 0 0 100 0 psi 3,500 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory 0 Development 0 Service El Stratigraphic ri Daily Report of Well Operations yes 16. Well Status after work: r Oil El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP ❑ SPLUG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 3lZ —Z c Contact Sandra Haggard ,I�� Email Sandra HaggardCa�xtoenergy .com Printed Name- �""'� 6 '44 Title Regulatory Analyst Signature, - (-.7'../ver, Phone _377_3,r7Z. Date •34. Form 10-404 Re MAR 2 21013 w , - Z-.(S �_/ z Submit Original Only ;(1.0 . ACC March 21, 2013 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Submission of Report 10 -404 for Well Operations for MGS C41 -23LN Dear Mr. Norman, XTO Energy, Inc. hereby submits the Report of Sundry Well Operations Form 10 -404 for the MGS C41 -23LN Please find enclosed the following information for your records: 1. Form 10 -404 Report of the Sundry Well Operations 2. Daily Operations Report 3. Current Wellbore Schematic 4. Copy of MIT Test Chart If you require additional information, please contact me at (303) 397 -3672 Sincerely, Sandra M. Haggard Regulatory Analyst, Western Division CC: Alec Bridge, Operations Engineer @ (303) 397 -3608 Scott Griffith Scott Landon XTO Energy Inc. • P.O. Box 6501 • Englewood, CO 80155 • 9127 S. Jamaica St. • Englewood, CO 80112 • (303) 397 -3600 • Fax: (303) 397 -3899 An ExxonMobil Subsidiary • S ;(TO 1 -22 -13 ACB ENERGY CURRENT Completion MGS C41 -23LN WIW ', ,��� KB: 35' Cook Inlet, Alaska Ord ■ ■ r Water Depth: 73' MSL Leg 4, Conductor 28 $0.00:10,. API No.: 50- 733 - 20163 -01 Sidetrack: 1 -20 -05 Original Spud: 12 -17 -68 / ; � / / Tbg: 2 -7/8" 6.5# L80 +1% Cr 8rd EUE Surf Csg: 10 3/4 ", 40.5# J55 BTC. /! Set: 01/04/2013 Set @ 1,653'. Cmt'd w/ 1,350 sx. 4' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 337' 2 -7/8" X Nipple (2.313" ID) 8rd 9 Cr @ 341' 4' Pup Jt 2-7/8" 6.5# 1% Cr 8rd EUE @ 342' 369 jts 2 -7/8" 6.5# 1% Cr 8rd EUE 2 -7/8" X Nipple (2.313" ID) 8rd 9 Cr @ 11,604' 6' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 11,605' Anchor w/ Seals 8rd (13 Cr) @ 11,611' Of Intermediate Csg: 7" 29# L80 BTC. // 5" TIW HB-BP Pkr ( Cr) Set @ 9,622'. Cmt'd w/ 335 sk STG 1 & BP P Pk1 C ( @ 11,617' 392 sk STG 2. DV Tool @ 2,515'. 10' MOE (13 Cr) @ 11,613' X -Over MOE to 2 -7/8" 8rd (13 Cr) @ 11,623' / 6' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 11,624' �R 2 -7/8" XN Nipple (2.205" ID) 8rd 9 Cr @11,630' '0 4' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 11,631' WL REG @ 11,635' Drilling Liner: @ ' r li liner top L80/P110 STL. 11 jt Set @ 12,039'. TOL @ 9,259'. TIW "LX" Liner Top Pkr. Cmt'd w/ 220 sk. ■ ■ • C 2 A t Perforate Slotted Liner (12/29/2012) (2.5" TCP RDX - 15 /! guns, 2 SPF, 60 deg phasing, 2,180 shots total): 12,280' - 12,430' 12,550' - 12,640' 12,730' - 12,860' 12,900' - 13,220' l ,� 13,260' - 13,370' 13,570' - 13,640' / 14,150' - 14,370' . Production Liner: 3-%" 8.8# L80 STL Slotted. Set @ 14,410'. TOL @ 11,848'. Blank Sections: 11,848 12,258' Liner Across: HR, HN, HK, HI, HE & HC. 12,442 - 12,540' 12,664 - 12,730' 13,192 - 13,225' 13,378 - 13,544' 13,672 - 14,097' 14,377 - 14,410' TD: 14,410' MD (9,178' TVD) ) (TO gray Activity and Cost Summairyps ENERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:OOAM 14,410.0 Jobs Job Category Primary Job Type / Initial Job Type Secondary Job Type / Final Job Type Start Date End Date Well Maintenance Slickline 12/9/2012 00:00 12/9/2012 00:00 Objective PRE - WORKOVER / Pull GLV Dummy Valve for Drilling to kill well Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 1.0 12/9/2012 12/9/2012 - Rig up wireline and pressure test lubricator. - Run in hole with N -KOT & ML pulling tool. Made several attempts to locate #12 GLM 11,591' / #11 GLM 11,123 / #10 GLM 10,686' but could not sit down in any of them. Cannot pull any of the dummy valves above these depths for kill fluid purposes so pulled out of hole to check tools. Tools looked okay. - Run in hole with 2" Daniels KOT full drift & ML pulling tool. Hit scale bridge at 1198' and then solid scale at 1293'. Pull out of hole. - Readjusted springs on N -KOT. - Re -ran N -KOT & ML pulling tool to # 10 GLM. Worked tools %2 hour and then was finally able to sit down and latch # 10 Dummy valve. Jarred 45 minutes using spangs and hydraulic jars. Valve freed. Pull out of hole. - Rig down wireline. Turn well over to drilling. Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 1/1 Report Printed: 2/28/2013 ) fro /paily Activity and Cost Summary s ENERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Jobs Job Category Primary Job Type / Initial Job Type Secondary Job Type / Final Job Type Start Date End Date COMPLETIONS Recompletion 11/27/2012 00:00 11/28/2012 00:00 Objective Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 1.0 11/27/2012 11/28/2012 0000 -2400 Set out welding shop koomey house and welding shop equipment, center rig over leg 2 Rig up jacks and move rig south over leg 1 Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 2.0 11/28/2012 11/29/2012 0000 -2400 skid rig to leg #1. Remove 10" flow line from pump room and walk way between shop,clean and re- install. cut out washed out 4" high pressure mud line valve on #1 pump, trouble shoot crown beacon light, rig up rig lighting move jacks to pull rig East. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 3.0 11/29/2012 11/30/2012 0000 -0600 Set in welding shop equipment, set koomey house, set south side shop 0600 -2400 Wind 30 mph, wait on moving North side shop no magor crane work. weld in new 4" valve on #1 mud pump high pressure line, cleaning on platform, plumb in jet lines to 10" flow line, connect steam and air lines between South side welding shop and pits, work on lighting in derrick, trouble shoot electrical on rotary table, screw down tin on pits and South side welding shop.(walls) work on high pressure mud line pressure sensors, and mud pump rod oiler systems. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Weekly safety meeting with drilling crews Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 4.0 11/30/2012 12/1/2012 0000 -1200 High winds preventing crane operations for welding shop, finish installing 4" valve on mud line, clean 6" choke flow lines, With 2900 crane transfer equipment - iron racks, mud matieral, filter skid and filters, backets etc to pipe rack and to leg 2 clearing south side platform for rig skid. 1200 -1800 Wind starting to diminish Continue transferring equipment to pipe rack, set North side welding shop, make up service lines, install hand rails on pipe rack, set walk way to west crane, and stairs from pipe rack to main deck welders fab and work on pit suction lines for new isolation valve. 1800 -2400 Wind pick back up 30 mph -crane work minimal, make up firewater line at welding shop, hang tin on welding shop(walls) Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 5.0 12/1/2012 12/2/2012 0000 -0400 High winds continue crane work minimal. Prep for skidding, transfer equipment to pipe rack from south side decks. service rig jack unit. 0400 -1200 Start skidding rig East towards leg #4 Install BOP trolly beam extension. hang choke house, installing handrails, remove work over hatch on leg #2 install production hatch, weld step to crane walk around, replace valve in pump room breaseway, work on steam piping in subase, installing isolation valves on steam heaters. 1200 -1800 Transfer change house and parts house from leg #4 to leg #2 clear deck on leg #4 repair pit room exaust fan guard, replace suction valve #5 pit, fab stand for N2 back up for man riders, trouble shoot wiring for rotary table, replacing steam lines in subase. transfering equipment from Leg #4 to pipe rack and leg #1 &# 2 1800 -2400 Continue transfering equipment off leg #4 set Install work over hatches on Leg #4 Rig up air to rig for using tuggers, hang blocks to trouble shoot leak on weight indicator, lay out electrical cables accross deck, and re -route around to north side of rig.Set in poorboy gas buster in choke house. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Construction Summary # 3 www.xtoenergy.com Page 1/8 Report Printed: 2/28/2013 f E NERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:OOAM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 6.0 12/2/2012 12/3/2012 0000 -1200 Continue stringing electrical cables to North side of rig. Rig up to skid top section rig South, set drilling line spool on main deck, attempt to skid top rig sub South, trouble shoot and repair jack, break pony sub loose, work on steam lines in subase, work on suction lines in mud pits, set West crane boom stand and weld down on leg #2 re- terminate wiring for rotary table, change out contact blocks and switches on iron roughneck. working on replacing hand rails, and cleaning decks. 1200 -2400 Jack upper subase South, set choke manifold in choke house,hook up vent lines, close choke house roof, hang steam heater in choke house, hook up electrical rig floor, work on suction lines in pit #3 remove 2900 crane boom stand off leg #4 rearange and clean up decks, weld up hand rails on south side stairs going to production level, Attempt to jack rig East, work on rig jacking unit. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 7.0 12/3/2012 12/4/2012 0000 -0630 Work on rig jacking unit. organize equipment on decks 0630 -1000 Skid rig East towards leg #4 (pulling rig) install new suction line pit #3, 1000 -1230 Move jacks to push Change out bad bladders on Koomey unit bottles. 1230 -2400 Skid rig to leg #4 (problems with jacks and grippers) replace leaking steam line in pump room hallway Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 8.0 12/4/2012 12/5/2012 0000 -1800 Skidding rig attempting to center over well, (problems with jacks, grippers and power unit - had to move upper jack to lower skid) string electrical lines and plug in rig. Rig is skidded as far East as necessary 1800 -2400 Move jack to upper section skid and center over C 41 -23LN make up storm clamps, work on replacing hand rails on south side deck. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit. Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 9.0 12/5/2012 12/6/2012 0000 -1200 Rig up steam and air lines to rig, tighten storm clamps, remove lower jacks from skid, and scope in upper jacks, rig down jack unit. Skid koomey house over, make up trolly beam in welding shop. Attempt to take on drill water, line on platform plugged, Back load boat. 1200 -2400 Work with welder on handrails South side platform, Remove hose for taking water from boat, put in shop to thaw. Fix steam heaters in subase and rig floor, run air control line for koomy remote on rig floor, pick up electric cables off pony sub deck, work on steam lines in pits, clean up welding shop. Set beaver slide. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit.(day 2) No drilling Electrician Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 10.0 12/6/2012 12/7/2012 0000 -1200 Install landing from doghouse artic entry to beaver slide, orginize decks, clear water and ice from boat transfer hose and PT hose, good test. cleaning in welding shop, pump room. welder working on hand rails beaver slide, pipe rack. Repair seals on spear hydramatic side drawworks, fix leak on dead man for hook load, Work on accumulator, 1200 -2400 Continue assisting welder with hand rails, on platform, install water hose on North side for taking on water. install knee braces under dog house, pressure up koomey check for leaks, continue cleaning and orginizing decks and rig Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit.(day 3) No drilling Electrician Construction Summary # 3 www.xtoenergy.com Page 2/8 Report Printed: 2/28/2013 • ) flay Activity and Cost Summary ENERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 11.0 12/7/2012 12/8/2012 0000 -1200 Stage equipment for back load, clear rig floor, palitize 3 -1/2 tools, work on steam heater in pits, screw down tin on south side pit wall,start rig engine check DC power, House keeping on platform. Welder work on hand rails and stairs. 1200 -2400 Assist production electrition work on rig electrical, (gas sensor, 480 for iron roughneck, and communication) hang 2" hose on stand pipe, ajust drawworks brakes band rollers, work on hand rails and plate on back deck work on choke manifold, unload boat, tak on 29000 gal water. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers Representative from Control Technology on site to repair accumulator air pumps and inspect unit.(day 4) release rep No drilling Electrician Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 12.0 12/8/2012 12/9/2012 0000 -1200 Work on choke manifold, (vent line on poorboy, flow lines outlets on choke) lay out koomey lines install 2" demco on circ stand pipe, set cat walk, organize decks. 1200 -2400 Removing and changing plate on pony sub, Work on koomey lines, cleaning in celler, put up rig floor drain hoses, hang 10" hall way work on choke flow lines. Service 3900 crane(West) orginize decks. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers No drilling Electrician 24hr shut in on well, built to 240psi, Slickliner rig up to pull lower dummy from GLM in A.M. on 12 -9 -12 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 13.0 12/9/2012 12/10/2012 0000 -1200 Work on hanging 6" flow line off poor boy, cleaning in pump room, celer, and rig floor.lnstall 4" flow line from choke to mud pits. Replace fresh water line valve in pits, organize decks, assist welders 1200 -2400 Hang 6" choke flow line, from rig to pits, Cleanining and orginize celler, decks, pump room, Assist electrician trouble shooting electrical problems with drawworks and rotary table, test mud pumps Good assist welders, prep for back load. Remarks # 2 Rig move costs divided 5 ways for next 5 workovers No drilling Electrician, Production electrician came from A trouble shoot electrical problems. Slickline pull dummy from GLM #10 10667' SLM (was unable to latch on to pull from GLM's #12 or #11) well has 500psi shut in. Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 14.0 12/10/2012 12/11/2012 0000 -1200 Dress elevators and slips for 2 -3/8" pipe. move rig jack,rig up lazy susan under cuttings auger, finish make up 4" high pressure mud line, put 50 bbls FIW in pill pit for testing lines, work on installing plate on back deck pony sub, Assist production electrician trouble shoot power problems for drawworks, and rotary table. work on 10" flow line, assiat production take on 14000 gal fuel. 1200 -2400 Back load boat. assist electricians repair drawworks and rotary table. finish 10" flow line, lay plate on back deck pony sub, build stairs for pony sub, cleaning and orginizing sub, and decks, assemble derrick board on rig floor. Remarks # 2 Rig move costs divided 5 ways for next 5 workover Production electrician came from A trouble shoot electrical problems. Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 15.0 12/11/2012 12/12/2012 0000 -1200 hang derrick board south side derrick, turn on water to rig, clean & orginize decks, R/U circ line to choke manifold, circ. & check for leaks, Trouble shoot blockage in choke manifold. 1200 Cont. trouble shoot & remove blockage in choke manifold, remove fluid in pit # 3 & start repairing leak in suction line Remarks # 2 Rig move costs divided 5 ways for next 5 workover Production electrician working with new drilling electrician. Construction Summary # 3 www.xtoenergy.com Page 3/8 Report Printed: 2/28 /2013 • ) fro gaily Activity and Cost Summary. ENERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 16.0 12/12/2012 12/13/2012 0000 Repairing leak in suction line in pit #3 0900 Transfer brine from storage tanks to pits 0930 PJSM, Kill well w/ 10.3 ppg CaCl2 @ 4 bpm, 1600 psi tbg pressure, holding 700 psi back pressure, 8.4 ppg returns, 9.5 ppg returns after 1500 strokes, pumped 430 bbls (80 bbls over calculated volume) 1700 Monitor well - OK 2000 R/D circulating lines 2100 Set BPV & N/D tree & set out same Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 17.0 12/13/2012 12/14/2012 0000 N/U BOPs, changed out double gates Remarks # 2 Replaced double gate rams with Cameron Type U because we needed the better variables Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 18.0 12/14/2012 12/15/2012 0000 Cont. N/U BOPs, Test gas detectors, 1400 Test BOPs, 250/2500 annular, 250/5000, all other equipment Remarks # 2 Construction Summary # 3 Rpt No Report Start Date Report End Date Operation Summary # 1 19.0 12/15/2012 12/16/2012 0000 Finish BOP test 0200 R/D test equipment & blow down lines 0400 M/U landing jt & pull hanger to rig floor, seals pulled free @ 90k, Up wt. 83k 0500 Circ. & wt. up t/ 10.5 ppg 0730 Monitor well - OK 0830 UD 2 -7/8" Tbg and jewelry, NORM =2 2230 Change elevators & tong jaws 2300 Brine flowing out Tbg., R/U and circ., 10.0 ppg brine returns, Remarks # 2 287 jts 2 -7/8" tbg Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 20.0 12/16/2012 12/17/2012 0000 Cont. Circ 2 -3/8" Tbg and weight up light brine, 5.7 bpm @ 910 psi, monitor well - OK 0100 POOH, UD 75 jts 2 -3/8" Tbg & seal assembly, NORM = 2 0430 Set wear ring 0500 Trouble shoot and repair iron roughneck clamp mode 0700 M/U milling assembly, strap, rabbit & p/u DP 2330 Trouble shoot & repair iron roughneck spinners Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 21.0 12/17/2012 12/18/2012 0000 Cont. repairing spinners on iron roughneck 0130 Cont. RIH w/ milling assembly, P/U DP, Tag Pkr © 11,633' 1130 P/U Kelly & break circulation 1200 Milling on Pkr f/ 11,633' - t/ 11,635', Up wt. 150k, Dn wt 75k, Rot wt 100k, Tq 2000 ft/Ibs, 1700 psi © 3 bpm 1800 DP twisted off, wait on Overshot Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 4/8 Report Printed: 2/28 /2013 t ro gaily Activity and Cost Summary's E NERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 22.0 12/18/2012 12/19/2012 0000 Cont. wait on fishing tools 1030 M/U Overshot, Latch fish @ 40' retrieved 1 jt. Run # 2 TOF © 71', retrieved 15jts DP Run # 3 TOF @ 499', no fish Run # 4 Latch fish @ 499', POOH, Break, inspect & make -up all connections Remarks # 2 UD 5 bad jts. DP Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 23.0 12/19/2012 12/20/2012 0000 Cont. POOH, break, inspect & make -up all connections 1900 Wait on mud motor & tools Remarks # 2 Check rotary torque values Repair kelly spinner Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 24.0 12/20/2012 12/21/2012 0000 Wait on mud motor & tools 1200 M/U BHA & RIH, break circ @ 4000', 9000' & 10,000' 2200 Milling Pkr @ 11,635', Up wt 150k, Dn wt 85k, Rot wt 105k, Tq 3600 ft/Ibs @ 20 rpm, 1100 psi @ 2.8 bpm Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 25.0 12/21/2012 12/22/2012 0000 Milling Pkr @ 11,636', Up wt 150k, Dn wt 85k, Rot wt 105k, Tq 3600 ft/Ibs @ 20 rpm, 1100 psi @ 2.8 bpm 0530 Push Pkr down hole t/ 11,823', 0600 Circ Hi -Vis sweep, Mill partially plugged, finish circ bottoms up 1030 POOH(wet) 2200 M/U Spear & RIH Remarks # 2 Production using AC /DC Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 26.0 12/22/2012 12/23/2012 0000 Cont. RIH w /spear 0830 Spear Pkr @ 11,823', Up wt 135k, Dn wt 75k, 1250 psi @ 1.1 bpm 1000 POOH, retrieved all 35' of fish 2200 Pull wear ring 2230 R/U & test BOPs Remarks # 2 Production using AC /DC Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 27.0 12/23/2012 12/24/2012 0000 Cont. Test BOPs 1100 Set wear ring 1200 Blow down choke & kill lines & manifold 1300 M/U mill & mud motor, R/U Weatherford to JAM tbg 1330 Weatherford trouble shooting equipment 1700 P/U 2 -3/8" flush joint tbg Remarks # 2 Production using AC /DC Construction Summary # 3 www.xtoenergy.com Page 5/8 Report Printed: 2/28/2013 ) fro Spay Activity and Cost Summary( ips ENERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 28.0 12/24/2012 12/25/2012 0000 Cont. P/U & JAM 2 -3/8" tbg 0100 RIH w/ clean -out assembly to 10,747' 1100 Slip & cut drlg line 1230 P/U Pkr assembly & XN nipple 1330 RIH t/ 11, 896' 1500 Mill @ 12,087' to 12,087', Up wt. 145, Dn wt 85, 700 psi @ 1.5 bpm 2300 UD 6 jts DP & RIH t/ 12,151' Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 29.0 12/25/2012 12/26/2012 0000 Circ. & RIH t/ 14,050' 0900 Unplug mill, motor will not work 0930 POOH Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 30.0 12/26/2012 12/27/2012 0000 Cont. POOH & change out mill & motor 0330 RIH w/ Clean -out assembly #2 t/ 3 -1/2" liner 1800 Stage in hole, circ. as needed 2130 Wash & ream f/ 14,050' - t/ 14,214', Up wt. 150k, Dn wt 70k, 1250 psi @ 71 gpm Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 31.0 12/27/2012 12/28/2012 0000 Cont wash & ream f/ 14,214' - t/ 14,373', Up wt. 150k, Dn wt 70k, 950 psi @ 71 gpm 2300 Pump Hi -Vis sweeps & chase w/ 30 bbls of 2 micron filtered CaCl2 10.5ppg Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 32.0 12/28/2012 12/29/2012 0000 Spot 30 bbls of 2 micron Filtered CaCl2 10.5ppg f/ 11,000' - t/ 14,373' 0100 POOH 11,500', strap out 0630 Drop ball & open circ sub, circ out sweeps, minimal scale in returns 0900 Cont. POOH, SLM, lay down 2 -3/8" tubing 2200 R/U to run perf guns, PJSM, pick up guns Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 6/8 Report Printed: 2/28/2013 Spay Activity and Cost Summa nips ) (To NERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:00 AM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 33.0 12/29/2012 12/30/2012 0000 P/U perf gun assembly 0900 P/U 14 jts 2 -3/8" tubing 1030 RIH with guns on 2 -7/8" DP 1830 14410' no tight hole, P/U 145K - S/O 75K pull up place bottom shot, 14370' and top shot 12280' drop ball, rig up and pump 1.2bpm 400psi ball on seat 1915hrs with 44.5 bbls pumped, pressure up guns went off 3000psi 1930 Monitor well, change out drill pipe belly finger in derrick, fill trip tank, build pill, well static pump pill 2130 POOH with guns Remarks # 2 Recieved verbal waiver from Mr. Chuck Scheve ofAOGCC to run completion with out doing weekly BOP test that is due on 12 -30 -12 (1500hrs 12- 29 -12) "New Perforations" Guns - RDX, 2.5 ",2 shots per foot, 60 degree phasing (2180 holes) 12280' - 12430' 12550'- 12640' 12730' - 12860' 12900' - 13220' 13260'- 13370' 13570'- 13640' 14150' - 14370' Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 34.0 12/30/2012 12/31/2012 0000 POOH with pelf gun assy, lay down 2 -3/8" space out tubing, lay down and inspect guns, all shots fired 1800 pull wear ring 1830 clean rig floor, rig up to run completion. PJSM, (2 hours working on tongs.) 2130 Pick up packer assy, RIH picking up 2 -7/8" 1% Cr L80 6.5# EUE 8rd tbg, straping and drifting. Remarks # 2 Recieve 13000 gal. diesel fuel from boat (67534 gal on board) Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 35.0 12/31/2012 1/1/2013 0000 RIH with completoin string picking up 2 -7/8" tubing, SLM and Drift 1330 Tag top of 5" liner @ 9277', attempt to work into TOL, unsuscessful 1800 Rig up to POOH racking back tubing. 2300 POOH Remarks # 2 receive 14000 gal diesel fuel. Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 36.0 1/1/2013 1/2/2013 0000 POOH with completion string, lay down & inspect WLEG, lay down packer. 0800 Rig up to test BOPE set test plug. 1000 Test BOP's 250/5000 psi, Hydril 250/2500 psi, accumulator function test, test gas alarms 1700 Rig down test assembly, clean floor 1800 Pick up packer assembly, RIH 1830 Work on #5 cat starter, warm up ACDC 1930 RIH with packer assy. 2000 Work on power tongs. 2130 RIH with packer assy. 7265' @2400 hrs Remarks # 2 On 12 -29 -12 had spoken with Mr. Chuck Scheve ofAOGCC to skip weekly BOP test due to running completion. We agreed to test BOP's if we had problems and had to come out of hole. Notified state by E -mail of up coming test today at 1600 hrs Monday 12 -31 -12 Construction Summary # 3 www.xtoenergy.com Page 7/8 Report Printed: 2/28/2013 ) fro fray Activity and Cost SummarOls ENERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:OOAM 14,410.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 37.0 1/2/2013 1/3/2013 0000 / RIH with packer F/ 7265 to 9278' tag top 5" liner. 0130 / Work into top of liner (had to turn pipe to line up mule shoed end to enter, and had to bounce it past at every large OD on pkr assy, and first 3 collars of tubing. 5" liner has good sized lip bent over, catching on tubing collars when picking up more pipe) 0600 / Pick up hanger, (drift would not fit through pup bucked up into hanger, rig up and remove pup, nose rolled in of pup. 0900 / Land hanger, pick up 3' rig up to circulate. (P /U 85K S/O 58K) 0930 / Circ packer fluid, 2 bpm, 450 psi 1400 / PJSM, acid pickle - 1st pickle 12 bbls acid 16.5 bbls FIW (1.5 bpm -500 psi) pressure climb, rate drop, rev. out acid. 2ed pickle, 10.5 bbls acid, 52 bbls 10.5 ppg brine, reverse out. (1.5 bpm -500 psi) 1800 / Land tubing hanger run in lock pins, drop bar, wait 30 min. /1900 / Set Packer - Pressure tubing to1000psi hold 15 min.(monitor 25. psi „r,,p),Dressure tubing i 4000psi hold 15 min (monitor 50 psi drop) attempt pressure on annulus full comunations, pressure up on tubing with test pump 5000psi, (small indication 4700- 4800psi of setting) pressure up annulus 2150 V psi hold 30 min no bleed off. 200 / Pufl i ding joint, s etBPVblow down mud lines, rig down flow back iron to PTS tank Remarks # 2 11636' WLEG 11630' XN nipple 2.205 ID 11607'TIW 5” HB -BP permanent packer 11597' X nipple 2.313 ID 341' X nipple 2.313 ID Construction Summary # 3 Rpt No Report Start Date Report End Date Operation Summary # 1 38.0 1/3/2013 1/4/2013 0000 Clean and clear off rig floor and celler of unneeded equipment, Injecting fluid from PTS tank and trash fluid from pits, and storage tanks, cleaning in celler drains plugged, work to unplug drains, remove drilling nipple, choke and kill lines, 4 bolt BOP's cleaning and organizing decks and equipment prep for back load. 1200 Continue working on teller drains,and cleaning celler deck, wellhead room. install BOP lifting cradle lift stack and move to side, pull and lay down riser, continue prep for back load. mop up well head room. 2130 Lower tree, nipple up and test hanger void 5000psi , good test, test tree componets 5000psi good test. Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 39.0 1/4/2013 1/5/2013 0000 -1200 Clean up tools from wellhead room, rig up slick line, run #1 retrieve packer setting bar, run #2 pull RHC plug, rig down slick line. back load boat, rig down flow lines from rig to pits, and high pressure mud line. Remarks # 2 Release rig from C41 -23LN at 1200 hrs. Construction Summary # 3 www.xtoenergy.com Page 8/8 Report Printed: 2/28 /2013 ) fro gaily Activity and Cost Summar3 s ENERGY Well Name: Middle Ground Shoal C41 -23LN API /UWI Location Field Name Permit Number State Well Configuration Type 50733201630100 TO8N- R13W -S23 Middle Ground Shoal 204 -236 Alaska Directional Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 1/27/2005 5:45:00 PM 4/14/2005 6:00:OOAM 14,410.0 Jobs Job Category Primary Job Type / Initial Job Type Secondary Job Type / Final Job Type Start Date End Date Well Maintenance Slickline 1/4/2013 00:00 1/4/2013 00:00 Objective POST COMPLETION - Pull RHCP Plug & Prong Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 1.0 1/4/2013 1/6/2013 - NOTE: RHCP plug body was run in place with completion. Prong was dropped to set packer. - Rig up wireline and pressure test lubricator. - Run in hole with 2" JDC pulling tool. Well had small amount of pressure & fluid to surface. Latched & pulled RHCP drop bar at 11,614' WLM. Pull out of hole. Well on strong vacuum. - Run in hole with 2 -1/2" GS pulling tool to 11,618' WLM. Latch & pull RHCP plug body. Pull out of hole. - Rig down wireline. Turn well over to production. Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 1/1 Report Printed: 2/28/2013 X S\ - . N.i. . ' /'� .+ L ! „ A ._ ;..._.._ ` f / Q!� f dttt,i_ S f Ip f r j *f, A > � / / . # , i ...,2,- 2000 4 A - , ► r " 5*..: / / : ti / f ti ,{ (� I z / `� CI 1 Cy' ,,,, , r *, 1 4 / '7''''''')C.-' --, etTIV ' i r-ithid , 1..• • i i� ,� i { 000 i i ` ■ A t • ` 'iryY • __ „ _ , 004000 • A \ 2i-0---4‘-----‘--gtoit 4 'Pt 8 • ••, 1 N \ \ ..„.. :),..;-----4,\ , ,....\- ' ‘k., \ fir a dbdh- r - . . - 7 Oddg .. . .....".'' . / ' ` _ 07 09 -- i ----' �` 4 N .,�� ...,'''''''' ',.., ',........y • • �, ,,Trrri n, SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Maria Perez Regulatory Analyst XTO Energy, Inc. O 200 N. Loraine, Suite 800 Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, 86 G Oil Pool, MGS #C41 -23LN Sundry Number: 312 -260 Dear Ms. Perez: tvt,ANNED AUG 0 X 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. Sincerely, 4 Daniel T. Seamount, Jr. Commissioner DATED this Z day of August, 2012. Encl. "` • RECEIVED JUL 162012 E NERGY a subsidiary of ExxonMobil AOGCC July 12, 2012 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 Re: Form 10 -403, request for sundry approval Objective: Pull Tubing, Repair Well, Perforate, and Stimulate. Middle Ground Shoal #C41 -23LN Water Injection Well Middle Ground Shoal Field, E, F, & G Oil Pool Cook Inlet, Alaska API 50-733-20163-01-00 XTO Energy Inc. hereby submits its Application for Sundry Approval to pull the tubing, repair well, perforate, and stimulate. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval. 2. Cover Page 3. Summary Page. 4. Injection Plot. 5. Rate & Pressure Monitoring Plots for Injection Waiver. 6. Deviation Survey. 7. Job Procedure. 8. Current Wellbore Diagram. 9. Proposed Wellbore Diagram. 10. Wellhead Schematic. 11. BOP 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 A/C 432- 620 -6743 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 • . RECEIVED - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 1 6 2012 APPLICATION FOR SUNDRY APPROVALS �OGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El • Pull Tubing 111 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El • Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy Inc. Development ❑ Exploratory ❑ 204 -236 • 3. Address: Stratigraphic ❑ Service 0 6. API Number: 200 N. Loraine, Suite 800, Midland, Texas 79701 50 -733- 20163 -01 -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 El Middle Ground Shoal #C41 -23LN ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 0018756 • 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): 14410' • 9177' • 14377' 9177' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1653 10 -3/4" 1653' 1584' 3130 psi 1580 psi Intermediate 9622 7" 9622' 7249' 8160 psi 7020 psi Production 2780 5" 12039' 8751' 10140 psi 10490 psi Liner 2562 3 -1/2" 14410' 9178' Slotted Slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12258' - 14377' 8765-9177' 2 -7/8" & 2 -3/8" L -80 11681' Packers and SSSV Type: Baker 5" DB Perm Pkr, No SSV Packers and SSSV MD (ft) and TVD (ft): 11646' 12. Attachments: Description Summary of Proposal 13 13. Well Class after proposed work: Detailed Operations Program II BOP Sketch 6 Exploratory ❑ Development ❑ Service 31 14. Estimated Date for 10/1/2012 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 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 Paul Figel, Engr 432 - 620 -6743 Printed Name Maria Perez Title Regulatory Analyst Signature Phone 432 -620 -4325 Date 7/12/2012 . #441- � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t Z -2A. . Plug Integrity ❑ // BOP Test El Mechanical Integrity Test Location Clearance Other Bo P tecj f /-0 5 d U p 5 - 4. Q pe -- ti cli I el r c Co v,:, -14c C'c 1,../) :it-, h ..:CO 9 SG /rim cc 34 F? e r2 V1) / V CI per ,O 4C 2-5'. Z-6 CO !A r7" - .fig re -1urr1 Subsequent Form Required: la 4-0 APPROVED BY / ^ Approved by"� COMMISSIONER THE COMMISSION Date: 8 t l DMS AUG 3 1 2011 C 'V Sub it in / j / pycate 403 Revised 1/2010 L1/� J r 1 G ! N A �. �' ���' ' ca �1 \ p),,,,,,, / TO ER GY June 29, 2012 To: John Norman Victoria Ferguson Cc: Scott Griffith Scott Landon From: Paul Figel Subject: Workover for MGS C41 -23LN (204 -236): Repair Tubing Pressure Communication Objective: The workover proposed for the C41 -23LN, located on Platform C, Cook Inlet, is to repair the pressure communication on the tubing by casing annulus. The AOGCC granted an Injection Waiver in 2010 to allow continued injection under certain criteria. The current tubing in place is the original gas lift string which had the gas lift valves replaced with dummies in 2005 when the well was converted to injection. Due to the history of a low injection volume, the well will he perforated across the ±,300' of slotted litter prior to running the new completion in hopes to overcome any near wellbore skin damage. Well History: The well was sidetracked into the West Flank in Jan 2005 for a reverse penetration from the Hemlock HR to the HC. Although the well was completed as a producer, the long term objective was to be an injector for West Flank pressure support. The well IP'd @ 165 BO with nil water but was down to 92 BO within 3 weeks. A LWD porosity log was not run but the resistivity log had good shows. There were not any issues drilling this section of the well and oil base mud was utilized as a standard practice. A 3 -1/2" slotted liner was set across the 2300' open hole section. The well as converted to injection 4 months later in 2005. The initial injection rate was 700 BWIPD @ 3500 psi but quickly dropped and stabilized at 90 BWIPD for the next 4 years. The well was shut -in from April 2010 to Jan 2011 pending the Injection Waiver Approval from the AOGCC. The current injection rate is 91 BWIPD @ 3500 psi. MISC: XTO Energy has been granted a waiver since 1999 concerning the BOP stack since the rig sub structure can only fit a double ram configuration (as seen in the attached BOP Schematic) versus the 3 ram stack. XTO was grandfathered a variance due to the depleted reservoir pressure and the extensive knowledge of the Middle Ground Shoal over the past 45 years. Therefore, XTO is requesting the same variance for this project. The anticipated date for operations start up is October 2012. Please contact me at 432 - 620 -6743 with any questions or concerns. Sincerely, g cjj Paul Figel Engineering Manager • • WORKOVER SUMMARY for C41 -23LN Scope of work: The main objective is to repair the pressure communication on the tubing by casing annulus. The AOGCC granted an Injection Waiver in 2010 to allow continued injection under certain criteria. The current tubing in place is the original gas lift string which had the gas lift valves replaced with dummies in 2005 when the well was converted to injection. Due to the history of a low injection volume, the well will be perforated across the ±2300' of slotted liner prior to running the new completion in hopes to overcome any near wellbore skin damage. A new packer and injection string will be installed. Current Well Status: Injecting 91 BWIPD @ 3500 psi. Well Info: See Attached Procedure & TVD Survey. SSV Report NA as Injector. MASP & Kill Weight: BHP = 3900 psi: (8.4 ppg FIW x 8933' Midperf TVD x 0.052) = 3902 psi. (Assumes fluid @ Surf) Kill weight: 3900 psi = (0.052) (8750' Top Perf TVD) (x, ppg) x = 8.6 ppg + 0.5 ppg = 9.1 ppg mud Mud Recipe will be 8.4 ppg FIW + 35 lbs/bbl CaC12 Based upon surveys on offset producers, the West Flank BHP is 3000 -3500 psi. As seen in the attached Injection Rate & Pressure Monitoring Plot for 2010, the well was dead from July — Dec with FIW in the injection tbg. MIT Info: The well has had an Injection Waiver 9.009 since Dec 2010. As seen in the Press & Monitoring file, the well has good integrity on the 7" Intermediate & 10 -3/4" Surface Casing. BOP Ram Configuration: VPR for 2 -3/8" to 5 ". Schematic Attached. Workover Rig: XTO derrick is a permanent rig on Platform C. Requested Waiver: XTO Energy has been granted a waiver since 1999 concerning the BOP stack since the rig sub structure can only fit a double ram configuration (as seen in the attached BOP Schematic) versus the 3 ram stack. XTO was grandfathered a variance due to the depleted reservoir pressure and the extensive knowledge of the Middle Ground Shoal over the past 45 years. /14P5P <' 3 oo ? pS Contact Info: • 02 _rim stoic a ccer i per AAc ZS , 2 gsz,y2) • Operations Engineer: Paul Figel, XTO Energy, 432 - 620 -6743, Paul figel @xtoenergy.com • Superintendent: Scott Griffith, XTO Energy, 907 - 776 -2506, scott @xtoenergy.com • /TO ERGY MASP for C41 -23LN Current Well Status: Injecting 91 BWIPD @ 3500 psi and has been on injection since 2005. The formation is very tight and as seen in the attached plots for injection, downtime and surface pressure_ the well will bleed to 0 psi given several days. Since the well will be perforated in hopes to overcome any near wellbore skin damage, the MASP will be based upon a 50% water r-ut 8.4 ppg FIW = 0.437 psi/ft 34 API = .0.3702 nsiift. Mid Perf TVD: 8955' Ton Perf TVD: 8765' BHP = (0.437 psi /ft)(8955') = 3913 psi P�v — -'. t :765'1+ (0.510A37 nsi/ft)(8_765'1= 3538 nsi MASP = 3913 — 3538 = 375 usi) Paul Figel Engineering Manager • PSI C41 -23 INJ HEMLOCK HraGs 3600 36 3.400 L V " ' ` I t. � r' �L�. 34 FF 7 3,200 32 3.000. Hj .30 i 2,800 ( }I .28 2,600, 11 7 ti 1 26 �� I 2,400 E . y �,24 I IYI (I j+ 2 200. I� ! I „22 P 2,000, . .20 1,800_ �j 8 • 1,600, . ( I* I.. .16 1,400, 14 1,200, .12 1.000, . ,10 800. _! . . .8 600. . \ . • 6 • 400. • "}} t,. • • • .4 • 200. . . I • \1 1 .2 8/9/09 10/1 12/1 2/1 4/1 6/1 8/1 10/1 12/1 2/1 4/1 6/1 8/1 10/1 12/1 2/1 4/1 6/1 8/8/12 --Casing Pressure -•– Tubing Pressure — Annulus Pressure -- SurfaceCasingPressure -- InterCasrngPressure . Down Hours • SoapStick { MCF C41 -23 INJ HEMLOCK BBL .400 .375 350 .325 ,300 .275 .250 ,225 200 175 t 150 J 1� .125 r r JAM/. r J ^ 100 \viill .1 'i l j•, �, 'T/ M .75 ll ') M ill, � . N rn .50 . 1 r 1 25 / 1 • 0 8/9/09 10/1 12/1 2/1 4/1 '6/1 8/1 10/1 12/1 2/1 4/1 6/1 8/1 10/1 12/1 2/1 4/1 6/1 8/8/12 — Gas —Oil — Water — Water IN —Gas Injection CO2 Prod —0O2 Injection — Gas Target — Oil Target ..... LinePressure i .rx.r....■ w assAsassowerm■y - v !,. Convert to Inj Aug 2005 100 i li 50 ' r iLwovs.or.......vert,p,riviirol - _ -- NGS (V4 0311- 23LN(N) 1 m CH SI due to TCA Press j 0D 'Afr Granted Waiver in Dec '10 10 \ii ........... m Cis - I- -T CD ail .MNI= CD hjRess --_ _ _ - -_ - Test ECM Alaska 1 -__ 0 Test BAFD Alaska 4 Test NUM Alaska XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5,000 500 Injection [psig] 4,500 450 • Injected [bbl] w 4,000 - Hrs Down 400 E to E.' L a 3 � cif ---r 350 p O �' 06 f.; m c 3,000 300 ce I z • - 2,500 X X 250 • 2,000 • 200 • • 1,500 4 • 150 1,000 ♦ N ♦ 100 • 500 ♦ 50 • $ r. > 0 0 P .O �O t .O ^ O ^ O ^ O ^O r.O t.O N % ^ O N % ^ N , , , ry 0 , O , , O , O �O �O ry 0 ry0 XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 TBG Annulus [psig] 1000 WH Injection [psig] _ 4500 ---+ Injection Rate (bbl /d) 900 Surface Casing Pressure - m L • _ — T Intermed [psi 800 2 0 cc C a z c 3500 700 ,g o N r N V y d 5 3000 600 a m I Y m 2500 500 E U) N d 7 Y r T _ c c • Q 2000 400 t _a • _ j 1500 300 1000 • 200 ilk 500 i 100 0 - 0 , d o ,yo 0 o � , 1 4 15' I' <yo do do ‘15 ,yo do d d 41. 0 XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval Al0 No. 9.009 5,000 TBG Annulus [psig] 1000 WH Injection [psig] 4,500 --.-- Injection Rate (bbl /d) 900 --a—Surface Casing Pressure d —e-7" Intermed [psig] 3 4,000 800 • co N i a - 4- a. 3,500 X X X X X )I( X X X X X X X X X X X X X X X X( xC xC xC X X X xC X 700 cc riT�TT ♦ ♦ ♦ ♦ ♦ • ♦ ♦ ♦ ♦ ♦ �T� 0 _ Z q+ Des . 0 3,000 600 E.D. I a. 2,500 500 2 05 _ = a to m 2,000 - 400 c Si c c - — 1,500 300 m .0 ca • 1,000 200 Cl) 500 100 0 c • - • - 0 ,,, < 1 O^% <I' 0 < O O 0 0 < O O O 0 0 O O,,, P. 0 0 < h h h h h h h I .. • • Field: Middle Ground Shoal Date: 21- Apr -2005 Well: C41 -23LN IIIIIIIIIIIIIIIIF _11111111.6 R North 2481939 North 2484009 East 230647 East 230488 2326' FNL, 2484' FEL 259' FNL, 2588' FWL Sec. 14, T8N, R13W Sec. 14, T8N, R13W MD DEVIATION AZIMUTH TVD NORTH EAST DOGLEG MRKB GR.N. MRKB j f f deg /100ft 0 0.00 0 0 2474190.16 231422.87 0 38 0.00 0 38 2474190.16 231422.87 0 100 0.50 2 100 2474190.43 231422.89 0.81 200 0.50 205 200 2474190.47 231422.72 0.98 300 0.50 14 300 2474190.5 231422.64 1 400 0.50 149 399.99 2474190.54 231422.97 0.92 500 4.25 62 499.9 2474191.83 231426.5 4.25 600 5.75 71 599.52 2474195.02 231434.58 1.69 700 8.00 62 698.8 2474199.67 231445.57 2.49 800 8.75 39 797.76 2474208.6 231456.71 3.41 900 11.50 28 896.2 2474223.09 231466.51 3.35 1000 14.00 29 993.73 2474242.23 231477.5 2.51 1100 18.00 31 1089.83 2474265.74 231491.86 4.04 1200 22.75 33 1183.55 2474294.79 231511.03 4.8 1300 27.25 34 1274.16 2474329.47 231535.17 4.52 1400 29.50 34 1362.14 2474368.25 231562.63 2.25 1500 29.00 34 1449.39 2474408.12 231590.87 0.5 1600 28.50 35 1537.06 2474447.13 231619 0.69 1653 28.1 35 1583.73 2474467.36 231633.92 0 1756 28.45 32 1674.44 2474507.42 231661.76 1.42 1785 29.51 29.98 1699.81 2474519.29 231669.26 4.97 1820 29.25 26.3 1730.31 2474534.24 231677.7 5.21 1881 29.03 28.85 1783.59 2474560.24 231692.04 2.07 1979 28.84 28.85 1869.36 2474601.24 231715.87 0.19 2074 29.92 24.05 1952.15 2474642.46 231737.53 2.73 2170 31.2 20.98 2034.82 2474687.11 231757.22 2.1 2267 32.7 14.44 2117.15 2474735.59 231773.86 3.89 2364 33.01 13.12 2198.63 2474786.39 231787.56 0.8 2458 33.53 10.31 2277.23 2474836.62 231799.17 1.73 2554 34.38 7.75 2356.86 2474889.36 231808.78 1.73 2648 35.72 3.75 2433.82 2474942.91 231815.38 2.83 2745 36.91 359.03 2512 2475000.26 231818.06 3.13 2837 38.29 356.27 2584.89 2475056.37 231817.02 2.37 2933 39.57 354.6 2659.57 2475116.58 231813.58 1.72 3027 40.87 351.06 2731.36 2475176.94 231807.36 2.8 3122 43 349.66 2802.03 2475239.75 231798.15 2.45 3216 46.37 346.21 2868.86 2475304.65 231785.76 4.42 3310 46.09 344.61 2933.89 2475370.7 231770.17 1.26 3409 45.96 345.43 3002.63 2475439.93 231753.34 0.61 3505 45.82 345.57 3069.45 2475507.04 231737.61 0.18 3598 46.02 346.34 3134.14 2475572.2 231722.89 0.63 3691 45.52 346.8 3199.01 2475637.35 231708.89 0.64 3787 46.65 346.82 3265.6 2475705.02 231694.66 1.18 3882 48.59 347.27 3329.63 2475773.75 231680.5 2.07 3907 48.58 347.44 3346.17 2475792.13 231676.82 0.51 4004 48.05 347.62 3410.68 2475863.2 231662.8 0.56 1 0 • MD DEVIATION AZIMUTH TVD NORTH EAST DOGLEG MRKB _ GR.N. MRKB f f deg /100ft 4100 47.71 346.87 3475.06 2475932.99 231648.67 0.68 4194 47.57 346.66 3538.4 2476000.95 231634.32 0.22 4286 47.15 347.33 3600.72 2476067.22 231620.6 0.7 4381 46.62 346.41 3665.65 2476135.1 231606.4 0.9 4473 46.48 347.59 3728.92 2476200.5 231592.87 0.94 4568 46:19 347.27 3794.51 2476267.9 231579.45 0.39 4663 46.05 347.67 3860.36 2476335.06 231566.13 0.34 4755 45.76 347.4 3924.38 2476399.88 231553.35 0.38 4850 47.56 346,86 3989.58 2476467.57 231539.5 1.94 4947 47.48 347.41 4055.09 2476537.66 231525.17 0.43 5045 47.25 346.05 4121.46 2476608.19 231510.23 1.05 5138 46.35 346.03 4185.13 2476674.33 231495.39 0.97 5235 47.64 347.1 4251.29 2476743.68 231480.5 1.56 5329 48.52 346.39 4314.09 2476812.11 231466.02 1.09 5422 48.54 346.46 4375.67 2476880.2 231451.22 0.06 5515 48.29 347.29 4437.4 2476948.29 231436.97 0.72 5610 48.14 347.21 4500.7 2477017.71 231422.92 0.17 5706 48.01 346.06 4564.85 2477087.56 231408.01 0.9 5801 47.46 345.89 4628.74 2477156.14 231392.54 0.59 5898 46.61 345.56 4694.85 2477225.31 231376.61 0.91 5991 46.3 346.49 4758.92 2477291.08 231361.83 0.8 6084 45.7 345.23 4823.53 2477356.3 231346.98 1.17 6180 45.4 345.93 4890.75 2477423.04 231331.44 0.61 6275 45.16 345.43 4957.6 2477488.81 231316.25 0.45 6366 44.66 344.9 5022.05 2477551.28 231301.22 0.69 6459 44.9 346.64 5088.06 2477615.12 231286.58 1.34 6556 45.06 347.57 5156.68 2477682.29 231272.81 0.7 6650 46.44 348.85 5222.27 2477748.49 231260.58 1.76 6742 46.73 349.04 5285.5 2477814.35 231249.27 0.35 6841 46.94 348.62 5353.23 2477885.49 231236.9 0.38 6937 47.36 348.05 5418.51 2477954.73 231224.25 0.62 7030 47.61 348.89 5481.36 2478022.19 231212.09 0.72 7130 46.18 347.97 5549.69 2478094.03 231199.1 1.58 7224 46.1 347.91 5614.83 2478160.61 231186.46 0.1 7313 45.98 348.68 5676.61 2478223.62 231174.9 0.64 7407 46.22 348.76 5741.79 2478290.33 231163.17 0.26 7502 46.12 347.36 5807.58 2478357.68 231150.53 1.07 7596 46 347:12 5872.81 2478424.02 231137.1 0.22 7687 46.11 347.17 5935.96 2478488.22 231123.98 0.13 7784 45.99 346.93 6003.28 2478556.61 231109.9 0.22 7877 46.28 347.57 6067.72 2478622.33 231096.6 0.59 7993 46.55 347.89 6147.7 2478704.82 231080.63 0.31 8089 46.97 347.65 6213.46 2478773.49 231067.38 0.47 8185 47.4 348.49 6278.71 2478842.7 231054.4 0.78 8279 47.58 348.04 6342.23 2478910.85 231041.87 0.4 8372 47.23 347.48 6405.17 2478978.07 231028.89 0.58 8466 47.42 347.05 6468.89 2479045.81 231015.2 0.39 8562 47.42 347.03 6533.84 2479115.04 231000.92 0.02 8658 47.5 347.28 6598.75 2479184.34 230986.78 0.21 8753 47 346.48 6663.23 2479252.62 230972.51 0.81 8849 47.31 347.01 6728.52 2479321.48 230957.94 0.52 8946 47.28 346.85 6794.3 2479391.27 230943.41 0.13 9041 47.36 347.43 6858.7 2479459.69 230929.43 0.46 9131 47.68 346.6 6919.48 2479524.69 230916 0.77 9234 47.76 346.5 6988.78 2479599.19 230899.98 0.11 9328 47.8 346.74 7051.94 2479667.26 230885.42 0.19 9425 48.27 348.86 7116.81 2479738.08 230871.8 1.7 2 r • • 1 MD DEVIATION AZIMUTH ND NORTH EAST DOGLEG MRKB GR.N. MRKB f f deg /100ft 9519 47.66 347.28 7179.75 2479806.7 230858.94 1.41 9706 47.47 347.13 7305.93 2479941.95 230831.46 0.12 9786 46.78 347.8 7360.36 2479999.45 230820.05 1.06 9872 45.46 348.16 7419.97 2480060.36 230808.53 1.56 9931 44.67 348.16 7461.65 2480101.42 230800.9 1.34 9995 44.58 354.13 7507.22 2480145.94 230795 6.55 10098 45.55 356.59 7579.97 2480218.72 230790.78 1.94 10195 46.17 358.35 7647.52 2480288.31 230789.3 1.45 10284 46.6 358.35 7708.92 2480352.74 230788.92 0.48 10379 46.78 358 7774.08 2480421.87 230788.3 0.33 10473 46.69 358.35 7838.51 2480490.31 230787.69 0.29 10567 46.69 358 7902.99 2480558.71 230787.07 0.27 10661 46.25 356.94 7967.73 2480626.84 230785.62 0.94 10757 45.99 358 8034.27 2480696.02 230784.15 0.84 10851 45.02 358.35 8100.15 2480763.06 230783.55 1.07 10948 44.76 358.7 8168.87 2480831.52 230783.35 0.37 11049 46.51 357.59 8239.49 2480903.71 230782.65 1.9 11142 48.54 357.39 8302.29 2480972.29 230781.22 2.19 11236 49.38 356.74 8364.01 2481043.16 230779.2 1.03 11328 48.31 358.64 8424.55 2481112.41 230777.99 1.94 11423 49.26 358.05 8487.15 2481183.87 230777.56 1.1 11520 49.43 0.61 8550.35 2481257.44 230778.38 2.01 11596 49.93 359.5 8599.53 2481315.36 230779.76 1.29 11677 57.97 353.69 8647.18 2481380.7 230777.2 11.49 11774 67.38 349.62 8691.67 2481466.09 230766.53 10.39 11864 74.42 347.1 8721.11 2481549.69 230751.26 8.26 11960 81.23 343.87 8741.35 2481640.97 230729.8 7.82 12027 84.33 344.26 8749.77 2481705.28 230713.03 4.66 12114 87.4 341.8 8756.04 2481788.81 230689.61 4.52 12196 86.64 342.36 8760.3 2481867.28 230666.2 1.15 12292 85.43 345.18 8766.94 2481959.81 230641.54 3.19 12386 83.21 349.13 8776.25 2482051.43 230622.84 4.8 12484 82.53 346.11 8788.42 2482146.85 230604.17 3.14 12582 85.1 344.66 8798.98 2482241.65 230581.75 3.01 12675 81.5 348.48 8809.83 2482331.92 230562.36 5.62 12770 79.9 347.06 8825.18 2482423.97 230544.6 2.24 12863 75.62 352.88 8844.91 2482513.73 230530.8 7.65 12956 75.69 349.62 8867.96 2482603.06 230519.13 3.4 13051 74.69 347.66 8892.24 2482693.49 230503.11 2.26 I 13122 75.69 350.76 8910.39 2482761.18 230491.81 4.45 13219 77.4 352.3 8932.96 2482854.78 230480.06 2.34 13313 76.8 354.94 8953.95 2482946.03 230471.96 2.81 13407 78.3 353.65 8974.22 2483037.55 230464.93 2.08 13506 74.09 350.8 8997.84 2483133.04 230454.13 5.09 13600 73.83 350.36 9023.81 2483222.48 230441.39 0.53 13696 74.04 351.03 9050.38 2483313.83 230428.56 0.71 13794 77.78 2.73 9074.31 2483408.63 230425.64 12.19 13887 77.53 12.33 9094.24 2483498.29 230439.58 10.09 13981 79.44 12.61 9113 2483587.74 230461.52 2.05 14080 78.94 4.16 9131.6 2483683.5 230477.89 8.4 14175 77.5 358.62 9151.01 2483776.35 230482.28 5.91 14271 81.85 359.38 9168.21 2483870.77 230482.8 4.6 14358 87.07 1.02 9176.61 2483957.3 230485.09 6.29 14410 90.19 2 9177.85 2484009.21 230487.65 6.29 3 r • • 1 ' XT0 ERGY XTO ENERGY INC. MGS C41 -23LN WEST FLANK, COOK INLET, ALASKA Repair Press Comm., Perf Liner & Run New Injection Tbg Procedure WELL DATA: SURFACE CASING: 10 -3/4" 40.5# J55 BTC. Set @ 1,653'. Cmt w/ 1,350 sk. INTERMEDIATE CSG: 7" 29# L80 BTC. Set @ 9,622'. DV Tool @ 2,515'. Cmt w/ 335 sk STG 1 & 392 sk STG 2. DRILLING LINER: 5" 18# L80/P110 STL. Set @ 12,039'. TOL @ 9,259'. Cmt w/ 220 sk. PRODUCTION LINER: 3 -1/2" 8.8# L80 Hydril 513 Slotted. Set @ 14,410'. TOL @ 11,848'. TUBING: 2 -7/8" 6.5# L80 8rd EUE: Surface to 9,175'. 285 Jt 2 -3/8" 4.7# L80 8rd EUE: 9,175' — 11,681'. 75 Jts PACKER: 5" Baker DB Permanent Packer 9 Chrome @ 11,646'. OPEN HOLE: 6" from 12,039 — 14,410' MD. BHP: ±3,900 psi BHST: 170 Deg F CURRENT INJECTION: 91 BWIPD @ 3500 psi OBJECTIVE: Pull GLV String w/ Dummy GLV's, perforate Slotted Liner & Run new Injection String. NOTES: • AFE # : 1200396 • Barney to make SL 1.75" gauge ring run to GLM #12 prior to MIRU derrick. • If well is not dead w/ 8.4 ppg FIW — add 35 lbs/bbl CaC12 for 8.9 ppg • Need PTS tank for Pickle Acid Job. Materials Required: • 60 bbl Gel Pill (2 #/bbl FloZan + 3 gal Greencide) (Provided by MI) • 60 gal WC1447WR Corrosion Inhibitor (Nalco) • 900 gal 12% Acetic Acid (Univar) ➢ 2 gal EC1447 Corrosion Inhibitor for Acetic (Nalco) • 1000 gal 10% Pickle Acid (BJ) • 1000 lbs Soda Ash (MI) 6 -29 -12 Y:\ PLF \alaska\Procedures \C41- 23LN\C41 -23LN Procedure to Perf & Run New Inj Tbg 6- 29- 12.docx • • 2 PROCEDURE: 1. SD injection. Bleed -off well to header. 2. RU Slickline & lubricator. RIH w/ pulling tool to GLM #12 @ 11,591'. Latch & POOH the dummy valve. RD lubricator. 3. MIRU Derrick. Circ well with 360 bbl standard FIW at 4 BPM to the prod header through GLM @ #12. Check to make sure well is dead. 4. MI 12,000' 2 -7/8" 10.4# SLH90 HT drill pipe (1.975" ID) & 9 ea 3 -1/8" DC (1.5" ID). 5. Notify the AOGCC 48 hrs prior to the BOP test. Set BPV's and ND the WH. Install riser & NU BOP's. Pull BPV's & set double check valves. Ensure BOP has VPR pipe rams for 2 -7/8" & 2- 3/8" tbg. Press test BOP's to 250 psi & 5000 psi. Send in WH to Cameron. New WH to have SS .yalx.�.. 6. RU slips & tongs for 2 -7/8" & 2 -3/8" tbg. Pull & release Baker seal assembly from pkr @ 1 1,646'. POOH & LD 285 jts 2 -7/8" & 75 jts 2 -3/8" tbg while checking for NORM. Send tbg to onshore to be sold for scrap. Send in tbg hanger to Cameron. New hanger to be SS. 7. MU 5" Packer milling BHA on 3 -1/8" DC's & 2 -7/8" DP. RIH to top of pkr @ 11,646'. Establish string weight. Mill packer per packer milling procedures. After the ph drops, circ bottoms up w/ 20 bbl gel sweep followed w/ FIW. POOH with the packer & 35' tailpipe. If packer does not come out, RIH with spear & grapple to retrieve the packer. Push pkr to 3 -1/2" TOL @ 11,848'. POOH slowly w/ pkr & 35' tail pipe. LD spear. 8. MI 2700' 2 -3/8" 4.7# L80 Hydril Flush Jt tbg. 9. RIH w/ 2.75" mill (3 -1/2" 9.3# drift is 2.867 ") on 2700' 2 -3/8" tbg x -over to 2 -7/8" DP. RIH to TD @ 14,410'. Circ 20 bbl gel pill followed with 320 bbl FIW @ 3 BPM. (Weatherford to JAM the 2 -3/8" Hydril tbg.) 10. Spot 21 bbl 12% acetic acid from 14,410 - 12,000'. (Will flush in Step #21.) POOH. LD all 2 -3/8" tbg except for 18 jts ( ±558'). 11. MI Expro TCP Services. Hold a pre job safety before picking up the perforating guns. Designate the essential personnel allowed on the rig floor while making up the guns. The well must be dead before deploying or retrieving the gun string. 12. Open the BOP's & MU the ±2090' of 2.5" 2511 Razor RDX TCP guns with slips & safety dog collar. Guns to be loaded @ 2 jspf @ 60 degree phasing. 6 -29 -12 Y:\PLF\alaska \Procedures \C41- 23LN\C41 -23LN Procedure to Perf & Run New Inj Tbg 6- 29- 12.docx • • 3 Top Bottom Length Net, Ft Shots @ 2 Perfs 12280 12430 150 150 300 Blank 12430 12550 120 Perfs 12550 12640 90 90 180 Blank 12640 12730 90 Perfs 12730 12860 130 130 260 Blank 12860 12900 40 Perfs 12900 13220 320 320 640 Blank 13220 13260 40 Perfs 13260 13370 110 110 220 Blank 13370 13570 200 Perfs 13570 13640 70 70 140 Blank 13640 14150 510 Perfs 14150 14370 220 220 440 TOTAL 2090 1090 2180 13. Have solid landing bar available to deploy in gun string to set across the pipe rams if well starts to kick while MU TCP guns. Close pipe rams & kill well through kill line. )-0 bvi 1)P c,,(F t/ 14. MU hydraulic actuated firing head to gun string. Filler sub to be installed above firing head. RIH w/ guns on 18 jts (558') 2 -3/8" tbg & 2 -7/8" DP back to surface. Rely on tbg tally to put guns on / depth. 15. Drop ball down the tubing. RU mud pump & circ ball down. Press up on guns to ±3,000 psi to fire guns. Watch well for 15 min to note any press build up. Kill well if necessary before POH w/ guns. 16. POOH w/ DP & tbg. LD the 2 -7/8" DP & 2 -3/8" tbg. Conduct a safety mtg when guns are 300' below rig floor. LD guns & check for misfires. 17. MI 12,000' (inc14% excess) 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE tbg. 18. RIH w/ TIW 5" HB -BP Chrome Permanent Packer on 2 -7/8" 6.5# 1% Cr 8rd EUE tbg and land as follows: Install new 2 -7/8" SS tbg hanger. a w/ 0 Item Length, ft Top Bottom X 2 -7/8" 6.5# 1% Cr 8rd EUE tbg 330 0 330 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 330 334 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr 1 334 335 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 335 339 2 -7/8" 6.5# 1% Cr 8rd EUE tbg 11,246 339 11,585 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr 1 11,585 11,586 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 11,586 11,592 Anchor w/ Seals 8rd EUE (13Cr) 1 11,592 11,593 5" TIW HB -BP Permanent Packer (13 Cr) 4 11,593 11,597 10' Millout Extension (13 Cr) 10 11,597 11,607 X -Over MOE to 2 -7/8" 8rd (13 Cr) 1 11,607 11,608 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 11,608 11,614 2 -7/8" XN Nipple (2.205 ID) 8rd 9Cr 1 11,614 11,615 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 11,615 11,619 WL REG 1 11,619 11,620 6 -29 -12 Y:\PLF\alaska \Procedures \C41- 23LN\C41 -23LN Procedure to Perf & Run New Inj Tbg 6- 29- 12.docx NJ� 4 re 19. Notify AOGC • __ .. . . 20. RU BJ w/ 1,000 gal 10% Pickle Acid & the 250 bbl flowback tank. Press test all lines to 2,000 psi. / Est circ down the tbg w/ FIW. Pickle the injection tbg with 500 gal 10% Pickle acid @ 2 -3 BPM. Underdisplace the acid with FIW by 500' from the end of the tbg. Reverse circ the acid into the v flowback tank with the rig pumps. (Have 1,000 lbs of soda ash in the tank to neutralize the acid �� before pumping acid.) Repeat a 2 pickle sweep with the remaining 500 gal of acid. Reverse out �,tiA acid with the rig pumps until returns are clean. Pump spent acid into disposal well C44 -14RD & record all volumes injected. 21. S P?pe r? Use acicdpump to flush acetic acid from Step #10 w/ 40 bbl FIW @ 2 -3 BPM w/ y Pmax = 4000 psi. RD BJ. 22. Rig to pump 300 bbl pkr fluid (300 bbl FIW + 60 gal WC1447WR Corrosion Inhibitor). Displace w/ ±67 bbl FIW. 23. RU Slickline & press test lubricator to 4,000 psi. RIH w/ "N" test tool plug and seat on XN nipple @ 11,614. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Con't to press up to ±3,500 psi to set packer. Hold a 4,000 psi press test on the tbg for 15 min. Bleed off the tbg press. 24. Perform the MIT on the 2 -7/8" tbg annulus with an AOCCewitii,ss. With the 5" Packer set @ 11,597', press test the annulus to 2,150 psi (8,600' TVD x 0.25 = 2,150 psi) and hold for 30 minutes. 25. POOH w/ test tool. RD Slickline. 26. Set BPV. ND BOP's & riser. NU new SS WH & pull BPV. Set 2 way check & test WH to 5,000 psi. Pull out 2 way check. Release Rig. PWOI. Paul Figel Engineering Manager 6 -29 -12 Y:\PLF\alaska \Procedures \C41- 23LN\C41 -23LN Procedure to Perf & Run New Inj Tbg 6- 29- 12.docx • 0 ;(TO PLF 9 -7 -05 ENERGY Current Completion MGS C41 -23LN WIW 1 4 KB: 35' Cook Inlet, Alaska II I� Water Depth: 73' MSL Leg 4, Conductor 28 TBG: API No.: 50-733-20163-01 2 -7/8" 6.5# L80 8rd EUE to 9,175' Sidetrack: 1 -20 -05 J 2 -3/8" 4.7# L80 8rd EUE 9,176' to 11,681' Original Spud: 12 -17 -68 7 J Set: 4 -14 -05 / r Surf Csg: 10 3/4 ", 40.5# J55 BTC. GLM MD TVD Set @ 1,653'. Cmt'd w/ 1,350 sx. J #1 1975 1894 Dummy Valve #2 3566 3112 Dummy Valve #3 4874 4006 Dummy Valve r #4 6027 4783 Dummy Valve #5 7211 5606 Dummy Valve J r #6 8143 6251 Dummy Valve Intermediate Csg: 7" 29# L80 BTC. #7 8947 6794 Dummy Valve Set @ 9,622'. Cmt'd w/ 335 sk STG 1 & „ / #8 9617 7246 Dummy Valve 392 sk STG 2. DV Tool @ 2,515'., #9 10195 7648 Dummy Valve #10 10686 7985 Dummy Valve "< \ / „, #11 11123 8289 Dummy Valve ►�� J �_ #12 11591 8597 Dummy Valve �y� J Hanger: 2 -7/8” RTS6 Box X 3 - %" 8rd Pin @ Surf X -Over 3 -W 8rd Box X 2 -7/8" 8rd Pin @ 2' 6' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 313' 47 WO Drilling Liner: 5" 18# L80/P110 STL. --' flO 2 -7/8" X Nipple (2.313" ID) 9Cr @ 320' 1 jt P110 @ liner top. %' 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 321' Set @ 12,039'. TOL @ 9,259'. 2-7/8" 6.5# L80 8rd EUE @ 321 - 9,175' y TIW "LX" Liner Top Pkr. X -over 2 -718' 8rd Box X 2 -3/8 8rd Pin @ 9,175' y � %: Cmt'd w/ 220 sk. ' ' 2 -3/8" 4.7# L80 8rd EUE @ 9,176' - 11,634' i 1 2 -3/8" X Nipple (1.875" ID) 8rd 9Cr @ 11,634' !;'; �'� 10' Pup Jt 2 -3/8" 4.7# 8rd EUE 9Cr @ 11,636' y it 12.5 Baker Loc (40 -26) w/ Seals @ 11,646' 5" Baker DB Perm Pkr (32 -26) 9Cr @ 11,646'* 10' Baker SBE 13Cr @ 11,649' ►Z ►(': X -over SBE to 2 -3/8" 8rd Pin 9Cr @ 11,658' 10' Pup Jt 2 -3/8" 4.7# 8rd EUE 9Cr @ 11,659' /' 9y 2 -3/8" XN Nipple (1.791" ID) 9Cr @ 11,669' 10' Pup Jt 2 -3/8" 4.7# 8rd EUE 9Cr @ 11,670' WLREG @ 11,681' *Pkr was set on DP. Tbg was 12.4' deeper than DP measure w/ all depths corrected to tbg meas. Production Liner: 3 -%" 8.8# L80 STL Slotted. v Set @ 14,410'. TOL @ 11,848'. Blank Sections: 11,848 - 12,258' 12,442 12,540' Liner Across: HR, HN, HK, HI, HE & HC. 12,664 - 12,730' 13,192 - 13,225' 13,378 - 13,544' 13,672 - 14,097' 14,377 - 14,410' Fish: GLV dropped 8 -29 -05 TD: 14,410' MD (9,178' TVD) A 6 41104 6. • 0 TO 4 -5 -12 PLF ENERGY Proposed Completion MGS C41 -23LN WIW KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 4, Conductor 28' API No.: 50- 733 - 20163 -01 :7, Tbg: 2 -7/8" 6.5# L80 +1% Cr 8rd EUE @ Sidetrack: 1-20-05 11,620' Set: Original Spud: 12 -17 -68 o 4' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 330' Surf Csg: 10 3/4 ", 40.5# J55 BTC. 2 -718 X Nipple (2.313" ID) 8rd 9 Cr @ 334' Set @ 1,653'. Cmt'd w/ 1,350 sx. 4' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 335' ±363 jts 2 -7/8" 6.5# 1% Cr 8rd EUE 2 -7/8" X Nipple (2.313" ID) 8rd 9 Cr @ 11,585' 6' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 11,586' Anchor w/ Seals 8rd (13 Cr) @ 11,592' 5" TIW HB -PB Perm Pkr (13 Cr) @ 11,593' /, 10' MOE (13 Cr) @ 11,597' ! ;/ X -Over MOE to 2 -7/8" 8rd (13 Cr) @ 11,607' Intermediate Csg: 7" 29# L80 BTC. ? - //1 o Set @ 9,622'. Cmt'd w/ 335 sk STG 1 & n 6' Pup Jt 2 -7/8" 6.5# 1 /o Cr 8rd EUE @ 11,608' %rte^ 2 -7/8" XN Nipple (2.205" ID) 8rd 9 Cr @11,614' 392 sk STG 2. DV Tool @ 2,515'. �, 4' Pup Jt 2 -7/8" 6.5# 1% Cr 8rd EUE @ 11,615' WL REG @ 11,619' ►� Wit,% / � a> ;1/ 04 Drilling Liner: 5" 18# L80/P110 STL., id 1 jt P110 @ liner top. Set @ 12,039'. TOL @ 9,259'. TIW "LX" Liner Top Pkr. Cmt'd w/ 220 sk. ■ ■ f f � %► Z� vi ■ ■ i /;■ 20 -r 5 Production Liner: 3 -Y2' 8.8# L80 STL Slotted. Set @ 14,410'. TOL @ 11,848'. Blank Sections: 11,848 - 12,258' L,, 12,442 - 12,540' Liner Across: HR, HN, HK, HI, HE & HC. 12,664 - 12,730' 13,192 - 13,225' 13,378 - 13,544' 13,672 - 14,097' 14,377 - 14,410' TD: 14,410' MD (9,178' TVD) J ,, • • e ik CAMERON XTO PLATFORM C Well 41 -23L Equipment Tree 2 -9/16 API 5K Run with 2 -1/16 API 5K Wing Valves in run of tree use R -27 Ring Gaskets Valve on wing use R -24 Ring Gaskets Tubing Hanger has 2 -1/2" Type H BPV Profile i. S MTNTM mu cm 6 4-, 1,0 A)1" 00 , 0-400" 0 -i I. MI _. _._ J R -27 d , N ; ^ c ; I � c Fit :.4 Pneumatic R -27 i J SSV o gm in 00 o....i(o 04 _) 00 • Tubing Head Adapter -2 n m 7- 1/16" API 5K 2 -9/16 API 5K R-46 Ring Gasket Bottom le �� 11' R -27 Ring Gasket Top R-46 : 6 saiu IiF INN ' Of Tubing Spool 11 API 5K x 7- 1/16" API 5K - _ ; �� e _ R -54 Ring Gasket Bottom 0 0 011111111 R-46 Ring Gasket Top ��o� �o� ������ �o ������ -� =.4 Annulus Outlets are 2 -1/16 API 5K - x °�° a e - ( 1 8' 2' R -24 Ring Gasket ° � u ID" 2 ®/16 API 5K ' �.. i ` R -24 Ring f8a¢kpt NIP R -54 ;j; III.: 5' 6" Lowermost Casing Head II.. II um 11" 3K ( #9 Clamp) x 11 API 5K Top R -53 MODIFIED Ring Gasket Bottom = = R -54 Ring Gasket Top III - �o o ®:Ui II , Annulus Outlets are 2 -1/16 API 5K o - II1 -r =E 3' 6" R -24 Ring Gasket - v. � o 2' 4" 011=1 1 1 O 2 -1/16 API 5K ) O R -24 Ring Gasket **R-53 MODIFIED • • . 5/23/2012 13.625 BOP Schematic.xls 1 XTO - ENERGY KB Elevation Date: 5/23/2012 "Rig Floor" Flow Flow line Nipple II Hydril / 13 5/8" 5m 13 5 /8" 5m Annular double ram preventer 1TE mm lrn m o • 2. tt_� v 6K = 13 5/8" 5m Cameron �_ I 1......1 Pipe rams �- I i • i i IE f 13 8" Cameron �y 5/ Blind 5m Rams �o I. :- L-0 II III 11 11 III . 41 :1122111 11 4.4 • I 1I II . ill II 2 1/16" Kill Line IN 3 1/8 "Choke Line 111 11 11 l I l 11 21/16" 31/8 31/8 5 5m 5m Hydraulic Manual Manual Valve Valves valve 13 5/8 5m riser 135/8 "5m LTIFEITLIITffillrj Mud Cross with 3 1/8" outlets Page 1 o 7 Regg, James B (DOA) Pm 7 From: Paul Figel@xtoenegy.com Sent: Monday, August 06x2012 6:31 AM l 7I 1 z To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring July 2012 AIO # 9 -009 Attachments: C41 -23LN Rate and Pressure Monitoring July 2012 (AIO 9.009).xlsx Attached is the July 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C41 -23LN as required by Administrative Approval AIO No. 9.009. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX SCANNED MAY 0 7 ZU 3 Office: 432 - 620 -6743 I��r11�� Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 • • XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Apprntial Ain tin a flog 5,000 TBG Annulus [psig] 1000 WH Injection [psig] _ t Injection Rate (bbl /d) 900 4,500 - — Surface Casing Pressure d — 7 Intermed [psig] 4,000 800 d � a 3,500 X X X X X X X X X X X X X X X X X )K )K )K )K )K )K X )IC )K 700 C 4 0 - r 06 v 3,000 600 y • = a` 2,500 500 a> o6S - d 2,000 400 E c � Q 1,500 300 06 .0 ~ 1,000 200 500 100 0 C .3 0 • \ , L O \ 'V \ 'V , \ , y p \ c1, \ 'V gy p 1, \ . , \ t5 \1� ,- , , A \ t� A \ n� A \ �j A \ 1 A \ 0� \N \N \ '` �j \' 1 \'` off ' \ `y "� \ `yh \`l ,\ \`L 3 1 1 1 '1 '1 1 1 1 1 1 1 • . C41 -23LN (2042360) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 7/1/2012 91 8 0 3,350 3,500 0 7/2/2012 88 7 0 3,350 3,500 0 7/3/2012 89 7 0 3,350 3,500 0 7/4/2012 89 7 0 3,350 3,500 0 7/5/2012 90 5 0 3,350 3,500 0 7/6/2012 88 5 0 3,350 3,500 0 7/7/2012 61 5 0 3,350 3,500 8 7/8/2012 21 5 0 3,350 3,500 22 w/f down 7/9/2012 112 5 0 3,350 3,500 0 7/10/2012 96 5 0 3,350 3,500 4 w/f down 7/11/2012 100 5 0 3,350 3,500 0 7/12/2012 93 5 0 3,350 3,500 0 7/13/2012 94 5 0 3,350 3,500 0 7/14/2012 91 5 0 3,350 3,500 0 7/15/2012 90 5 0 3,350 3,500 0 7/16/2012 89 5 0 3,350 3,500 0 7/17/2012 92 5 0 3,350 3,500 0 7/18/2012 93 5 0 3,350 3,500 0 7/19/2012 90 5 0 3,350 3,500 0 7/20/2012 91 5 0 3,350 3,500 0 7/21/2012 87 5 0 3,350 3,500 0 7/22/2012 88 5 0 3,350 3,500 0 7/23/2012 92 5 0 3,350 3,500 0 7/24/2012 93 5 0 3,350 3,500 0 7/25/2012 94 5 0 3,350 3,500 0 7/26/2012 95 5 0 3,375 3,500 0 7/27/2012 91 5 0 3,375 3,500 0 7/28/2012 91 5 0 3,375 3,500 0 7/29/2012 91 5 0 3,375 3,500 0 7/30/2012 94 5 0 3,375 3,500 0 7/31/2012 93 5 0 3,375 3,500 0 h XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 —a— TBG Annulus [psig] 1000 5000 -4-- WH Injection [psig] - 4500 t Injection Rate (bbl /d) 900 AD—Surface Casing Pressure - m III c 4000 —e- 7 " Intermed [psig] 8 00 a; as N L Z - a c 3500 r 700 ois 0 co N U c 3000 600 I m I - 1 '8 ? N 2500 5 00 c Q 2000 400 8 a) • s - I- cn 1500 300 • - 1000 - f 200 • • 500 100 0 0 \ , ti o g �,yo e e �, \ , y o \ , y o �,yo e g \ , y o �, �,yo e e \ , y o � , y o \ , y o �, N '1 4 11 4 off A\ 4 4 ,,c , , r N't ^ � ^ ti n j T :4 4 `O� ^ \� 4 II • • Regg, James B (DOA) 7 -04 zo From: Paul_Figel @xtoenergy.com Sent: Thursday, July 12, 2012 7:41 AM To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring June 2012 AIO # 9 -009 Attachments: C41 -23LN Rate and Pressure Monitoring June 2012 (AIO 9.009).xlsx Attached is the June 2012 in'ection rate and wellhead •ressure monitorin• resorts for the Middle Ground Shoal C41 -23LN as required by Administrative Approval AIO No. 9.009. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. SCANNED I4AY 0 7 2013 Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 TBG Annulus [psig] 1000 WH Injection [psig] _ --.— Injection Rate (bbl /d) 900 4500 Surface Casing Pressure CD — 7" Intermed [psig] z 4000 800 Cl) • a) a 3500 l( )K cc �t 31F 31f 31F 31E 31E 31E 31E 31E�1� �C �C )K �C )K �C )K 700 O f....) \ - _ aa) 3000 600 y c _ a) — Cr. 2500 500 2 ea "CI ▪ 2000 400 d c _ c c 0) 1500 w as 300 cu 't 1000 200 (/) 500 100 • • • • ♦ •- - _ 0 C 0 <ti P.ti <V ^ti 1\ti �I' NI P. 0 0 ^� 0 0 Net' , , \ , y o � , y o �, � � , y o ■ � ti �� � , y o �, � , y o � �, �, 6 6P ^� c§ 6 e � ^� ^ S ^ ^ h '� �� ery �, �rti �, §,y C41 -23LN (2042360) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 6/1/2012 66 5 0 3375 3500 0 6/2/2012 66 5 0 3400 3500 0 6/3/2012 65 5 0 3400 3500 0 6/4/2012 63 5 0 3400 3500 0 6/5/2012 66 5 0 3400 3500 0 6/6/2012 69 5 0 3400 3500 0 6/7/2012 71 5 0 3400 3550 0 6/8/2012 72 5 0 3400 3550 0 • 6/9/2012 76 5 0 3400 3550 0 6/10/2012 78 5 0 3400 3550 0 6/11/2012 79 5 0 3400 3550 0 6/12/2012 73 5 0 3400 3550 0 6/13/2012 76 5 0 3400 3550 0 6/14/2012 74 5 0 3400 3550 0 6/15/2012 76 5 0 3400 3550 0 6/16/2012 76 5 0 3400 3550 0 6/17/2012 78 5 0 3400 3550 0 6/18/2012 80 5 0 3400 3550 0 6/19/2012 82 5 0 3400 3550 0 6/20/2012 60 5 0 3400 3550 7 turbine down 6/21/2012 0 5 0 2400 2500 24 turbine down 6/22/2012 0 5 0 2400 2500 24 turbine down 1 6/23/2012 69 5 0 3350 3500 20 turbine down 6/24/2012 123 5 0 3350 3500 0 • 6/25/2012 102 5 0 3350 3500 0 6/26/2012 96 5 0 3350 3500 0 6/27/2012 90 5 0 3350 3500 0 6/28/2012 91 5 0 3350 3500 0 6/29/2012 89 8 0 3350 3500 0 6/30/2012 87 8 0 3350 3500 0 XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 - - � — TBG Annulus [psig] 1000 —*--WH Injection [psig] - 4500 + — Injection Rate (bbl /d) 900 —U-- Surface Casing Pressure - • N 7 4000 —e-- 7" Intermed [psig] 800 :; u) ro N cc d a` z 0 3500 ilaNEPlialiagghlOW ANN - 700 y v m a 5 3000 600 a.) _ ∎ is - a d to 2500 500 m C v _ c c 2000 400 R C • 3 H to 1500 300 • 1000 I 200 • 500 ` _ iniiiiii s � 1 00 wow i�` 1 0 0 d o , , , do NN NN , , ,yo e , , d o , , d o d o d o , ,yo Mgs C41 - Z3C.A,) P•Ti 4 2.34,0 Regg, James B (DOA) A� From: Paul_Figel @xtoenergy.com �I1l[ v Sent: Wednesday, June 06, 2012 6:55 AMff To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring May 2012 AIO # 9 -009 Attachments: C41 -23LN Rate and Pressure Monitoring May 2012 (AIO 9.009).xlsx Attached is the May 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C41 -23LN as required by Administrative Approval AIO No. 9.009. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 445NOCE) JUL 1 3 ZO Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 • • XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5,000 1000 TBG Annulus [psig] 4,500 - -» - WH Injection [psig] 900 —4- -Injection Rate (bbl /d) a) — Surface Casing Pressure $00 Li 4,000 N — e-- 7 Intermed [psig] _ co y d la d 3,500 .iC a( r. * )K )IC )n )K )K M )K ;K )K 3K )K )K )K )K )■ 700 IX C Z O o8 d 3,000 600 y Q. 2,500 _ 500 a) co i ao 'a u 2,000 - 400 E d c Q 1,500 300 a) ca u I- 1,000 200 t to 500 100 ._.,. . 0 C - - - - - - a 0 1\ <I' P.% t\l' ^V ^ NI' P. ^I' , ( 1 ' NI' <I' ^ NI' 1\1' ^� ,ti d ,yo 41' o ,tio ,y o , y o , y o , d o , y o � o , y o to ,� o , h h b h h 0 h h h 0 h • 0 C41 -23LN (2042360) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 5/1/2012 75 5 0 3,375 3,500 0 1 5/2/2012 79 5 0 3,375 3,500 0 5/3/2012 82 5 0 3,375 3,500 0 5/4/2012 81 5 0 3,375 3,500 0 5/5/2012 72 5 0 3,375 3,500 0 5/6/2012 69 5 0 3,375 3,500 0 5/7/2012 64 5 0 3,375 3,500 0 5/8/2012 67 5 0 3,375 3,500 0 5/9/2012 67 5 0 3,375 3,500 0 5/10/2012 72 5 0 3,375 3,500 0 5/11/2012 51 5 0 3,375 3,500 8 Pump down 5/12/2012 82 5 0 3,375 3,500 8 Pump down 5/13/2012 93 5 0 3,375 3,500 0 5/14/2012 85 5 0 3,375 3,500 0 5/15/2012 77 5 0 3,375 3,500 0 5/16/2012 75 5 0 3,375 3,500 0 5/17/2012 72 5 0 3,375 3,500 0 5/18/2012 61 5 0 3,375 3,500 0 5/19/2012 74 5 0 3,375 3,500 0 5/20/2012 70 5 0 3,375 3,500 0 5/21/2012 69 5 0 3,400 3,500 0 5/22/2012 64 5 0 3,400 3,500 0 5/23/2012 64 5 0 3,400 3,500 0 5/24/2012 64 5 0 3,400 3,500 0 5/25/2012 63 5 0 3,400 3,500 0 5/26/2012 63 5 0 3,400 3,500 0 5/27/2012 65 5 0 3,400 3,500 0 5/28/2012 67 5 0 3,400 3,500 0 5/29/2012 63 5 0 3,400 3,500 0 5/30/2012 59 5 0 3,400 3,500 0 5/31/2012 62 5 0 3,375 3,500 0 XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 TBG Annulus [psig] - 1000 - WH Injection [psig] _ 4500 Injection Rate (bbl /d) 900 44 - • Surface Casing Pressure - • - 4000 _e___ _e___ 7" Intermed [psig] 800 . N _ ca N rx a) -) a 3500 iv - - 700 ? o 3000 600 ai n ` O Ilk c - m I 2500 500 v 06 A i A - c 2000 400 c oa Q 1500 - 300 cz I- 1000 - $ 200 N • - 500 100 0 11 4 - 0 , , 1 , \ �O , �O , 1, \ 1• �O �O �O ��O , 1, �O �O ,0 ,LO D �O 1 , , , ,y0 <1•41,0, O O 0 O , 0 O ry 0 �O e O , O O y 0 � \� , \ 1 , �O � � O ► �\ y\ O \ � O\ ,\ c O \ ry ,\\ , \ p\ �O\ \\ ► ��o \ „� 4 O ^„� \�,, ^O \ o,y' \ \O \� , 1\ \ �O\ � �„�r� ►∎ � \ �O \ � , � \ �y r�0 \ gyp \ • \ \ ,ti' s \ \h ,� 7 ,��o \ n� 0\ r� \ ^ ∎ /'r N '''. 1. 4� ^'P' t t. h O c '\ 1\ 4 O\ O \ j \ O \ NN P r�`L 4\ \ rV ∎ t \ ry\ y\ 4\ n�\ t p\ h 4 v \ O\ Regg, James B (DOA) From: Paul_Figel @xtoenergy.com Tp 7 / l�L Sent: Thursday, May 03, 2012 5:12 AM ,\ J To: Regg, James B (DOA); Scott_Griffith @xtoenergy. om; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring April 2012 AIO # 9 -009 '' Attachments: C41 -23LN Rate and Pressure Monitoring April 2012 (AIO 9.009).xls Attached is the April 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C41 -23LN as required by Administrative Approval AIO No. 9.009. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. M Midland, TX� i ��!` UI Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 513((2.,- , XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 - -- TBG Annulus [psig] 1000 WH Injection [psig] - —+-- Injection Rate (bbl /d) 4500 900 Surface Casing Pressure - L. 4000 —0-7" Intermed [psig] 800 d - m • a) to 0 - 3500 - X X X X X X CPC 700 c 4iiaris'zisimrisio - -.�.� z �, rz ,. - y 3000 600 m 'c 'o - co I a 2500 500 2 co ea - 'a ca e 2000 400 E = m c 1500 300 6 0) 4 _ 0 1- . • 1000 200 3 500 100 ^ti o ' ` 1' p3' o ' ` ti o p3' o ' ` ti o ^' o ' ` ti o ' ` i l' o N i t' o ' ` ti O ^ti o '`ti o ' ` ti o '`ti � �� �\ a � ` � �� ti \ � � � ti , �ti \ � 1 �ti ,� OP' `' tl t � � ti ` � � ti ` y e ti ` 41' `o �ti o� o o a o� • t:. ati . • • C41 -23LN (2042360) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 4/1/2012 243 4 0 3375 3500 0 4/2/2012 67 4 0 3300 3450 0 4/3/2012 71 4 0 3300 3450 0 4/4/2012 72 4 0 3300 3450 0 4/5/2012 67 5 0 3300 3400 0 4/6/2012 62 5 0 3300 3400 0 4/7/2012 64 5 0 3300 3400 0 4/8/2012 62 5 0 3300 3400 0 4/9/2012 64 5 0 3300 3400 0 4/10/2012 65 5 0 3300 3400 0 4/11/2012 61 5 0 3300 3400 0 4/12/2012 57 5 0 3300 3400 0 4/13/2012 58 5 0 3300 3400 0 4/14/2012 64 5 0 3350 3400 0 4/15/2012 64 5 0 3350 3400 0 4/16/2012 65 5 0 3350 3400 0 4/17/2012 58 5 0 3350 3400 0 4/18/2012 63 5 0 3350 3400 0 4/19/2012 61 5 0 3375 3500 0 4/20/2012 64 5 0 3375 3500 0 4/21/2012 62 5 0 3375 3500 0 4/22/2012 62 5 0 3375 3500 0 4/23/2012 58 5 0 3375 3500 0 4/24/2012 59 5 0 3375 3500 0 4/25/2012 81 5 0 3350 3500 0 4/26/2012 58 5 0 3375 3475 0 4/27/2012 61 5 0 3375 3475 0 4/28/2012 75 5 0 3350 3500 0 4/29/2012 75 5 0 3375 3500 0 4/30/2012 70 5 0 3375 3500 0 1 1 XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 TBG Annulus [psig] 1000 WH Injection [psig] 4500 — ♦-- Injection Rate (bbl /d) 900 Surface Casing Pressure a) h 4000 — 7" Intermed [psig] 800 co U re Q 3500 �; -- 700 m 3000 600 L •= a m s 2500 ' ' 500 :a m N t i E = 2000 400 :: c c od Q 1500 300 � CD " n1111 03 o 1000 200 co • 500 k ' - - w I .� 100 0. p NNNNNNNNNNNN NN NNN NNNNNIelelelel le I, 1, rt' f lt � �0 O to 4V( � el' G ly O�, y O G il'' . O NN O NN O N O O G l'AG 41' 'I' G �o��OG O O G � o a��� � et> \D� \�1. ` )1/4 0 t 0� ` 4 . N O, s t b N ( OS � \1 \ry > • Pvt 2, C 23,0 Regg, James B (DOA) From: Paul_Figel @xtoenergy.com � 4!(q �. Sent: Monday, April 09, 2012 6:16 AM To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Feb & March 2012 AIO # 9 -009 Attachments: C41 -23LN Rate and Pressure Monitoring Feb & March 2012 (AIO 9.009).xls Middle Ground Shoal Attached is the Feb & March 2012 injection rate and wellhead pressure monitoring reports for the Mi d C41 -23LN as required by Administrative Approval AIO No. 9.009. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 AdVINEDAPR 17 n z XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 —A— TBG Annulus [psig] 5000 1000 -- WH Injection [psig] 4500 — • Injection Rate (bbl /d) 900 —f-- Surface Casing Pressure • a) 4000 0 7" Intermed [psig] 800 N N L Z = 3500 sssssssss ` .. ssil ifor___/riao1TTaanTATATATNTNT/ K 700 o 3000 600 °' • a) = 2500 500 ca d 0.5 2000 400 06 Q 1500 300 23 a • 1- 1000 200 N 500 100 3 0 O (1,'Z' O O O O O O O O O O O O O O 09.1e419. O O O O O O O O O O XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 _ TBG Annulus [psig] 1000 —— WH Injection [psig] 4500 —4— Injection Rate (bbl /d) 900 Surface Casing Pressure - • a) = 4000 7" Intermed [psig] 800 �; co vs N - w a) a 3500 700 ? c _ 08 O 0 O 3000 600 E a _ - m i 2500 500 `� .. aa)i o� A E L = 2000 400 c • 08 c Q 1500 300 R ~ 1000 • 200 • 500 100 0 1±:11 0 9 19��0 191 `O 1O 91��0$14f1090\1941909419 ti O� 0 O� ti O � ,�0191O <19��0��0 9 9, 19�10419 0 h 1' 4ti v V O� ^ D t1 t. 4 4 �O 4 A 1 0� \'` 4'' \ �` 4 N'`,, O <L;�ti N 'I' \t\ 0' 4\ 41' 4\ 41'' is t, l' • Regg, James B (DOA) From: Paul_Figel @xtoenergy.com r� 2 tie " I Sent: Monday, February 20, 2012 10:34 AM ( 1 To: Regg, James B (DOA); Scott_Griffith©xtoenergy.com; Barney_Phillips©xtoenergy.com; Greg_Duggin©xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring JAN 2012 AIO # 9 -009 Attachments: C41 -23LN Rate and Pressure Monitoring JAN 2012 (AIO 9.009).xls app " 013 Attached is the JAN 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C41 -23LN as required by Administrative Approval AIO No. 9.009. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 i u k titieD 03 1' • • XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 --rte TBG Annulus [psig] 5000 - 1000 - =+E — WH Injection [psig] - 4500 $-- Injection Rate (bbl /d) — 900 a Surface Casing Pressure - a2 c 4000 — 7 Intermed [psig] 800 2 N _ L1' O) a ` 3500 - • X. +( X X X ;K X :K ;K X X X X X K ;K :K ( X K X +I( `K 700 3 c in m 3000 600 su c a m 2500 500 0 E c 2000 400 3 c c c °d < 1500 300 u co 10 a _ t I-- c 1000 200 rn 500 100 0 C t. 3 C _ , 2 0 N1' G ^ NI' Nry Nti NeV N% Nry Ntry N N% N% N% ^ti Rti N% ^ti . N O 0 ,� � � ,�� �,� �,� \,� \ ^ 1 \,� \ry ' ti ti 17 ,y 1 0 • C41 -23LN (2042360) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 1/1/2012 58 5 0 3350 3450 0 1/2/2012 59 5 0 3350 3450 0 1/3/2012 65 5 0 3350 3450 0 1/4/2012 64 5 0 3350 3450 0 1/5/2012 56 4 0 3350 3475 0 1/6/2012 63 4 0 3350 3475 0 1/7/2012 61 4 0 3350 3475 0 1/8/2012 74 4 0 3350 3475 0 1/9/2012 62 3 0 3350 3500 0 1/10/2012 68 3 0 3350 3500 0 1/11/2012 66 3 0 3350 3500 0 1/12/2012 64 3 0 3350 3500 0 1/13/2012 67 3 0 3350 3500 0 1/14/2012 56 3 0 3350 3500 0 1/15/2012 53 3 0 3350 3500 0 1/16/2012 47 3 0 3350 3500 0 1/17/2012 42 3 0 3350 3500 0 1/18/2012 47 3 0 3350 3500 0 1/19/2012 52 4 0 3350 3500 0 1/20/2012 67 4 0 3350 3500 0 1/21/2012 66 4 0 3350 3500 0 1/22/2012 70 4 0 3350 3500 0 1/23/2012 68 4 0 3350 3500 0 1/24/2012 70 4 0 3350 3500 0 1/25/2012 71 4 0 3350 3500 0 1/26/2012 63 4 0 3350 3500 0 1/27/2012 63 4 0 3350 3500 0 1/28/2012 59 4 0 3350 3500 0 1/29/2012 54 4 0 3350 3500 0 1/30/2012 49 4 0 3350 3500 0 1/31/2012 41 4 0 3350 3500 0 I XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval AIO No. 9.009 5000 —£— TBG Annulus [psig] 1000 WH Injection [psig] 4500 - -a►--- Injection Rate (bbl /d) - 900 -- — Surface Casing Pressure 4000 —e— 7" Intermed [psig] 800 a N a 3500 4 ---'r�.;_._; ►, - , �- --' . ._ __ W.., _ - 700 ' ,a ______ -- ad ® �y r a � cn � 3000 p. th 6 c i 2500 s 500 :S 1 ad i = 2000 - - - 400 C - ad 1500 300 ca la z r 1000 200 • 500 k. ' ' - -. �- t •. — 100 0 0 4 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 \ � �� � y � � � 0 �� \ � ��� � 0 � �� , �� 0 6 ��, � \ 0 �� � ���,� \ ry �� ���, \ ��� ` 0 ��, \ �� ^ 0 �� 0 0 � � ^ ,����,��� ^0 ����� ^\O � ^ ry ry �,, ^O �� \ ��� ^,� ��� , 00�`L • • (7- C..Y.-) 'A7 / ft I n /SEANPARNELL , GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 9.009 Mr. Paul Figel Engineering Manager XTO Energy 200 North Loraine, Suite 800 Midland, TX 79701 RE: MGS C41 -23LN (PTD 2042360) Administrative Approval Revision Middle Ground Shoal (MGS) E, F, G Oil Pool � Q� 5 ppR 1 Dear Mr. Figel: In accordance with Rule 6 of Area Injection Order (AIO) 09.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Com nission) hereby GRANTS XTO Energy's (XTO)'s December 17, 2010 request for administrative approval to continue water injection in the subject well. Middle Ground Shoal (MGS) C41 -23LN exhibits tubing by inner annulus communication. The Commission finds that XTO does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of XTO's diagnostic procedures and wellhead pressure trend plots indicate that MGS C41 -23LN exhibits at least two competent barriers to the release of well pressure. It is expected that the inner annulus pressure will equalize with the injection pressure. When equalized the surface pressure of 3500 psi will be approximately 43 % of the production casing's minimum internal yield pressure rating. Should the well develop communication to the outer annulus, the 3500 psi injection pressure would represent 112 % of the surface casing's minimum internal yield pressure rating. Outer annulus pressures must be monitored and engineering controls must be installed to assure ongoing integrity of the surface casing. With such in place, the Commission believes that the well's condition would not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in MGS C41 -23LN is conditioned upon the following: 1. Injection is limited to WATER ONLY. 2. XTO shall monitor and record tubing, inner annulus and outer annulus (T /I /O) pressures and injection rate daily; 1 • AIO 9.009 December 21, 2010 Page 2 of 2 3. XTO shall submit to the AOGCC a monthly report of well pressures, injection rates. and pressure bleeds for all annuli; 4. Due to mechanical risk, a pressure test of the combined tubing and inner annulus (CMIT) is NOT required; 5. XTO shall perform a MIT -OA to 500 psi every 2 years; 6. XTO shall install, maintain and operate automatic well shut -in equipment linked to the well's outer annulus pressure. The actuation pressure shall not exceed 300 psi. Testing of the shut -in equipment (shut -down valve and mechanical or electrical pressure detection device) shall be performed in conjunction with production well pilots and safety valves. XTO shall provide to the Commission the testing procedure that will be used to verify the integrity of the well shut -in equipment linked to the outer annulus pressure; 7. XTO shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9. The initial OA MIT should be performed in conjunction with the shut -in equipment testing requirement of Rule 6. That will establish the anniversary date for future testing. DONE at Anchorage, Alaska and dated December 21, 2010. Daniel T. S ount, Jr. Cathy 11. Foerster Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather. the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented tot by the application for reconsideration." 1 4 . ; In computing a period of time above, the date of the event or default after which the designated period begins to run is not ' clu od: the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5 : g . , t that does not fall on a weekend or state holiday. v. i Lys /', • � Page 1 of 2 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Friday, December 17, 2010 11:22 AM To: Maunder, Thomas E (DOA); Scott _Griffith @xtoenergy.com; Greg_Duggin @xtoenergy.com; Steve_Phipps @xtoenergy.com; Barney_Phillips @xtoenergy.com; Regg, James B (DOA) Subject: Re: Request Permission to Continue Inj on C41 -23LN (2042360) Yes Tom as this is a request for the AA like the other wells. There is no immediate plans to rig up on the well. My mgr agrees that we need to workover these wells pretty soon. Would like to say that I may get the funds for this spring. Have a good Christmas Paul From: "Maunder, Thomas E (DOA)" [tom.maunder @alaska.go� J Sent: 12/17/2010 09:01 AM YST To: Paul Figel; Scott Griffith; Greg Duggin; Steve Phipps; Barney Phillips; "Regg, James B (DOA)" <j im.regg @alaska.gov> Subject: RE: Request Permission to Continue Inj on C41 -23LN (2042360) Paul, et al, I can treat your message as the application for AA. I would expect that the AA will be essentially in the same form as the earlier ones. Is there any plan to do any fill clean out on the well? I know such operation is not likely at this time due to ice. Call or message with any questions. Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Friday, December 17, 2010 8:45 AM To: Maunder, Thomas E (DOA); Scott _Griffith @xtoenergy.com; Greg_Duggin @xtoenergy.com; Steve_Phipps @xtoenergy.com; Barney_Phillips @xtoenergy.com; Regg, James B (DOA) Subject: Request Permission to Continue Inj on C41 -23LN (2042360) Tom, We would like to apply for AA on C41 -23LN to return to injection. It's been several months since we talked about this well when it had press communication between the tbg & casing back in April. We have just completed installing the same equipment on the wellhead as C24 -23 & A33 -14. This will have the same Press Sensor set @ 300 psi on the 7" x 10 -3/4" Surface Casing connected to the USI auto shut -off valve on the tbg injection. Please see attached files. According the last slickline jobs, we think the problem is either a hole in the tbg or a leaking dummy GLV. Unfortunately, the tubing is severely scaled up that prevents future diagnostic work with wireline. We think the tbg is not parted as we were able to slickline past the end of tbg on May 4th. On our last RU on Oct 3rd, we were unable to get past 945'. Please let me know if you require any more information or have any questions. I will be on vacation starting today & will be back on Jan 3rd. 12/20/2010 Page 2 of 2 Thank you, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 12/20/2010 TO PLF 9 -7 -05 ENERGY Current Completion MGS C41 -23LN WIW KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 4, Conductor 28 TBG: API No.: 50- 733 - 20163 -01 2 -7/8" 6.5# L80 8rd EUE to 9,175' Sidetrack: 1 -20 -05 2 -3/8" 4.7# L80 8rd EUE 9,176' to 11,681' Original Spud: 12 -17 -68 Set: 4 -14 -05 Surf Csg: 10 3/4 ", 40.5# J55 BTC. GLM MD TVD Set @ 1,653'. Cmt'd w/ 1,350 sx. #1 1975 1894 Dummy Valve #2 3566 3112 Dummy Valve #3 4874 4006 Dummy Valve #4 6027 4783 Dummy Valve #5 7211 5606 Dummy Valve #6 8143 6251 Dummy Valve Intermediate Csg: 7" 29# L80 BTC. #7 8947 6794 Dummy Valve Set @ 9,622'. Cmt'd w/ 335 sk STG 1 & #8 9617 7246 Dummy Valve 392 sk STG 2. DV Tool @ 2,515'. #9 10195 7648 Dummy Valve #10 10686 7985 Dummy Valve #11 11123 8289 Dummy Valve #12 111591 1 8597 IDummy Valve Hanger: 2 -7/8" RTS6 Box X 3 -'/i" 8rd Pin @ Surf X -Over 3 -'/2' 8rd Box X 2 -7/8" 8rd Pin @ 2' 6' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 313' Drilling Liner: 5" 18# L80/P110 STL. 2 -7/8" X Nipple (2.313" ID) 9Cr @ 320' 1 jt P110 @ liner top. 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 321' Set @ 12,039'. TOL @ 9,259'. 2 -7/8" 6.5# L80 8rd EUE @ 321 - 9,175' TIW "LX" Liner Top Pkr. X -over 2 -7/8" 8rd Box X 2 -3/8" 8rd Pin @ 9,175' Cmt'd w/ 220 sk. 2 -3/8" 4.7# L80 8rd EUE @ 9,176' - 11,634' 2 -3/8" X Nipple (1.875" ID) 8rd 9Cr @ 11,634' 10' Pup A 2 -3/8" 4.7# 8rd EUE 9Cr @ 11,636' 12.5' Baker Loc (40 -26) w/ Seals @ 11,646' 5" Baker DB Perm Pkr (32 -26) 9Cr @ 11,646'* 10' Baker SBE 13Cr @ 11,649' X -over SBE to 2 -3/8" 8rd Pin 9Cr @ 11,658' 10' Pup A 2 -3/8" 4.7# 8rd EUE 9Cr @ 11,659' 2 -3/8" XN Nipple (1.791" ID) 9Cr @ 11,669' 10' Pup A 2 -3/8" 4.7# 8rd EUE 9Cr @ 11,670' WLREG @ 11,681' *Pkr was set on DP. Tbg was 12.4' deeper than DP measure w/ all depths corrected to tbg meas. Production Liner: 3-'/" 8.8# L80 STL Slotted. Set @ 14,410'. TOL @ 11,848'. Blank Sections: 11,848 - 12,258' 12,442 - 12,540' Liner Across: HR, HN, HK, HI, HE & HC. 12,664 - 12,730' 13,192 - 13,225' 13,378 - 13,544' 13,672 - 14,097' 14,377 - 14,410' I Fish: GLV dropped 8 -29 -05 TD: 14,410' MD (9,178' TVD) �4 � X *Alaska Daily Report *un Dates: 4/30/2010 - 12/17/2010 Report for: Midland Well Name: Middle Ground Shoal C41 -23LN API: 5073320163 County: Kenai Peninsula State: Alaska Objective: Slickline First Reported: 4/20/2010 Finaled: 4/21/2010 Rig: Rig Number: Rig Type: AFE #: AFE Total: AFE Remaining: Activity Date: 04/20/2010 Report Date: 06/02/2010 Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with full drift 2 -3/8" scratcher to 11,649' WLM and located XN nipple. Brushed XN nipple several times then checked out end of tubing to 11,750' WLM. No obstructions in tubing. Pull out hole. - Shut down wireline for the night. Prep tools to plug tubing tail for tomorrow. Activity Date: 04/2112010 Report Date: 06102/2010 Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with 1.875" PXN plug body on X -line running tool. Went through 2 -7/8" tubing fine. Got through crossover to 2 -3/8" at 9145' WLM just fine. Sat down at 10,150' WLM. Had no jar action. Had production operator flow me out of the well using a 1/2" bleed hose to the header. Tools freed. Pull out of hole. - Out of hole. Inspect tools. Found the plug bottom was full of a very fine, black & wet scale. - Called out an alternate type plug to run from Pollard. Job was postponed till next hitch. See continuation on 4/3/2010. Objective: Slickline First Reported: 4/30/2010 Finaled: 5/5/2010 Rig: Rig Number: Rig Type: AFE #: AFE Total: AFE Remaining: Activity Date: 0413012010 Report Date: 06/0212010 Operation Summary: - Rig up wireline. - Run in hole with a modified standing valve on a 1.875" XN lock with out locating keys. Fell fine thru the 2 -7/8 ". Got thru crossover okay at 9145' WLM. Continue down hole. Sat down at 10,168' WLM. Work thru bridges to 10,173'. Pull up hole in the 2 -3/8" to 9,000'. Back flow well. Run back down hole. Broke thru bridge at 10,173'. (NOTE: #9 GLM is at 10,195' MD). Continue down hole. Sat down at 10,644' WLM. Worked thru bridges at 10,652 110,654 / 10,662 / 10,664 / 10,667 / 10,669 / 10,680 and broke free. (NOTE: #10 GLM at 10,686' MD) Continue down hole. Sat down at 11,510' WLM. Worked thru bridge at 11,514 and then hit hard obstruction at 11,517' Pull up hole in to 2 -7/8" to 9000'. Back flow well to move cuttings. Continue down hole. Sat down at 11,469' WLM. Worked thru numerous tight spots from 11,473 to 11,568' where tools got solid. (NOTE: #12 GLM at 11,591' MD). Pulled up hole to 11,495' and tools hung up with out jars. Had operator back flow well while I worked wire. Tools freed at 11,320'. Pull out of hole. Inspect tools. Plug bottom full of a black, wet, fine scale that has grit in it and stains hands and tools like ink. - Run in hole with 2 -3/8" full dress scracther. Sat down at 11,425. Worked scale bridges at 11,425 / 11,432 to 436 / 11,528 / 11,532 / 11,546 / then got solid at 11,548. Pull up hole to 9000 in 2 -7/8" to back flow. Continue down hole. Sat down at 11,425. Broke thru bridges at 11,432 to 43611,528 / 11,532 / 11,546. Then hit solid at 11,548'. Pull up hole to 9000 in 2 -7/8" to back flow. Continue down hole. Sat down at 11,542. Cut scale bridges at 11,545 / 11,548 / 11,578 became solid. Pull up hole to 9000 in 2 -7/8" to back flow. Continue down hole. Sat down at 11,576 to 11,591 solid but broke thru. Then sat down at 11,608' WLM. Worked tools quite a while but could not get lower. Pull out of hole to inspect tools. Inspect tools. Plug bottom full of a black, wet, fine scale. Activity Date: 05/01/2010 Report Date: 06/02/2010 Operation Summary: Report Run on: 12/17/2010 Page 1 of 3 WellView ;If XI*Alaska Daily Report n Dates: 4/30/2010 - 12/17/2010 eport for: Midland - Set up MIT's on Platform A. Return to Platform C. - Rig up wireline and pressure test lubricator. - Run in hole with 2 -3/8" scratcher. Hit numerous spots of scale / fill bridges in the 2 -3/8" tubing from 11,534' to 11,624'. Pull up hole to 9000' and stand by for safety meeting for 1 hour. Went back down hole and had lost hole to 11,594'. Pull out of hole. - Secure equipment and SDFN. - Had production operator inject 45 BBL's down hole to clear debris is tubing. Activity Date: 05/02/2010 Report Date: 06/0212010 Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with 2 -3/8" scratcher all the way out of tubing tail at 11,750' no problems. Pull up hole and work XN nipple several times. Pull out of hole. - NOTE: Found a 3" piece of wire hung up in the spang jars. There was a wireline fishing job on this well 5 years ago. - Run in hole with a modified standing valve on a 1.875" XN lock with out locating keys. Started to count collars at 9600' and then sat down solid at 9850'. Could not work lower. Pull out of hole. - Run in hole with 1.845" gauge ring. Sat down on what is assumed a piece of old wire at 9894'. Jar through and then continue down hole. Tagged XN nipple at 11,651'. Pull out of hole. - Secure equipment and SDFN. Activity Date: 05/03/2010 Report Date: 06/02/2010 Operation Summary: - Performing AOGC -SVS tests on Platforms A & C. Activity Date: 05/0412010 Report Date: 06/02/2010 Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with a modified standing valve on a 1.875" XN lock with out locating keys. Sat down on obstruction (wire ?) at 10,072' and could not get lower. Pull out of hole. - Run in hole with 1.90" gauge ring. Tagged obstruction at 10,075'. Jarred through and then chased obstruction through 10,104 -106' and 10,212'. Continue down hole and tag X nipple at 11,612'. Pull out of hole. - Secure equipment and SDFN. Activity Date: 05/05/2010 Report Date: 06/02/2010 Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with a modified standing valve on a 1.875" XN lock with out locating keys. Was able to locate & set in XN nipple at 11,651'. Pull out of hole. - Perform 2) 30 minute pressure tests on tubing with annulus at 125 PSI. TIME TUBING ANNULUS Static 925 125 10:20 3500 200 10:25 3200 225 10:30 2740 300 10:35 2240 375 10:40 1950 425 10:45 1675 450 10:50 1450 500 - Results of test tell us that we have a high pressure / low volume leak from the tubing to annulus and we feel that the packer to casing wall integrity is good. - Run in hole with 2 -3/8" GS pulling tool to 11,651'. Latch & pull plug. Pull out of hole. - Rig down wireline. Will return to this well for further troubleshooting after we catch up on some production well maintenance. Objective: Slickline First Reported: 10/3/2010 Finaled: 10/3/2010 Rig: Rig Number: Rig Type: AFE #: AFE Total: AFE Remaining: Activity Date: 10/03/2010 Report Date: 10/07/2010 Report Run on: 12/17/2010 Page 2 of 3 WellView X '*Alaska Daily Report un Dates: 4/30/2010 - 12/17/2010 eport for: Midland Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with 2 -7/8" D &D Hole Finder plug to 10' WLM and hit scale. Worked tools a minute then pull out of hole. - Run in hole with 2.29" gauge ring. Cut numerous scale bridges from 10' to 934' WLM then scale became solid. Cut solid scale to 945' WLM. Consult with foreman. Pull out of hole. - Rig down wireline. End of Report Report Run on: 12/17/2010 Page 3 of 3 WellView t '� ' � �. ,. °F t:'u- `' � 1 �. / y �' �'� � /� m ,��, ' "' �y # t i t � 6 r 1 a .' y +.._.. � .., i +. a • `1 ... . *� %.. ,�� T .. 1 ' fi �� �: .�* � ` 1 {' ���FF4 z�.. �� µ #x a 7 ¢ � `� yy ,,, TT n S. i a +� /" �" 't �" :.. _ � k. ,tf ,�� # � �+R �/... IW ,fi '�:� a • — a P d L ik Akit * NNEL NO77CF': ot& for Val 5 r s .. It j s� i sd H!X- 1 rncF C41 -23 INJ HEMLOCK BBL 1 $a 160 140 120 100 80 60 4D 20 0 12117ro9 211 3f1 411 5!1 611 7f1 811 9!1 1011 11f1 12/16/10 — Gas ail —Water — Water Inj —Gas Injection -- CO2 Injection —Gas Target — ail T Psi C 41-23 INJ HEMLOCK Hrs D n 3,760 30 3 20 3 20 3 ,000 24 41� 22 2,600 20 2 18 2,000 10 1,760 1 4 1,600 12 1,260 1 • 1,000 0 750 - - a 5 a 4 i 1 250 - 2 - 12/17/09 2/1 3/1 4/1 611 E/1 7/1 0/1 0/1 10/1 11/1 12/16/10 — Casing Pressure Tubing Pressure —Annulus Pressure -- urfaceasingPressure - -- Inte • • Page 1 of 2 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Friday, October 29, 2010 6:54 AM To: Maunder, Thomas E (DOA) Cc: Greg_Duggin @xtoenergy.com; Scott_Griffith @xtoenergy.com Subject: RE: XTO MGS C41 -23LN Inj (204 -236) Tom, We estimate 1 month to have all equipment installed. I am hopeful that we will get to workover at least 2 well injectors that have press communication next year. This well especially since it supports several wells in the West Flank and only was putting 100 BWIPD in the ground. Paul "Maunder, Thomas E (DOA)" To Paul_Figel @xtoenergy.com, Scott_Griffith @xtoenergy.com, <tom.maunder @alaska.gov> Greg_Duggin @xtoenergy.com cc 10/28/2010 06:10 PM Subject RE: XTO MGS C41 -23LN Inj $ PP APR 1 2 2011 Paul, Sorry about the delayed reply. Yes, that sounds appropriate. When do you think that the equipment might be installed? Is there any plan for a cleanout? Not suggesting it, but asking. Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Monday, October 25, 2010 8:47 AM To: Scott_Griffith @xtoenergy.com; Maunder, Thomas E (DOA); Greg_Duggin @xtoenergy.com Subject: XTO MGS C41 -23LN Inj Tom, The C41 -23LN WIW was shut -in back in April with pressure communication on the tbg annulus. The well had dummy gas lift valves installed back in 2005 when the well was converted to injection. Nothing was done with the well until early Oct when slickline attempted to RIH to check for a bad valve. However, SL encountered scale and did not chance going in deeper. As you can see this well only injects about 100 BWIPD but being on the west flank, the oil production is ±50% per bbl of water injected vs east flank where the ratio is much smaller. I was requesting that we pursue an Administrative Approval with the OA pressure sensor & auto -shut valves on WH as 2/18/2011 Page 2 of 2 we did on the C42 -23 & A33 -14. Let me know what you think or if I need to provide more info. Thanks, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 CeII: 432 - 553 -5217 Fax: 432 - 687 -0862 2/18/2011 • • Daily Activity and Cost Summary NRRGY Section: Township: Range: Well Name: Middle Ground Shoal 041-23 INJ AP Field bane PemltNlmter Std! We II COetg ualbe ll4e (Edit 5073320163 dle Ground Shoal Alaska Org iral 03 Eleatic. Qy OroncI eleven (19 -Grow rd DlMaece g 'Spa Dab Rg Re kale OA Taal Depii QtlQj 105.00 1/1711968 Jobs Jca cabgorq P rmaryJob T14e ! N mall Job Type SemldantJob T y p e ! F hal Jab TIPe lE dit Well Maintenance Slickline Start Dab EEO Dab Oblectbe u1aIlag Merest (1.) 10/312010 10/312010 Attempt to set tubing plug AFE Edit AFE Hunter AFE Dab AF E Type AFESLEW Total APE AIWA it Total Fh Cast APE - Fan Whale Rg Rg Number ore rabr NI SartDab Rg Release Dab 'Edit 101312010 00:00 - 10(712010 00:00 Edit Rpt No. Ope raal SlmmaryN 1 DallyC0stT061 Cum CaStTO Dab 1 .0 - Rig up wireline and pressure test lubricator. - Run in hole with 2 -70" D &D Hole Finder plug to 10' VVLM and hit scale. Worked tools a minute then pull out of hole. - Run in hole with 2.29" gauge ring. Cut numerous scale bridges from 10' to 934' VVLM then scale became solid. Cut solid scale to 945 WLM. Consult with foreman. Pull out of hole. - Rig down wireline. Remand N 2 Coeetriatbl SlmmaryN 3 www.xtoenergy.com Page 111 Report Printed: 10/25/2010 M S (VV) C41 -23LN (INJ) 10000 MDDLE GROUND SHOAL ( 1000 - ____ -__ -_ ___ - tI _� 100 - - �r ..pwr-- ■ - rt \ 1 . 10 i i M (VV) C41 -23LN (INJ) CD VVtr __ -- ® - CD Gas - - I -T --w- CD_VVtrinj • CD InjR - ess • 1 i - test water - bbls • testgas - rrmf A , A GF FAP ! - - I 2004 05 06 07 08 09 10 Cum Oil 10122.000 Date Maunder Thomas E DOA From. Maunder, Thomas E (DOA) Sent: Thursday, May 06, 2010 9:28 AM To: Barney_Phillips @xtoenergy.com Cc: Paul_Figel @xtoenergy.com; Cody_Mishler @xtoenergy.com Subject: RE: XTO Energy - MGS - C41 -23 Barney, Thanks for the update. Continuing your diagnostics is appropriate. At this point, it appears that an AA like for the other well may be the final remedy if you are unable to eliminate the communication. Please keep us informed. Tom Maunder, PE AOGCC - - - -- Original Message---- - From: Barney_Phillips @ xtoenergy.com [ mailto :Barney_Phillips @xtoenergy.com] Sent: Wednesday, May 05, 2010 5:06 PM To: Maunder, Thomas E (DOA) Cc: Paul_Figel @xtoenergy.com; Cody_Mishler @xtoenergy.com Subject: XTO Energy - MGS - C41 -23 (See attached file: C41 -23LN Current WBD 9 -7 -05 CTI.pdf) Hello Tom, As per our earlier conversation concerning MGS - C41 -23 Water Injector: We have been working this past week with slick line to isolate the communication leak to the annulus. Some well conditions involving scale had to be dealt with but we have the well in good shape now. This morning we were able to set a one way check valve type plug in the Otis XN- Nipple at 11,669' MD. We performed 2 separate 30 minute pressure tests using 3500 PSI injection FIW down the tubing with the annulus bled down to 125 PSI and isolated. The results from both tests were almost identical. Pressure test numbers from the initial test were as follows: TIME TUBING ANNULUS Static 925 125 10:20 3500 200 Note: 6/10 BBL to reach test pressure against plug. 10:25 3200 225 10:30 2740 300 10:35 2240 375 10:40 1950 425 10:45 1675 450 10:50 1450 500 We left the well tatic to see where it would equalize. End pressures at 1 -1/2 hours were 925 tubing / 600 annulus. The results of this test indicate to us that we have a high pressure / low volume leak and that it is most likely a tubing to annulus problem. We feel at this time that the packer seal integrity to the annulus casing is not the culprit. Our next step in isolating this tubing to annulus leak would be to test the tubing hanger by installing a one way check valve on a 2.313" X -Lock in the X- Landing Nipple at 320' MD. 1 0 i!-7/811 With a succesful hanger test completed, we then propose to set D &D Pack Off style plug using the 2 -3/8" x 2 -7/8" crossover at 9175' MD as the anchor. Results from this test will show if the leak is within the 2 -3/8" tubing string and packer seal assembly or if the leak is above the proposed plug in the 2 -7/8" string. Currently we have some oil producing wells that we need to perform some slick line maintenance projects on. We plan to leave C41 -23 shut in (Not Injecting) and will return to troubleshooting and leak detection soon. We will keep you informed of our progress in the leak detection or any other developments. Best regards, Barney Phillips barney_phillips@xtoenergy.com Platform A: 907 - 776 -5241 Platform C: 907 - 776 -5251 2 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Scott_Griffith @xtoenergy.com Sent: Saturday, April 24, 2010 9:41 AM To: Maunder, Thomas E (DOA) Cc: Greg_Duggin @xtoenergy.com; Paul_Figel @xtoenergy.com; Steve_Phipps @xtoenergy.com; Cody_Mishler @xtoenergy.com Subject: RE: C41 -23LN Rate Press data plot Importance: High Tom, have communicated to all our production operators and supervisors that this type of event should have never occurred. Paul, Greg, Cody, Steve and I have discussed in detail how this happened and how we will prevent it from happening again in the future. In reference to your question, "What are our standing orders in regards to monitoring our injection wells ?" Our production operators are expected to report all observations that indicate any type of integrity issue with an injection well immediately to their supervisor. If the observation made by the production operator warrants shutting the well in immediately that is what they are expected to do. The supervisor then contacts either Greg or myself, and we would contact the AOGCC. We have reviewed the AOGCC Area Injection Order No. 9, all the "requirements" of the order and why we are required to strictly adhere to all the rules /requirements of the order with all our crews. We have identified several facts that resulted in this event not being reported as required. The production operators on shift were "trouble shooting" to try and identify what the issue might be. The production operators did not contact their supervisor to report the event. Management did not identify that we had an issue when reviewing the daily production reports. Our IT department while implementing a new electronic production report program, did not realize nor had they been informed of the importance of seeing more than just one day's worth of information by those reviewing the reports. *The new electronic production report program, eVIN had run parallel to our old program for several months before being implemented on January 1, 2010. We are still working to make sure that we have all the data reports needed to effectively conduct our business. The bottom line is that our production operators should have notified their supervisors immediately and they did not! We have clearly communicated our "expectations" to all of our employees about their responsibilities in regards to the requirements of our AOGCC Area Injection Order and the consequences our operation could expect by our not strictly adhering to requirements the order. Please let me know if you should need any other concerns about this event. Respectfully - Scott A. Griffith Production Superintendent XTO Energy Inc. 52260 Wik Road Kenai, Alaska 99611 907.776.2506 Direct 907.398.7108 Cell 907.776.2542 Fax Scott 12/20/2010 Page 1 of • Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Friday, April 23, 2010 11:42 AM To: Maunder, Thomas E (DOA) Cc: Barney_Phillips @xtoenergy.com; Cody_Mishler @xtoenergy.com; Scott_Griffith @xtoenergy.com Subject: RE: C41 -23LN Rate Press data plot Tom, Scott & I were discussing this breakdown. He will contact you on how we will deal with this in the future. In the meantime, I've had the IT dept enhance our new software that will graphically display the annulus pressure on our injection plots where before it was only seen on the daily production report for 1 specific date. It will be easier to spot on day to day plot. First & foremost, the operator on board needs to relate this info to his supervisor immediately. Paul `!I� ` APR E_ 2, 2, 0 1 "Maunder, Thomas E (DOA)" - .m.maunder @alaska.gov> To Paul_Figel @xtoenergy.com Scott_Griffith @xtoenergy.com, Cody_Mishl= • xtoenergy.com, 04/21/201 :48 PM cc Barney_Phillips @xtoenergy.com Subject RE: C41 -23LN Rate Press data plo Thanks for the information Paul. It a. s -ars that the press. e climb was pretty rapid after April 8. I would think the pressure increase on 4/8, the need to b��and the su . equent pressure increase to higher values following the bleed should have triggered at least an inte notif ation. As I pointed out in an earlier message, the Area Injection Order rule is pretty clear as to what ac s XTO is required to take. What sort of "standing orders" are in place regarding injection well monitoring? Tom Maunder, PE AOGCC From: Paul_Figel @xt• ° ergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Wednesday, pril 21, 2010 8:17 AM To: Maunder, TP .mas E (DOA) Cc: Scott_Gr . ith @xtoenergy.com; Cody_Mishler @xtoenergy.com; Barney_Phillips @xtoene = .com Subject: '41 -23LN Rate Press data plot .m, Attached is the data & plot for the Injector C41 -23LN. The injection rate did not increase as the pressure t1 -Sca c...1317 2/17/2011 • Page 2 of 2 "Maunder, Thomas E (DOA)" To <tom.maunder @alaska.gov> Paul_Figel @xtoenergy.com cc Scott_Griffith @xtoenergy.com, Cody_Mishler @xtoenergy.com, 04/21/2010 09:48 AM Barney_Phillips @xtoenergy.com Subject RE: C41 -23LN Rate Press data plot Thanks for the information Paul. It appears that the pressure climb was pretty rapid after April 8. 1 would think the pressure increase on 4/8, the need to bleed and the subsequent pressure increase to higher values following the bleed should have triggered at least an internal notification. As I pointed out in an earlier message, the Area Injection Order rule is pretty clear as to what actions XTO is required to take. What sort of "standing orders" are in place regarding injection well monitoring? ' Tom Maunder, PE ' AOGCC A ��, � From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Wednesday, April 21, 2010 8:17 AM To: Maunder, Thomas E (DOA) Cc: Scott_Griffith @xtoenergy.com; Cody_Mishler @xtoenergy.com; Barney_Phillips @xtoenergy.com Subject: C41 -23LN Rate Press data plot Tom, Attached is the data & plot for the Injector C41 -231-N. The injection rate did not increase as the pressure communicated on the tbg annulus. Barney is trouble shooting if it is the packer or leak in a dummy GLV. As far as not catching the problem immediately, obviously our operator did not communicate to the right person. And unfortunately, Jeff Gasch did not catch it while he was hanging around for his last 2 weeks prior to his departure. I apologize for the mistake and hope we rectify the situation. Please let me know if there is anything else that you need. Thank you, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 12/20/2010 XTO Energy - C41 -23LN Rate and Pressure Monitoring 4000 - 200 3500 175 3000 150 N c m c a ° w 0 2500- 125 a U � m .� 3 oS 2000 100 y CL c � Q 1500 75 U Q1 d � U K � L) 1000 50 N 500 25 0 0 o \ , y o \ , y o \ti \p o \,yo o p \ , y o \1y \ti q \ I'lp N.ZP ^N\ ^^ \gy ^,L �1. — CsgxTbg Annulus Pressure —*O—Injection Pressure —0—Injection Rate (bbl /d) (Surface Cas Pressure Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 19, 2010 10:37 AM To: Barney_Phillips @xtoenergy.com Cc: Paul_Figel @xtoenergy.com; Cody_Mishler @xtoenergy.com Subject: RE: XTO Energy ref C41 -23LN Water Injector Barney, et al, Thanks for the planned diagnostic procedure. There is not a problem with conducting this work. Could you please add some comments regarding the recent well history about the communication event? It should include the details (dates /pressures /etc) that you and I discussed on the phone. It would also be helpful to include the actual pressure observations graphically (if possible) like is done for C24 -23. Also, please note that Rule 7 (Well Integrity Failure) of AIO 9 states, "Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action." Tom Maunder, PE AOGCC - - - -- Original Message---- - From: Barney_Phillips @ xtoenergy.com [ mailto :Barney_Phillips@xtoenergy.com] Sent: Monday, April 19, 2010 10:20 AM To: Maunder, Thomas E (DOA) Cc: Paul_Figel @xtoenergy.com; Cody_Mishler @xtoenergy.com Subject: XTO Energy ref C41 -23LN Water Injector (See attached file: C41 -23LN Current WBD 9 -7 -05 CTI.pdf)(See attached file: C41 -23 Draft Procedure - Leak Det.doc) Hello Tom, As requested, I am attaching a procedure we plan to follow to perform the leak detection our our water injection well C41 -23LN. I have also attached a copy of the current schematic for reference. Please call me on Platform C or respond to this note should you have any questions or need more information. Regards, Barney Phillips barney _phillips @xtoenergy.com Platform A: 907 - 776 -5241 Platform C: 907 - 776 -5251 1 C41 -23 Leak Detection Procedure - Shut in Waterflood injection to allow tubing pressure to drop below 1000 PSI before rigging up wireline. - Bleed 7" annulus equal to tubing pressure. - Rig up wireline. - Run in hole with 2 -3/8" full drift scratcher. Drift thru end of tubing at 11,681' MD. Work area of 1.791" ID XN- Landing Nipple at 11,669' MD. POH. - Run in hole with 2 -7/8" scratcher. Drift tubing and tag 2 -7/8" x 2 -3/8" crossover at 9175' MD. POH. - Run in hole with 2 -3/8" PXN plug body to 2 -3/8" XN- Landing nipple at 11,669' MD. POH. - Run in hole with 2 -3/8" PXN equalizing prong to PXN plug body at 11,669' MD. POH. - Ensure that 7" annulus is equal to tubing pressure. (Estimate 1000 PSI). - Using Waterflood, pressure up tubing string to 2500 PSI. - Take 30 minute readings for a minimum of 12 hours (unless leak is obvious sooner) to see if annulus pressure increases. A drop in tubing pressure and increase in annulus pressure will confirm tubing to casing communication. NOTE: Times listed are based on annulus building approximately 300 PSI in 12 hours while well was on injection. - If there is no annulus pressure increase from first test, continue to second test. - Bleed annulus and tubing down to 500 PSI. - Take 30 minute readings for a minimum of 12 hours (unless leak is obvious sooner) to see if annulus pressure increases while tubing pressure remains the same. If annulus pressure increases and tubing pressure remains at 500 PSI, this will confirm a packer leak. We will have to get this far in the tubing / annulus pressure tests before we know how to proceed next. r~ MEMORANDUM TO: Jim Regg ~ ~l ~~~~ D'1 P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, November 19, 2009 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C41-23LN MGS C41-23LN Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: MGS C41-23LN Insp Num: mitLG091119112434 Rel Insp Num: API Well Number: 50-733-20163-01-00 permit Number: 204-236-0 Inspector Name: Lou Grimaldi Inspection Date: 11/16/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. r Well C41-23LN~Type Irij. ~ _ I TVD ~ ~ 8629 ~ IA T 50 j 2320 '' ~ ~ ' ----- 2320 ~ 2320 /I -- _ - -a---~-- 2042360 ' ~SPT ' P.T.D~ TypeTest ~ Test -- ,-- - --~ ! 2157 ~'i 60 60 -} pst i OA --r--- 60 60 4YRTST P P/F Interval ~ Tubing 3450 I. 3450 - ~_ _~__~ 3450 3450 ~ _ __._. ~--- __ __ NOtes: Good solid test. __ F !~ ry Thursday, November 19, 2009 Page 1 of 1 ~;. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: XTO Energy MGS Platform C 11/16/09 B. Phillips Lou Grimaldi ~ 4~r ~ C~ Packer De th Pretest Initial 15 Min. 30 Min. Well C41-23LN T e In'. W TVD 8,629' Tubin 3,450 3,450 3,450 3,450 Interval 4 P.T.D. 204236 T e test P Test si 2157 Casin 50 2,320 2,320 2,320 P/F P Notes: OA 60 60 60 60 Well T e In'. TVD Tubin Interval P.T.D. T test Test si Casin PIF Notes: OA Well T e In~. TVD Tubin Interval P.T.D. T etest Test si Casin P/F Notes: OA Well T In'. TVD Tubin Interval P.T.D. T e test Test si Casin PIF Notes: OA Well T e In'. TVD Tubin Interval P.T.D. T test Test si Casin P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test , . 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) ~~ D~~ ~. ~ ~~g MIT Report Form BFL 11/27/07 MIT MGS C 11-16-09.x1s • y = ~ - MICROFILMED 43/01 /2008 .:. .{ ~-- . ~.,~ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE • F:1LaserFicheK;vrPgs_Ins~ettslMicrofilm Marker.doc / (,( M.., 1.d t) .., DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 ~"q,.J. 21 J--..J. ~~)- API No. 50-733-20163-01-00 ~.. Permit to Drill 2042360 Well Name/No. MGS C41-23LN Operator XTO ENERGY INC MD 14410/ TVD 9177 r' Completion Date 4/14/2005./ Completion Status 1-01 L Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~~-- ----~-- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH 9197 14410 e Log/ Electr Data Digital Dataset Ty-p~ed/Frmt NUmber ~~-c Lis 13180 i ~_...". Name I nd u ction/Resistivity Log Log Run Scale Media No -_.._.__.~~._.- _._-~----~._~- ._~~_.~ Received Comments 6/10/2005 GRlRESISTIVITY LWD-¡ ___-.J Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Daily History Received? .9 N Formation Tops .Q / N Analysis Received? ~ - Comments: -_._---~~.-_..- ~jto --~ Compliance Reviewed By: -~~--- Date: ~ N.~ ). c).:;) ., . . ~TO ~kRGY XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) November 8, 2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 1 4 2005 Alaska Oil & Gas Cons. Commission Anchorage RE: Sundry Well Operations Report: Well C41-23LN Convert to Water Injection Dear Mr. Norman, XTO Energy, Inc. hereby submits its Sundry Operations Report (Form 10-404) for converting the C41- 23LN from a producer into a water injection well. This well is located on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. The well had the MIT performed on September 25, 2005. Please find attached the following information for your files: 1. Form 10-404 Sundry Well Operations Report 2. Daily Report of Operations 3. Present Wellbore Schematic 4. MIT Test form Ifyòu have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, Va..t 01· Çß Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith t .. STATE OF ALASKA A ALASW'OIL AND GAS CONSERVATION COMM~N REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 1 4 2005 Alaska Oil & Gas Cons. Commissil 1 . Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator XTO Energy Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 Exploratory 0 204-236 3. Address: 200 N. Loraine, Ste 800, Midland, Tx 79701 Stratigraphic 0 Service 0 6. API Number: 50-733-20163-01 7. KB Elevation (ft): 9. Well Name and Number: 35' C41-23LN 8. Property Designation: 10. Field/Pool(s): ADL 18756 Middle Ground Shoal 11. Present Well Condition Summary: Total Depth measured 14,410 feet Plugs (measured) NIA true vertical 9177 feet Junk (measured) NIA Effective Depth measured 14,377 feet true vertical 9177 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1653' 10-3/4" 1653' 1584' 3130 psi 1580 psi Intermediate 9622' 7" 9622' 7249' 8160 psi 7020 psi Production 2780' 5" 12,039' 8751' 10,140 psi 1 0,490 psi Liner 2562' 3-1/2" 14,410' 9178' Slotted Slotted Perforation depth: Measured depth: 12,258' - 14,377' True Vertical depth: 8765' - 9177' Tubing: (size, grade, and measured depth) 2-7/8" & 2-3/8" L80 11,681' Packers and SSSV (type and measured depth) Baker 5" DB Perm 11,646' No SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): None RBDMS 8FL NOV 1 4 2005 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 68 67 0 540 80 Subsequent to operation: NA NA 197 100 3500 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: OilO Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: 305-163 Contact Paul Figel Printed Name Paul Figel Title Engineering Manager Signature ~J J;t. ~ Phone 432-620-6743 Date 11/9/2005 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only . . 1 XTO ENERGY INC. Midland Well W orkover Report Objective: Change Out GL V wI dummy valves & Convert well to Injection 7/19/05 All depths are WLM. RU WL. RIH wl2-1/2" scratcher to 9,154'. Tagged 2-3/8" x-over. No obstructions in tbg. POOH. Rill wl2-3/8" scratcher to 11,649' & located XN nipple & exited EOT @ 11,750'. No obstructions in tbg. POOH. RDWL. RWTP. 8/25/05 All depths are WLM unless when noted. RU WL. Rill wl2-1I2" scratcher to 9,154'. Tagged 2-3/8" x-over. No obstructions in tbg. PUB & scratched across GLM's 7 - 1. Rill w/2-3/8" scratcher to 11,649' & located XN nipple. Brushed XN nipple several times then checked out EOT to 11,750'. No obstructions in tbg. PUB & scratched across GLM's 12 - 8. SDFN. 8/26/05 Rill w Ipulling tool to GLM # 12 @ 11,575'. Was able to locate & sit dwn in the pocket, but could not latch orifice valve. Also failed to pull GLM #11 @ 11,104'. PUB to GLM #10 @ 10,667' & latched GLV. Tbg was @ 425 psi & csg @ 490 psi. Well had been SI for 1-112 hrs at this pt. All indications were that the well was equalized. Pulled GL V & tools were blown up hole. WL parted @ kinked wire 4' above the rope socket when passing through the stuffing box, dropping the pulling tools DH. RU fishing string & extra lubricator. RIH wl2" IDC pulling tool to TOF @ 11,632' (KOT was sitting in XN nipple). Failed to latch fish due to wire. POOH. RIH wl2" IDC split skirt pulling tool to 11,632'. No success. POOH. SDFN. 8/27/05 Rill w/1.75" impression block to 11,632'. Impression showed 3 wire marks but no rope socket. RIH wl2", 2 prong wire grab baited on 2" RB pulling tool to 11,632'. Latched & POOH w/4' of wire from top of tool string. RIH w/2" IDC pulling tool to 11,632'. Latched & POOH w/entire fish. GL V #10 was in tact on the pulling tool. SDFN. 8/28/05 Rill w/pulling tool to GLM @12 @ 11,575'. Could not latch orifice valve. PUB to GLM #11 @ 11,104' & latched & POOH w/GLV. Rill w/pulling tool & failed to get GLV #12 again. PUB & latched GL V #9 @ 10,178'. RIH w/1.25" impression block to GLM #12 GLM. Impression was inconclusive. RIH & POOH w/GL V #8 @ 9,603'. Rill to check set tool in GLM #12. Was very difficult to sit dwn on valve. POOH. Check set tool indicated valve is still in pocket. RIH to GLM #12. Could sit down in pocket, but could not get a bite on pulling tool. POOH. Shimmed & repositioned IDC. Rill w/pulling tool to GLM #12. Was unable to latch GLV. SDFN. 8/29/05 Rill w/1.25" x 7/8" latch Bowen overshot to GLM #12. Worked tools 20 min & was able to sit dwn & latch orifice valve. POOH w/orifice valve. RIH w/pulling tool to GLM #7 but was unable to latch GL V. PUH to GLM #6 @ 8,122' & latched GL V. POOH. Made another attempt @ GLV #7 but no success. PUB to GLM #5 @ 7,196'but unable to locate pocket. PUB to GLM #4 @ 6,008' & latched GLV. POOH. Rill & was finally able to latch & . . 2 POOH w/GLV #7. Pulled GLV #5 @ 7,196', GLV #3 @ 4,854', GLV #2 @ 3,545' & GLV #1 @ 1,951'. All GLV's are out. RIH & set dummy valves in GLM's, 1,2 & 3. SDFN. 8/30/05 RIH & set dummy valves in GLM's 4, 5, 6, 7 & 8. Had trouble setting dummy valve in GLM #9 & ended up dropping the valve DH. RIH wl2nd dummy valve for GLM #9 & set OK. Set dummy valves in GLM's #10 & #11. All GLM's exeept #12 are closed off. MO WL equipment to RU iron to pmp pkr fluid. SDFN. 8/31/05 RU treating line. Pmpd 450 bbls FIW dwn the TCA through pocket #12. Pmpd 320 bbls pkr fluid dwn baek side. RU WL. RIH & set dummy valve in GLM #12 @ 11,575'. RIH wl2" N-test tool to XN nipple @ 11,654'. RU jumper line fr waterflood. Bled gas eap off tbg fr 500 psi to O. Annulus is @ 0 psi. Press tstd tbg to 3,600 psi for 30 minutes. No bleed-off. RIH & pulled N-test tool. RD WL. 9/3/05 Fin installing surface inj lines. Started up inj @ 16:30 hrs @ 700 BWIPD @ 150 psi WHP. TCA = 0 psi. Surf esg press = 180 psi. 9/4/05 Inj 746 bbls over last 24 hrs. Inj press @ 3,450 psi. TCA = 0 psi. Surf esg press = 180 psi. 9/5/05 Inj 506 bbls over last 24 hrs. Inj press @ 3,450 psi. TCA = 0 psi. Surf esg press = 180 psi. 9/6/05 Inj 396 bbls over last 24 hrs. Inj press @ 3,450 psi. TCA = 0 psi. Surf esg press = 180 psi. 9/7/05 Inj 337 bbls over last 24 hrs. Inj press @ 3,500 psi. TCA = 0 psi. Surf esg press = 140 psi. 9/8/05 Inj 310 bbls over last 24 hrs. Inj press @ 3,500 psi. TCA = 0 psi. Surf esg press = 138 psi. 9/9/05 Inj 297 bbls @ 3,500 psi. TCA = 0 psi. Surf esg press = 140 psi. 9/10/05 Inj 330 bbls @ 3,500 psi. TCA = 0 psi. Surf esg press = 140 psi. 9/11/05 Inj 309 bbls @ 3,500 psi. TCA = 0 psi. Surf esg press = 140 psi. 9/12/05 Inj 300 bbls @ 3,500 psi. TCA = 0 psi. Surf esg press = 140 psi. 9/13/05 Inj 285 bbls @ 3,500 psi. 9/14/05 Inj 283 bbls @ 3,500 psi. 9/15/05 Inj 273 bbls @ 3,500 psi. 9/16/05 Inj 247 bbls @ 3,500 psi. Well dwn for 1 hr due to wtr plant issues. . . 3 9/19/05 Inj 247 bbls @ 3,500 psi. 9/20/05 Inj 208 bbls @ 3,500 psi. 9/21/05 Inj 83 bbls @ 3,500 psi. 9/22/05 Inj 125 bbls @ 3,500 psi. 9/24/05 Inj 125 bbls @ 3,500 psi. 9/25/05 Inj 132 bbls @ 3,500 psi. 9/26/05 Inj 93 bbls @ 3,500 psi. 9/27/05 Had AOGCC on loc to witness mechanical integrity test. Press up TCA to 2,220 psi. Lost 10 psi in 30 min. Passed MIT. Inj 137 bbls @ 3,500 psi. 10/6/05 Inj 121 bbls @ 3,500 psi. 10/23/05 SD inj @ 50 BWIPD. Found turbine meter was full of junk giving bad readings. Serviced meter & replaced. RWTI @ 247 BWIPD @ 3,500 psi. 10/25/05 Inj @ 205 BWPD @ 3,500 psi. 10/26/05 Inj @ 197 BWPD @ 3,500 psi. . ;[19 MGS C41-23LN WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: 50-733-20163-01 Sidetrack: 1-20-05 Original Spud: 12-17-68 Surf Csg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1 ,350 sx. Intermediate Csg: 7" 29# L80 BTC. Set @ 9,622'. Cmt'd wI 335 sk STG 1 & 392 sk STG 2. DV Tool @ 2,515'. Drilling Liner: 5" 18# L80/P11 0 STL. 1 jt P11 0 @ liner top. Set @ 12,039'. TOL @ 9,259'. TIW "LX" Liner Top Pkr. Cmt'd wI 220 sk. Production Liner: 3-%" 8.8# L80 STL Slotted. Set@ 14,410'. TOL@ 11,848'. Blank Sections: 11,848 - 12,258' 12,442 - 12,540' 12,664 - 12,730' 13,192 - 13,225' 13,378 - 13,544' 13,672 - 14,097' 14,377 - 14,410' TD: 14,410' MD (9,178' TVD) . PLF 9-7-05 KB: 35' Water Depth: 73' MSL TBG: 2-7/8" 6.5# L80 8rd EUE to 9,175' 2-3/8" 4.7# L80 8rd EUE 9,176' to 11,681' Set: 4-14-05 GLM MD TVD 1 #1 1975 1894 Dummy Valve #2 3566 3112 Dummy Valve #3 4874 4006 Dummy Valve #4 6027 4783 Dummy Valve #5 7211 5606 Dummy Valve #6 8143 6251 Dummy Valve #7 8947 6794 Dummy Valve #8 9617 7246 Dummy Valve #9 10195 7648 Dummy Valve #10 10686 7985 Dummy Valve #11 11123 8289 Dummy Valve #12 11591 8597 Dummy Valve Hanger: 2-7/8" RTS6 Box X 3-%" 8rd Pin @ Surf X-Over 3-%" 8rd Box X 2-7/8" 8rd Pin @ 2' 6' Pup Jt 2-7/8" 6.5# L80 8rd EUE @ 313' 2-7/8" X Nipple (2.313" ID) 9Cr @ 320' 4' Pup Jt 2-7/8" 6.5# L80 8rd EUE @ 321' 2-7/8" 6.5# L80 8rd EUE @ 321 - 9,175' X-over 2-7/8" 8rd Box X 2-3/8" 8rd Pin @ 9,175' 2-3/8" 4.7# L80 8rd EUE @ 9,176' -11,634' 2-3/8" X Nipple (1.875" ID) 8rd 9Cr @ 11,634' 10' Pup Jt 2-3/8" 4.7# 8rd EUE 9Cr @ 11,636' 12.5' Baker Loc (40-26) wI Seals @ 11,646' 5" Baker DB Perm Pkr (32-26) 9Cr @ 11,646'* 10' Baker SBE 13Cr @ 11,649' X-over SBE to 2-3/8" 8rd Pin 9Cr @ 11,658' 10' Pup Jt 2-3/8" 4.7# 8rd EUE 9Cr @ 11,659' 2-3/8" XN Nipple (1.791" ID) 9Cr@ 11,669' 10' Pup Jt 2-3/8" 4.7# 8rd EUE 9Cr @ 11,670' WLREG @ 11,681' *Pkr was set on DP. Tbg was 12.4' deeper than DP measure wI all depths corrected to tbg meas. Liner Across: HR, HN, HK, HI, HE & HC. Fish: GL V dropped 8-29-05 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: XTO Energy MGS 41-23LN (Platform C) 09/25/05 Barney Phillips Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. We1l1C41-23LN I Type Inj. I S TVD I 8,628' Tubing 3,500 3,500 3,500 3,500 Interval I I P.TD.1204-236 I Type test I P Test psi I 2157 Casing 2,220 2,210 2,210 P/FI P Notes: OA 145 150 150 155 Weill I Type Inj. I I TVD I Tubing Interval I P.TD.I I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type testl I Test psil Casing p/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.TD. I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubing Interval I P.TD.I I Type testl I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT MGS C41-23 9-22-05 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 7) t P.I. Supervisor '" í'l It '1./0 <; DATE: Thursday, October 06, 2005 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C41-23LN MGS C41-23LN Src: Inspector -.. FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv --.J~f2- Comm Well Name: MGS C41-23LN API Well Number 50-733-20163-01-00 Inspector Name: Jeff Jones Insp Num: miDJ050926144303 Permit Number: 204-236-0 Inspection Date: 9/26/2005 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ì C41-23LN ¡Type Inj. ! w i TVD ! 8628 ! IA 0 I 2220 2210 I 2210 , I i I P.T. I 2042360 ITypeTest I. SPT i, Test psi T ! OA T i ! I 2157 I 145 150 ! 150 155 I INITAL P Tubing! 3500 3500 3500 3500 I I Interval PIF ! I I I Notes This is an initial test on a recent producer to water injector conversion. Platform appeared very clean, orderly and in good condition. Thursday, October 06, 2005 Page I of 1 No Flow Determination at MGS C41-23LN 1 Jim, This letter for the SSSV will not be necessary as the AOGCC just granted us permission to convert the C41-23LN to water injection as per Sundry Permit # 305-163 on 7-15-05. Our plans are to commence the CTI in mid Aug. Thank, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 Denise Mohar/MID/CTOC To 07/28/2005 06:55 AM Paul Figel/MID/CTOC@CTOC cc Subject Fw: No Flow Determination at MGS C41-23LN Paul, Does he need to direct this letter to you? D. Denise Mohar Production Analyst XTO ENERGY INC. Midland, TX Tel: 432-620-4314 Fax: 432-684-9681 Forwarded by Denise Mohar/MID/CTOC on 07/28/2005 06:54 AM ----- James Regg <jim reg9@admin.s tate.ak.us> To Denise Mohar 10f2 7/28/20059:53 AM No Flow Determination at MGS C41-23LN ~ 07/26/200s4lt:48 PM <Denise MOhar@xtoe4lÞrgy.com> cc Subject No Flow Determination at MGS C41-23LN I am preparing a letter advising that XTO is approved to remove the SSSV from MGS C41-23LN based on results of a no flow test done back in May. I need the name, address, and title of individual to send the letter to. Thanks. Jim Regg AOGCC (See attached Content-Type: application/octet-stream jim_regg.vcf . Content-Encodmg: base64 20f2 7/28/20059:53 AM IT..: rÞ ~lb . (~~ J.r;:::J . n ~ :' 'þ ¡! ' ! ª \:::Vd . ~ot./~ l.~(., (~ æJ FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Figel Engineering Manager XTO Energy Inc. 200 N. Loraine, Suite 800 Midland, Texas 79701 Re: Middle Ground Shoal C41-23LN Sundry Number: 305-163 Dear Mr. Figel: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decis' t Superior Court unless rehearing has been requested. DATED this ,.s:;ay of July, 2005 Encl. . . ~O~-d-S Ço . .'1þS" - \{.o -:> MECHAN! CAL INTEGRITY REPORT· '-. =?UD DP.!:::: : \/~~-oç -- :- ; G "C"T:;-' <::::-. . '-'1'5 -0 ç ...._ rì.oI>.J...J_r..._ ~.. ff/I OPER & FIELD '(.. T 0 ~G ~ WELL NUMBER Co '-\ \- d- ~ L ~ 7f'tt,:LL DATi--. m: \~",\~.MD. <1\'\~ TVD¡ ?BTD: \l.ß'\' MD G\~~ TVD Jk Ca.s i~g : Shoe: HD TVD j DV: ~~ MD ~ ~ ·Tvu ,A e' S- C:hoe' IdC)1c; HD ~'1SL TVIì j :CP: <;~s:; HD 'lOb ç ':'7D ~~::i:~'d·l{"/;¡~/\{P2:ker· \\Io'-lt.¡.m m, Set ~t \\<n'iS' \ o/~:- 1 S~ , \\ . \....\\/v P r ~o ~J!:-'o e -,-ze \0 a.na I) erl:3 - ~ "II'! ~ \0 \"\E.~ \\.......~ \ ~ ~ ~ V1:"'~-lÞ: w;-r q INTEGRITY - ? ART f 1 :;; J ~=~ur. - --~~ ~. ~ Š' '\ Annulu.s Press Test::;:P IS min ; 30 min ~ ~ rfc'- COlliülents' c..c.~\.....\\\"".~ '<Ð \$t)C\>';, ~'<- ~ ~\ ~ J:¡"";IJ~ .,- 1. ~1 . ): ~ r . -.y ....,;..j~.j } ~ :<:ECHÞ_"1I ca INTEGRITY - PART 12 \. '-I \ \,b \ ~ ~ ,(.. Cem.ent: Volumes :.. þ...mt. Liner ~OO~'t ; Csg ¡ DV ~ ~ ¡o; . t! 'Î Cwt -"01 to cove:!:" perfs "l ~~\... ð-\.t.€.""'-f"-.>r <E:..ü..Ç..Ç'\'-\E.~~~ r gOO' ~ ff1 r\ <>(è. ~'o~ \ \~·S~~ 7.iS(ð 'I.. S It ;' ~ ~ -z¡. Theare tical TOC ~~\t",\- tr_,,- ~ ~.....~€ê) -\0 ~ ...\m \'t~ 3J'7o'l.$ ~ J' ~ ~ 'no...... (S-~",- \ 0...... \. \"'~, \c ". Lt~... ~,,>\fc) o\¿. ~ -; Cement Bond Log (Ye. or No) '{~ S. ; In AOGCC File <t\"'\v,,,~ \\ ~ ~ CBL :i::valuation, ::one ê.DOVe perfs ~~~'tK~~~f\.-\-~~f\...\-\·~'~W ~(Þ 11 ., \ \<O~Qt'? ~:q~( 5~aè. Produc.tion Log: Tn:>e Evaluation CONCLUSIONS: ?art 11: \-\ ~ '\ ~ " ~'tCú ~;)- '. j.D~~t -oS 14V. . It.{ ?ar~ :Z: . . ;[tR XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) June 29, 2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval: Well C41-23LN Dear Mr. Norman, XTO Energy, Inc. hereby submits its Application for Sundry Approval (Form 10-403) for well C41-23LN on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. The well was drilled completed in April 2005 in the Hemlock with a reverse penetration in the HR, HN, HK, HI, HE & HC zones. Although the well was initially completed as a producer, the long term objective for the wellbore is to provide injection support to West Flank wells: A34-11LS2, A34-14LW, A31-14LW, A22-14LS & A43-11LW. Prior to drilling the well, it was anticipated that the production be greater than the actual ±100 BOPD, thereby, expecting to produce the well for quite some time prior to converting to water injection. But the latest well test @ 84 BOPD and knowing 5 producers could benefit from water injection pressure support; XTO is requesting the AOGCC's approval to convert the well. The completion was set with this in mind by installing a chrome packer & SS tbg hanger. As shown in the attached Completion Procedure, the 12 GL V's will be replaced with dummy valves & a MIT test will be performed. Please find attached the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Completion Procedure 3. Present Wellbore Schematic 4. Production Plot If you have any questions or require additional information, please contact me at (432) 620-6743. 7C:/> ~ Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith ORIGI~~/~L bTS 11/8/.S . STATE OF ALASKA %' Al,L\ all AND GAS CONSERVATION COMMA:>N CIlt 1 "l ~ "os ~ , APPLICATION FOR SUNDRY APPR~AL ,"",\ 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: 1. Type of Request: Suspend Repair well D Pull Tubing D Waiver ('1::;->1 Stimulate D TimeJUlmsMn 1 Re-er~.er 9US~[1~c .\^{~I~'bl> .. .;.~-,-, ',"-M ,,-,.- "." .:, :)/.'.... ': ',)-';:0': '.,'," 5. Permit toJ;>(i)l.N.umÞer: Abandon Alter casing D Change approved program 0 2. Operator Name: XTO Energy Inc. 3. Address: o D Exploratory D D Development Stratigraphic Service 204-236 6. API Number: 50-733-20163-01 200 N. Loraine, Suite 800, Midland, Texas 79701 7. KB Elevation (ft): 9. Well Name and Number: 35' C41-23LN 8. Property Designation: 10. Field/Pools(s): ADL 18756 Middle Ground Shoal 11. Total Depth MD (ft): 14,410' Casing Structural Conductor Surface Intermediate 1 Intermediate 2 Liner PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14,377' 9,177' Total Depth TVD (ft): 9,177' Length Plugs (measured): N/A Size MD TVD Burst 1653' 10-3/4" 1653' 1584' 9622' 7" 9622' 7249' 2780' 5" 12,039' 8751' 2562' 3-1/2" 14,410' 9178' Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 8765' - 9177' 2-7/8" & 2-3/8" L80 3130 psi 8160 psi 10140 psi Slotted Perforation Depth MD (ft): 12,258' - 14,377' Packers and SSSV Type: Baker 5" DB Perm Pkr, No SSSV 11 ,646' 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch D 14. Estimated Date for ./ 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D Plugged D WAG D GINJ D WINJ 0 Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Figel Printed Name Paul Figel Title Engineering Manager 7/21/2005 Date: Signature Date Phone 432-620-6743 COMMISSION USE ONLY Junk (measured): N/A Collapse 1580 psi 7020 psi 10490 psi Slotted Tubing MD (ft): 11,681' Service 0 Abandoned WDSPL D D 6/29/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 ó -- / ~ .3 Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: ~ tNrc.~G""\Cú..\ \,,~,,\¡ \t;-~-\ c-\. T~ \~ ""~~\ \;)41.: c::o~~'ð \>,\t)t' ~~~~....~ "-.:) « \. \ '\ ...... r~ \ C-Q:.. . RBDMS BFL JUL 1 9 2005 APPROVED BY THE COMMISSION COMMISSIONER Date: Form 10-403 Revised 11/2004../ o R \ G \ N A L Submit in Duplicate ;[19 . . XTO ENERGY INC. MGS C41-23LN ..... WEST FLANK, COOK INLET, ALASKA CONVERT WELL TO WATER INJECTOR PROCEDURE WELL DATA: SURFACE CASING: 10-3/4" 40.5# J55 BTC. Set @ 1,653'. Cmt wi 1,350 sk. INTERMEDIATE CSG: 7" 29# L80 BTC. Set @ 9,622'. DV Tool @ 2,515'. Cmt wi 335 sk STG 1 & 392 sk STG 2. DRILLING LINER: 5" 18# L801P110 STL. Set @ 12,039'. TOL @ 9,259'. Cmt wi 220 sk. PRODUCTION LINER: 3-112" 8.8# L80 Hydril513 Slotted. Set @ 14,410'. TOL @ 11,848'. TUBING: 2-7/8" 6.5# L80 8rd EVE: Surface to 9,175'. 2-3/8" 4.7# L80 8rd EVE: 9,175' -11,681'. PACKER: 5" Baker DB Permanent Packer 9 Chrome @ 11,646'. OPEN HOLE: 6" from 12,039 - 14,410'MD. DEPTH @ 60 DEGREES: 11,698' MD (8,657' TVD) BHP: 3,200 psi BHST: 165 Deg F CURRENT PRODUCTION: 84 BOPD, nil water & 49 MCF. OBJECTIVE: Convert well to water injection. NOTE: Packer fluid to consist of 10 gal/l00 bbl EC6065A Oxygen Scavenger & 15 gal/l00 bbl99VD049 Corrosion Inhibitor supplied by N alco. AFE # : 402251 Procedure 6-29-05 bl J \ I-.. . . 2 XTO Energy Inc. MGS C41-23LN COOK INLET, ALASKA PROCEDURE: 1. SD gas lift. MIRU Slickline. Press test lubricator. RIH & pull GLV's#,¥lí2@ ìÍrèfcll1bwîri.g depths: GLM MD #1 1975 #2 3566 #3 4874 #4 6027 #5 7211 #6 8143 #7 8947 #8 9617 #9 10195 #10 10686 #11 11123 #12 11591 NOTE: GLM's 8-12 are 2-3/8". 2. RIH wi setting tool & set dummy valves in GLM's #1-11. 3. RU treating line from mud pump to wellhead tbg annulus. Press test line to 1,000 psi. 4. Pump 450 bb1 FIW down the tbg annulus through the pocket on GLM #12 @ 3-4 BPM. Take returns into the production header. SD. Monitor well. Make sure all gas has been circ out. Annular capacity = 299 bbl Tbg capacity = 62.5 bbl 5. Prepare 350 bb1 (inc1 bottoms) packer fluid (350 bb1 FIW + 35 gal EC6065A Oxygen Scavenger + 53 gal 99VD049 Corrosion Inhibitor). Pump ±320 bb1s pkr fluid down the tbg annulus. 6. Notify the AOGCC 24 hrs prior to perfonning MIT test. 7. RIH wi setting tool & dummy valve. Set valve in GLM #12. POOH. 8. RIH & set SV in 2-3/8" XN nipple (1.791" ID) @ 11,669'. POOH. SI swab valve. 9. Press test tbg to 3,600 psi w/FIW. Monitor press for 30 min. B1eed-offpress. RIH & pull SV. 10. RU pump on tbg annulus. Perfonn MIT on TCA wi 2,200 psi for 30 min. (5' shoe @ 12,039' MD (8,751' TVD) : 8,751' x 0.25 psilft = 2,188 psi) 11. RD pump & WL. Pump well on inj on the 3,500 psi system. Procedure 6-29-05 p,L . XTO Energy Inc. MGS C41-23LN COOK INLET, ALASKA 2. ('.. .. ;JoI.~ Paul Figel Engineering Manager Kyle Hammond VP Operations Procedure . 6-29-05 3 L . ¡[rag MGS C41-23LN Cook Inlet, Alaska Leg 4, Conductor 2S API No.: 50-733-20163-01 Sidetrack: 1-20-05 Original Spud: 12-17-6S Surf Csg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd wI 1,350 sx. Intermediate Csg: 7" 29# LSO BTC. Set @ 9,622'. Cmt'd wI 335 sk STG 1 & 392 sk STG 2. DV Tool @ 2,515'. Drilling Liner: 5" 1S# LSO/P110 STL. 1 jt P11 0 @ liner top. Set @ 12,039'. TaL @ 9,259'. TIW "LX" Liner Top Pkr. Cmt'd wI 220 sk. Production Liner: 3-W' S.S# LSO STL Slotted. Set@ 14,410'. TOL@ 11,S4S'. Blank Sections: 11 ,S4S - 12,25S' 12,442 - 12,540' 12,664 - 12,730' 13,192 - 13,225' 13,37S - 13,544' 13,672 - 14,097' 14,377 - 14,410' TD: 14,410' MD (9,17S' TVD) . 'PC~4-26-05 KB;} i$' Water Depth: 73'MSL TBG: 2-7/S" 6.5# LSO Srd EUE to 9,175' 2-3/S" 4.7# LSO Srd EUE 9,176' to 11 ,6S1' Set: 4-14-05 GLM #1 ff2 #3 #4 #5 #6 #7 #8 #B #10 #11 #12 TVD 1894 3112 4006 4783 5606 6251 6794 7246 7648 7985 8289 8597 PORT 10 10 10 12 12 12 16 16 16 16 16 24 PSO 958 937 923 923 906 892 894 879 864 851 835 PSC 920 910 900 890 880 870 860 850 840 830 820 ORIFICE MD 1975 3566 4874 6027 7211 8143 8947 9617 10195 10686 11123 11591 Hanger: 2-7/S" RTS6 Box X 3-W' Srd Pin @ Surf X-Over 3-%" Srd Box X 2-7/S" Srd Pin @ 2' 6' Pup Jt 2-7/S" 6.5# LSO Srd EUE @ 313' 2-7/S" X Nipple (2.313"ID) 9Cr@ 320' 4' Pup Jt 2-7/S" 6.5# LSO Srd EUE @ 321' 2-7/S" 6.5# LSO Srd EUE @ 321 - 9,175' X-over 2-7/S" Srd Box X 2-3/S" Srd Pin @ 9,175' 2-3/S" 4.7# LSO Srd EUE @ 9,176' -11,634' 2-3/S" X Nipple (1.S75" ID) Srd 9Cr @ 11,634' 10' Pup Jt 2-3/S" 4.7# Srd EUE 9Cr @ 11,636' 12.5' Baker Loc (40-26) wI Seals @ 11,646' 5" Baker DB Perm Pkr (32-26) 9Cr @ 11,646'* 10' Baker SBE 13Cr @ 11,649' X-over SBE to 2-3/S" Srd Pin 9Cr @ 11 ,6SS' 10' Pup Jt 2-3/S" 4.7# Srd EUE 9Cr @ 11,659' 2-3/S" XN Nipple (1.791" ID) 9Cr @ 11,669' 10' Pup Jt 2-3/S" 4.7# Srd EUE 9Cr @ 11,670' WLREG @ 11,6S1' *Pkr was set on DP. Tbg was 12.4' deeper than DP measure wI all depths corrected to tbg meas. Liner Across: HR, HN, HK, HI, HE & HC. New Drill 150 C I.L 1 00 U 1:åE 10:: o C I a.. 50 œ o , , , t if , , * - XT Energy Inc. S 41-23LN iI""'''''''' "'.." , , , , , , , , , , , , -~ - ^^" "~- I , , , , '" . "" "" ~ 6/15/05 4t · - MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. 'KMC1 7/U/I)l? P. I. Supervisor { { DATE: May 20,2005 FROM: John Crisp, Petroleum Inspector SUBJECT: No Flow Test XTO Platform C Well C41-23LN PTD 204-236 Mav 20, 2005: I traveled to XTO Oil Company C Platform to witness SVS tests & to witness MIT on C23-23 & to witness no-flow test on C41-23LN. I arrived on the platform & began monitoring tubing pressure on C41-23LN @ 0800 hrs. Tubing pressure was o. I requested a bubble test from the tubing to a 5 gal. Pail of water using a % inch hose that is in direct communication to the tubing. No gas was witnessed from the bubble test on C41-23LN @ 0830 hrs. The use of a gas meter was discussed; I did not feel there would be enough pressure to register on the meter. We installed a very large 100-psi gauge in the tubing & shut the well in to monitor pressure build up during our other tests. Pressure on C41-23LN @ 0930 was O. Bubble test negative. Pressure on C41-23LN @ 1030 was O. Bubble test negative. Pressure on C41-23LN after 3 hour shut in @ 1330 hrs. was 1 psi. Bubble test showed slight gas release that lasted approximately 3 minutes. Four inches of water would effectively stop the gas release. Summary: I witnessed a no-flow test on XTO C41-23LN. The Operator was made aware my Supervisor would make a No-Flow Determination. Attachments: None Non-Confidential 2005-0520_ No-Flow _MGS _ C41-23LN ..Jc.doc . . . ;[t9 RECEIVED MAY 0 4 2005 XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) Alaska Oil & Gas Cons. Commìssion Anchorage May 2, 2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Well C41-23LN Dear Mr. Norman, XTO Energy, Inc. hereby submits its Well Completion Report (Form 10-407) for the sidetrack drilled .I for the C41-23LN on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. The well was completed in the Hemlock with a reverse penetration in the HR, HN, HK, HI, HE & HC zones. A 3-1/2" slotted liner was set across the Hemlock and being produced with gas lift. Please find attached the following information for your files: 1. Form 10-407 Well Completion 2. Daily Drilling Reports 3. Present Wellbore Schematic 4. Well Surveys 5. LWD Logs: GR & Resistivity (CD format)* 6. CBL Logs: 5" & 7" Intermediate (CD format) *Baker Inteq did not have the CD of the logs available at this time & was told it will take 2-3 weeks. In lieu of delaying the Completion Report, I will mail the disc separately after I receive it. If you have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, 0,...p ~ ç~ Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith i\L , . STATE OF ALASKA RECE.·· I\/ED ALASKA AND GAS CONSERVATION COMMIS. m'" ... . WELL COMPLETION OR RECOMPLETION REPORT AND I10G) 4 Z005 1a. Well Status: Oil0 GasD Plugged D Abandoned D Suspended D WAGD 1 b. Well Class: ,C 20AAC 25.105 20AAC25.110 Development iliska Oil ,~~{6~ (II GINJD WINJD WDSPL 0 No. of Completions 1 Other Service 0 Stratigr~ehQy~ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: XTO Energy Inc. Aband.: 4-14-05 ./ 204-236 3. Address: 6. Date Spudded: S 13. API Number: 200 N. Loraine, Ste 800, Midland, Texas 79701 ~/.:a.Î'O(' ~ 50-733-20163-01 4a. Location of Well (Governmental Section): Pl a tform C. Leg 4 7. Date TO Reached: ,.t- 14. Well Name and Number: Surface: / Cond 28, 504' FSL, 1532' FEL, Sec 23, T8N, R13W S.M. 4-7-05 I C41-23LN Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 2326'FNL, 2484'FEL, Sec 14, T8N,R13W,S.M. 105 Total Depth: 9. Plug Back Depth(MD+ TVD): MGS 259' FNL, 2588' FWL, Sec 14, T8N, R13W, S.M. 14,377' + 9177' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 231423 ./ y- 2474190 .. Zone- Ak4 (" 14,410' + 9177' ./ ADL-18756 TPI: x- 230647 y- 2481939 Zone- HR 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 230488 y- 2484009 Zone- HC NA NA 18. Directional Survey: Yes ~ No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost: 73 feet MSL NA 21. Logs Run: LWD: Gamma Ray & Resistivity. CBL on 5" drilling liner & 7" intermediate þ(ic.K -ff r.:1Ittt 1;770£""1> I~ ,-91'""'TJI'Þ 22. CASING, LINER AND CEMENTING RECORD 40 Ç.'&.~ CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 10-3/4" 40.5 J55 Surf 1653' Surf 1584' 15" 1350 sxs 0 7" 29 L80 Surf 9622' Surf 7249' 8-1/2" 727 sxs 0 5" 18 L80 9259' 12039' 7005' 8751' 6" 220 sxs 0 3-1/2" 8.8 L80 11848' 14410' 8716' 9178' 4-1/8" NA-slotted csg 0 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) Slotted liner: 12,258-12,442', 12,540-12,664', 12,730-13,192', 13,225- 2-7/8" 9175' 13,378',13,554-13,672', 14,097-14,377' 2-3/8" 9175-11,681' 11,646' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1960-1665' 220 sxs cement KOP 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 4-16-05 I gas lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I~as-Oil Ratio: 4/25/05 12 Test Period .... 55.5 20.5 NIL 2:: 730 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 75 830 24-Hour Rat€ ~ 111 81 NIL 28.5 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None rêöMPIËrTô1fl RBDMS BFL MAY 1 3 2005 i:l1 I I [,r 1 ì-.. mmission Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. GEOLOGIC MARKE NAME TVD Top Hemlock HR 12515' 8792' Top Hemlock HN 12893' 8852' Top Hemlock HK 13215' 8932' Top Hemlock HI 1337Ó' ,8966' "'~, " Top Hemlock HE 13650' 9038' Top Hemlock HC 14410' 9178' 29. FORMATION TESTS Include and briefly s arize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NONE 30. List of Attachments: Daily Drifiing ReÞorts,Wellbórè ScbefTÍatic; Well Survey, CD's w/GR, Resistivity & CBL 31. I herebyé:ertify t at thefòregoing is true and correct to the best of my knowledge. ...'f ' Contact: Paul Figel Printed Name: Paul Fiael Signature: Title: Engineer Manager Phone: 432-620-6743 Date: 5/3/05 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 à: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ... Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken,·índii::áte "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 . . 1 XTO Energy Inc. C41-23LN Daily Well Report Objective: Drill &: Complete --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 1/20/05 ND BOP's. MU 6" bit & TIH. Dressed off cmt plug @ 2,000'. TOOH. MU 7" csg cutter & TIH. Cut 7" csg @ 1,950'. TOOH. Redressed cutter. TIH & cut 7" csg @ 45'. ND BOP's. Prep to pull 7" csg. =================================================== =================================================== 1/21/05 PU 7" Spear Assembly. NU BOP w/7" pipe rams & tstd, OK. PU 7" spear assembly to fish csg. Prep to pull 7" csg. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 1/22/05 Jarring On Fish. Speared into 7" csg & attempted to jar free, unsuccesful. RIH & cut csg @ 503'. Speared fish & recovered 11 jts (458'). RIH wi cutter & cut csg @ 925'. Speared fish & recovered 10 jts (422'). RIH wi cutter & cut csg @ 925'. Speared fish & recovered 13 jts (548'). Speared fish & jarring @ report time. Prep to fish 7" csg. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 1/23/05 Testing BOP's. Jarred on fish, no movement. ReI spear & TOOH. RIH w/cutter & cut csg @ 1,950', 1,790' & 1,630'. Speared csg @ 1,473' & POOH. Recovered 3.5 jts (157'). Speared fish @ 1,630' & jarred, no movement. ReI spear & TOOH. PU 7.875" milling assembly & TIH to TOF @ 1,630'. Milled csg to 1,643'. Circ btms up & TOOH. Chg'd pipe rams & tstd BOP's. Prep to mill csg. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 1/24/05 Milling 7" Csg. Fin tstg BOP's & gas alarms. PU 7.875" milling assembly & TIH to TOF @ 1,643'. Milled 7" csg 1,643'-1,823'. Prep to mill csg. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 1/25/05 Circ Hole Clean. Milled 7" csg 1,823'-1,945'. RIH & speared fish @ 1,945'. TOOH, no recovery. MU & RIH w/6" clean out assembly. Circ iron cuttings out. Prep to fish csg. =================================================== =================================================== 1/26/05 Drilling Cmt. TOOH. LD 6" clean out assembly. TIHw/8.5" clean out assembly. Circ hole clean. TIH w/muleshoe to 1,960'. Pmpd 220sx CI "G" (15.8 ppg, 1.16 yield). TOOH. PU 8-1/2" bit & clean out assembly & TIH. Tagged cmt @ 1,665'. Dressed cmt 1,665'-1,740'. Prep to dress cmt. =================================================== =================================================== 1/27/05 Building New 9.5 PPG Mud. Dressed off cmt to 1,770'. Circ hole clean. Cleaned pits & built 9.5 ppg mud. Prep to displace hole w/new 9.5 ppg mud. =================================================== =================================================== 1/28/05 Drlg @ 2,660' (890' 124 hrs). Displace hole w/new 9.5 ppg mud. TOOH, I MU kick off assembly & TIH. Oriented, slide & rot fr 1,770'-2,660' (2,446' TVD). Drlg ahead. =================================================== =================================================== 1/29/05 Drlg @ 3,839' (1,179'/24 hrs). Slide & rot fr 2,660'-3,829' (3,301' 1/30/05 1/31/05 2/1/05 2/2/05 2/3/05 2/4/05 2/5/05 2/6/05 217/05 2/8/05 2/9/05 2/10/05 2/11/05 2/12/05 2/13/05 . . 2 TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 4,847' (1,008'/24 hrs). Slide & rot fr 3,829'-4,847' (3,989' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 5,637' (790'/24 hrs). Slide & rot fr 4,847'-5,637'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 6,263' (626' /24 hrs). Slide & rot fr 5,637'-6,263' (4,949' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 6,456' (193'/24 hrs). Rot fr 6,263'-6,376'. TOOH, chg'd bit & mtr. TIH. Slide & rot 6,376'-6,456' (5,085' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 7,240' (784'/24 hrs). Slide & rot fr 6,456'-7,240' (5,626' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 7,630' (390'/24 hrs). Slide & rot fr 7,240'-7,436'. Circ btms up. Short trip to 6,300'. Slide & rot fr 7,436'-7,630'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 7,864' (234' /24 hrs). Slide & rot fr 7,630' -7,864'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 7,994' (130'/24 hrs). Slide & rot fr 7,864'-7,994'. Circ btms up. TOH for bit. Tstd BOP's 250/5,000 psi, OK. PU bit #4, BHA & TIH. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 8,456' (462'/24 hrs). TIH & washed to btm. Slide & rot fr/7,994'-8,456'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 8,894' (438' /24 hrs). Slide & rot fr/8,456'-8,684'. Short trip to 7,740'. Slide & rot fr/8,684'-8,894'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Chg'd out bit @ 9,204' (310'/24 hrs). Slide & rot fr/8,894'-9,204'. Pmp sweep & TOH for bit. TIH w/bit #5. --------------------------------------------------- --------------------------------------------------- -- --- ------ - - - - - - -- ------- ---- - -- -- - - - - - - - - -- --- - - - - - - - - - - - - -- - - - -- ----------- - - --- - - - ------- - - - - - -- -- Drlg @ 9,464' (260'/24 hrs). PU new bit & BHA & TIH. Slide & rot 9,204'-6,464'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 9,630' (166'/24 hrs). Slide & rot 9,464'-6,630'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- TOOH To Run 7" Csg @ 9,634' (4'/24 hrs). Rot 9,630'-6,634'. Circ btms up. TOOH, PU clean out assy & TIH. Pmpd sweeps. C & C hole. TOOH to run 7" csg. Prep to run 7" csg. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Running 7" Csg @ 9,634' (0'/24 hrs). Fin TOOH. Installed 7" pipe rams & tstd. RU & ran 7", 29#, L-80, BTC csg. Prep to cmt 7" csg. . . 3 2/14/05 Prep To Set 7" Csg Slips @ 9,634' (0' /24 hrs). Fin running 228 jts 7", 29#, L-80, BTC csg. Cmt'd 1st stage w/55 bbls lead followed by 33 bbls tail. Cmt'd 2nd stage w/93 bbls lead followed by 16.5 bbls tail. Bumped plug, did not circ cmt to surface. ND BOP's & prep to set slips. Prep to set 7" csg slips. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/15/05 Tstg BOP's @ 9,634' (0' /24 hrs). Set csg slips, cut off csg. ND BOP's & pulled riser. NU WH & tst packed off 500-2,500 psi, OK. NU riser & BOP & tstd 250-5,000 psi, OK. Prep to TIH. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/16/05 Tstg w/6" Bit & BHA @ 9,634' (0' /24 hrs). Tstd 10-3/4" x 7" annulus to 500 psi. Bled dwn to 350 psi (9.7 EMW, 13.77 ppg). MU 6" clean out assembly. TIH & drld DV tool & cmt. Prep to clean out 7" csg. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/17/05 MU 6" Bit, Mtr & BHA @ 9,651' (17' /24 hrs). Drld landing collar & cleaned out to 9,563'. Tstd csg to 1,500 psi, tstd OK. Drld cmt & float equip & new fmt to 9,651'. Performed FIT tst (14.2 ppg), OK. TOOH & MU 6" bit, mtr & BHA. Prep to TIH. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/18/05 TOOH To Chg BHA @ 9,774' (123' /24 hrs). TIH w/Bit #7. Rot & slide fr 9,651'-9,766'. Losing 25-30 BPH. Pmpd & sqzd LCM pills. Rot fr 9,766'-9,774'. MWD & LWD jamming. Spotted LCM pill on btm & TOOH. Prep to TIH w/new BHA. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/19/05 Drlg @ 9,920' (146' /24 hrs). TOOH, stood back collars & LD BHA. MU rotating assembly & TIH, reamed to btm. Rot 9,774'-9,920' (7,451' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/20/05 Drlg @ 9,965' (45'/24 hrs). Rot 9,920'-9,933'. TOOH, chg'd BHA & TIH. Washed & reamed to btm. Slide 9,933'-9,965' (7,485' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/21/05 Drop Ball To Close Circ Sub @ 10,057' (92' /24 hrs). Slide & Rot 9,965'-10,057'. Loosing approx 150 BPH. Pmpd & sqzd LCM pills. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/22/05 Drlg @ 10,417' (360'/24 hrs). Slide & Rot 10,057'-10,417' (7,800' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/23/05 TIH @ 10,425' (8'/24 hrs). Rot fr 10,417'-10,425' (7,805' TVD). Pmpd 2 LCM pills & sqzd. TIH (string plugged), TOOH, stood back BHA. PU new mtr & MWD & TIH. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/24/05 Drlg @ 10,824' (399' /24 hrs). Washed & reamed fr 10,005' -10,425' . Slide & Rot fr 10,425'-10,686'. Raised MW to 12.2 ppg. Rot to 10,784' & raised MW to 12.5 ppg. Rot fr 10,784'-10,824' (8,080' TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/25/05 Drlg @ 10,921' (97' /24 hrs). Rot fr 10,824' -10,853'. Well flwg, raised MW to 12.7 ppg. Rot to 10,687' (losing fluid). Mixed & pmpd 50 bbls LCM. Reamed to btm & rot 10,867'-10,921' (8,150' TVD). Drlg ahead. 2/26/05 . . 4 --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Tstd MWD @ 11,018' (97'/24 hrs). Rot fr 10,921'-11,011'. Circ btms up. Slide drld 11,011'-11,018'. Pmpd 50 bbl LCM pill & sqzd in 21 bbls. Closed circ sub & tstd MWD. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/27/05 Circ & Raised MW to 13.0 PPG @ 11,018' (0' /24 hrs). Tstd MWD. Monitored well (MW cur to 11.7 ppg). Circ & raised MW to 12.7 ppg. Spotted 20 bbls 14.2 ppg mud on btm. SWI & monitored well, well flwg 10 bph. Circ & raised MW to 13.0 ppg. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 2/28/05 Circ &14.1 PPG Mud @ 11,018' (0'/24 hrs). Circ & raised MW to 13.2 ppg (began losing mud). Attempted to open circ sub, no good. Hooked up tst pmp & opened circ sub w/5,200 psig. Monitored well (480 psi). Circ 14.2 ppg mud. Lost rtns (well static). Pmpd 30 bbls (75#/bbl) LCM pill & chased w/112 bbls 14.1 ppg mud w/partial rtns. Monitored well, well flwg. TIH & circ 14.1 ppg mud w/partial rtns. Drlg ahead. 3/1/05 3/2/05 3/3/05 3/4/05 3/5/05 3/6/05 --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- TOOH @ 11,018' (0'/24 hrs). Circ & raised MW to 14.2 ppg. Well flwg 2 bph. Weight up to 14.4 ppg, lost rtns. Build LCM pills. Pmpd 40 bbls LCM (60#/bbl) & spotted 20 bbls 16 ppg mud. TOOH. Prep to chg BHA & TIH. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- TIH To Pmp Form-A-Set pill @ 11,018' (0'/24 hrs). Fin TOOH, LD BHA. Tstd BOP's 250-5,000 psi, tstd OK (witnessed by L. Grimaldi w/AOGCC). MU mules hoe, TIH to spot Form-A-Set pill. Prep to spot pill & TOOH. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Monitor Sqeeze Pressure @ 11,018' (0'/24 hrs). TIH & spotted Form- A-Set pill @ 10,978'. Sqzd 10 bbls @ 1 BPM, 240 psi. Pmpd additional 20 bbls & maintained 20 psi. Monitored drop to 140 psi in 3 hrs. Opened well & circ, monitored losses @ 40 BPM. Mixed 2nd pill & pmpd 59 bbls Form-A-Set pill. Sqzd in 30 bbls & monitored press. Prep to monitor losses. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- POOH w/Muleshoe @ 11,018' (0'/24 hrs). Sqzd Form-A-Set pill & monitored well. C & C mud to 14.5 ppg in & 14.4 ppg out wino losses. Pmpd 50 bbls (17 ppg) balanced plug & TOOH. Prep to TIH w/bit. - -- - ------- - - - - - - - - - ------- - - - - - - - - ------------- --- - -- - - -- - - - - - - - -- - - - ------ - - -- -- - - - - - - -- -------- - - -- --------------------------------------------------- --------------------------------------------------- TIH to CO @ 11,018' (0'/24 hrs). TOH, LD shoe. PU 7" RTTS & TIH. Set @ 2,647'. Tstd 4" DP x 7" csg to 1,500 psi, OK. TIH w/RTTS to 9,568' & set. Tstd 4" DP x 7" csg to 1,500 psi, OK. TOH & LD RTTS. PU bit & TIH to shoe. Circ, conditioned mud & prep to CO. CO OH. --------------------------------------------------- --------------------------------------------------- -- - - --- - ------- -- - -- --- - - - -- - - - -- ------- - --- - - - ---- - - - - - -- - - - - -- --- - ------ - - - - -- - - - - -- -- - - -------- - - -- Circ & conditioned hole @ 11,018' (0'/24 hrs). Conditioned mud to 14.5 ppg. Washed & reamed to 10,045', lost returns. Pulled to 8,632' & est circ, built volume, circ btms up. RIH to 9,574' & circ btms up. Washed & reamed to 10,200' & pmpd 50 bbls LCM at loss zone (9,766'-10,030'). Attempted to circ BU (severe losses). TOH to shoe & circ btms up w/some losses. Est circ on btm. 3/7/05 3/8/05 3/9/05 . . 5 Prep to TOH for Drlg assembly @ 11,018' (0'/24 hrs). TOH, stood back & CO assembly. MU muleshoe & TIH to 10,203', circ btms up (losing 10 bph). RU BJ Services & pmpd 150sx CI "G" cmt. TOH 15 stands, closed pipe rams & sqz'd @ 1,300 psi max. Dropped wiper plug & circ btms up. Prep to TOH. TOH & MU drlg assembly. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Washed & reamed to btm @ 11,018' (0'/24 hrs). TOH, MU bit & BHA & TIH. Drld cmt stringers fr/8,992'-9,622'. CO cmt in OH to 10,200'. Washed & reamed to 10,300' (no losses, 80 units gas). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Circ & conditioned @ 11,018' (0'/24 hrs). Washed & reamed fr/10,300'-10,416' (pipe stuck). Worked stuck pipe, opened diverter valve & pmpd 50 bbls FW (pipe came free). TOH to shoe & circ btms up. Circ & conditioned mud to TOH. TOH. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/10/05 Washed & reamed @ 10,620' (0' /24 hrs). Circ & conditioned mud to 13.8 ppg. Spotted 50 bbls (17 ppg) pill. TOH, LD directional assembly, MU rotary assembly & TIH. Washed & reamed fr/9,900'- 10,620' (lost 50 bbls @ 10,425'). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/11/05 TIH w/directional assembly @ 11,025' (7' /24 hrs). Washed, reamed & drld new form fr/11,018'-11,025'. Circ btms up, spotted 17 ppg pill & TOH. MU directional assembly & TIH. Drlg ahead. 3/12/05 --------------------------------------------------- --------------------------------------------------- ---- ----------------------- - - - - - - - -- -- --- - -- - - - - - - - -- - -- - - - - - - -- -- - - - ----- --- - - - - - - - - - --- - - - - - - ---- --- Sliding @ 11,069' (44'/24 hrs). TIH, slide & rot fr 11,025'- 11,069'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/13/05 Building Mud Volume @ 11,141' (72' /24 hrs). Slide & rot fr 11,069'- 11,137' (losing 50-80 BPH). Pmpd 50 bbls LCM pill. Rot 11,137'- 11,141' (lost rtns). Pmpd 50 bbls LCM pill. Build mud volume (hole taking 7 BPH). Drlg ahead. --------------------------------------------------- --------------------------------------------------- - - - - - - - - - - - - --- - - -- -- -- - - - - - -------- ------ -------- - - - - - - - - - - - - -- ---- - - ----- - - - - - - - ---------- - - - ------- 3/14/05 Drlg @ 11,264' (123' /24 hrs). Monitor well, no losses. TIH, washed to btm & slide & rot fr 11,141'-11,264'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/15/05 Drlg @ 11,578' (314' /24 hrs). Slide & rot fr 11,264'-11,578'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- ----- - - - - - - - - - - - - - - - - - - - - - - -- - ------ -- ---- - - - - - - - - - --- - - - - - - - - - - - - - - - - ---------- - ------ --------------- 3/16/05 MU New Bit & BHA @ 11,600' (22' /24 hrs). Slide & rot fr 11,578'- 11,600'. TOOH (spotted 3 heavy pills). LD BHA & tstd BOP's 250- 5,000 psi, tstd OK. Jim Regg w/AOGCC waived witnessing test. MU new bit, motor & jars. Prep to TIH. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/1.7/05 Drlg @ 11,746' (146' /24 hrs). TIH w/new bit & BHA. Washed & reamed to btm. Slide & rot fr 11,600'-11,746'. Drlg ahead. 3/18/05 --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Circ Btms Up @ 11,972' (226'/24 hrs). Slide & rot fr 11,746'- 11,972' (8,745' TVD). Circ btms & prep to TOOH. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/19/05 Drlg @ 11,999' (27' /24 hrs). Circ & spotted pill. TOOH for bit. MU new bit & BHA & TIH. Reamed to btm & rot fr 11,972'-11,999' (8,745' . . 6 TVD). Drlg ahead. =================================================== =================================================== 3/20/05 PU 5" Csg @ 12/1041 (105//24 hrs). Rot fr 11/999/-12/1041 (8/7451 TVD). Circ btms up I spotted pill & TOOH to run csg. PU 5" 18# csg Prep to run 5" csg. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/21/05 Cmt 5" Liner @ 12/1041 (01/24 hrs). Ran 62 jts 5"1 18#1 L-80 & 3 jts 5" 18#1 P-110 csg. RIH w/liner to 12/03911 could not work deeper. Set liner hanger w/1/800 psi & reI fr hanger. Tstd lines to 3/500 psil tstd OK. Pmpd 30 bbls MCS-4D spacer @ 13 ppg. Prep to cmt liner. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/22/05 Cleaning pits @ 12/1041 (01/24 hrs). Cmt/d liner w/200sx CI "G"I did not bump plug. Set liner top pkr & pulled 301 above liner. Circ & TOOH. LD setting tool. MU 6" bit & scraper & TIH. Tagged liner top @ 9/2591. Circ btms up & TOOH to 3/3101. Unable to LD DP due to high winds. Cleaned mud pits. Prep to clean out liner. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/23/05 Displaced Mud w/FW @ 12/1041 (01/24 hrs). TOOHI LD DP. TIH w/4-1/8" bit & 2-7/8" DP. W & R cmt stringers 1116001 to landing collar @ 11/9451. Circ hole clean. Tstd csg to 1/500 psi for 30 minsl tstd OK. Prep to displace mud w/FW & TOOH w/clean out assembly. =================================================== =================================================== 3/24/05 Prep to chg to OBM @ 12/1041 (01/24 hrs). Disp hole w/FW. Prep for oil-base mud. Disp w/OBM. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/25/05 RU to run bond log @ 12/1041 (01/24 hrs). Prep to chg to OBM. Pmpd 20 bbls weighted spacer. Displaced FW w/9.0 ppg OBM & TOH. NU lubricator & RU Schlumberger to run bond log. Ran bond log. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/26/05 TIH w/4-1/8" bit @ 12/1041 (01/24 hrs). Ran bond log. RD Schlumbergerl ND lubricator & NU drlg nipple. PU 2-7/8" DPI BHA & TIH. Drlg 4-1/8" hole. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/27/05 Drlg @ 12/3401 (236//24 hrs). TIHI washed & reamed to btm. Slidel rot & surveyed fr/12/104/-12/3401 (8/7701 TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/28/05 Drlg @ 12/577 I (237//24 hrs). Slidel rot & surveyed fr/121 340 1_ 12/5771 (8/8011 TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/29/05 Drlg @ 12/8071 (2301/24 hrs). Slidel rot & surveyed fr/12/577/- 12/8071 (8/8351 TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/30/05 Drlg @ 13/0661 (259//24 hrs). Slidel rot & surveyed fr/121 807 1_ 13/0661 (8/8951 TVD). Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 3/31/05 Testing BOp/S @ 13/1441 (78//24 hrs). Slidel rot & surveyed fr/13/066/-13/1441 (8/9171 TVD). Circ btms up & TOH for bit. LD BHA & RU test equip. Tstd BOP/s 250/51000 PSII OK. John Crisp w/AOGCC waived witnessing tst. TIH --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/1/05 4/2/05 4/3/05 4/4/05 4/5/05 4/6/05 4/7/05 4/8/05 4/9/05 . . 7 Drlg @ 13,160' (1'/24 hrs). PU 45 jts 2-7/8" DP & stood back. MU mtr, LWD, MWD & pulser sub & tst. TIR to 5" shoe @ 12,039'. Slipped & cut drill line. TIR to 13,055'. Washed 89' to btm. Rot 13,144'- 13,160' --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drlg @ 13,358' (198'/24 hrs). Slide, rot & surve3yed fr/13,160'- 13,358'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- TIR w/new bit @ 13,409' (51'/24 hrs). Slide, rot & surveyed fr/13,358'-13,409'. Circ btms up & TOR for bit. MU new bit, BRA & TIR. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drilling @ 13,673' (264'/24 hrs). TIR & washed to btm. Slide, rot & surveyed fr/13,409'-13,673'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drilling @ 13,907' (234'/24 hrs). Slide, rot & surveyed fr/13,673'- 13,822'. Short trip 6 stands & reamed to btm. Slide & rot fr/13,822'-13,907'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Drilling @ 14,227' (320'/24 hrs). Slide, rot & surveyed fr/13,907'- 14,227'. Drlg ahead. --------------------------------------------------- --------------------------------------------------- ----- - - - - - - - - - - - - - - -- --- -- - - ------ - ---- - - ------- --- -- - - - - - - -- - - -------- - -- ----- - -- - - - - - - - - - - - - -- ------ TOR for 5" csg scraper @ 14,410' (183'/24 hrs). Slide, rot & surveyed fr/14,227'-14,410' TD. Circ btms up & TOR to PU 5" csg scraper. Will run OR logs. ,.. - -- - --------------- - - - - - - - - ----- - - - - - - - - - - - -- -- - - - - -- - - - - -- - - -------- - - - - --------- - ----- - - - - - - - -- ----- --------------------------------------------------- --------------------------------------------------- TOR w/csg scraper @ 14,410' (0'/24 hrs). Finished TOR. LD BRA & PU used 4-1/8" bit & 5" csg scraper. TIR to 11,967'. Circ hole clean & TOR. Prep to run liner. --------------------------------------------------- --------------------------------------------------- --- -- - - -- ------ - ------ --- - ---- - - - - - - - - - ---- - - - - - - - - - - - - - - - - ------- --- - - ----------- - -- - ---- - - - - - - - ----- TOR for 3-1/2" liner @ 14,410' (0'/24 hrs). LD scraper. TIR, circ & cond hole. Displaced OR to #4 diesel. TOR to PU 3-1/2" slotted liner. Will run liner. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/10/05 TOR w/liner setting tools @ 14,410' (0' /24 hrs). PU 37 blank jts & 43 slotted jts 3-1/2", 8.8#, L-80 STL & TIW liner hanger. TIR & set liner @ 14,410' (liner hanger @ 11,847'). Circ & TOR w/running tools. LD DP & DC's. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/11/05 TIR to displace to FW @ 14,410' (0' /24 hrs). TOR, LD liner running tools. PU & RIR w/Baker 32-26 "DB" prod pkr & tail pipe. Set pkr @ 11,636'. TOR. PU muleshoe & TIR on 2-7/8" DP to displace hole w/FW. Displace with FW. 4/12/05 --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- Circulate soap sweep @ 14,410' (0'/24 hrs). TIR w/muleshoe to TOP @ 11,634'. Displaced hole w/FW. Rec 675 bbls OBM. Cleaned pits & circ soap sweep. PU completion string. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/13/05 RIR w/2-3/8" tbg @ 14,410' (0' /24 hrs). Circ w/soap sweeps. Stood back DP. MU & RIR w/Baker seal assembly, 75 jts 2-3/8", 4.7#, L-80 / N-80, EUE, 8rd tbg & 12 GLM's. Will hang off completion tbg. . . 8 --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/14/05 Released rig @ 14,410' (0' /24 hrs). TIH, stab into pkr w/seal assembly & space out. Pmpd biocide & pkr fluid. Landed tbg hanger, ND BOP's, NU tree & tstd, OK. ReI rig 4/14/05 @ 06:00 hr. Moved to / C42-23. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/16/05 RU flowline to flow-back tnk. Started up gas lift @ 03:30. Started unloading well. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/17/05 Recovered 520 bbls load. Fluid cleaning up. Put well into header system @ 1900 hrs. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/18/05 Well test: 165 BO w/O .1% water cut. Inj 1,000 MCF lift gas. Csg press @ 845 psi. Lifting on +/- GLV #8 of 12. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/19/05 Well test: 147 BO w/O .1% wtr cut. Inj 953 MCF lift gas. Csg press @ 840 psi. Lifting on +/- GLV #8 of 12. Well should be lifting dwn to the orifice @ this prod rate & gas inj volume. Must have a GLV problem. Can not wireline well until rig moves off current workover C42-23. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/20/05 Well test: 134 BO w/O .1% wtr cut & 82 MCF. Inj 758 MCF lift gas. Csg press @ 825 psi. Lifting on GLV #10. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/21/05 Well test: 128 BO w/0.2% wtr cut & 63 MCF. Inj gas @ 756 MCF. CP = 835 psi. --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- --------------------------------------------------- 4/25/05 Well test: 111 BO w/0.2% wtr cut & 81 MCF. Inj 720 MCF lift gas. Csg press @ 830 psi. FINAL REPORT . . Field: Middle Ground Shoal Date: 21-Apr-2005 c--- i= - Well: C41-23LN -- I -.- i ·w ~- ._- North 2481939 North 2484009 East 230647 East 230488 2326' FNL,2484' FEL 259' FNL,2588'FVVL / ~- Sec. 14, T8N, R13W Sec. 14, T8N, R13W ./ ....-------..---------...-.........-------------..----------....--------..-------------..--...-..--.. ~ MD DEVIATION AZIMUTH TVD NORTH EAST DOGLEG MRKB GR.N. / MRKB f f deg/1 OOft ------...-------.......----------........-...-------........-..-------...---..oo-------..--........---------- 0 0.00 0 0 2474190.16 231422.87 0 38 0.00 0 38 2474190.16 231422.87 0 100 0.50 2 100 2474190.43 231422.89 0.81 200 0.50 205 200 2474190.47 231422.72 0.98 300 0.50 14 300 2474190.5 231422.64 1 400 0.50 149 399.99 2474190.54 231422.97 0.92 500 4.25 62 499.9 2474191.83 231426.5 -----¡~ 600 5.75 71 599.52 2474195.02 231434.58 1.69 700 8.00 62 698.8 2474199.67 231445.57 2.49 800 8.75 39 797.76 2474208.6 231456.71 3.41 900 11.50 28 896.2 2474223.09 231466.51 3.35 1000 14.00 29 993.73 2474242.23 231477.5 2.51 1100 18.00 31 1089.83 2474265.74 231491.86 4.04 ~-~- 1200 22.75 33 1183.55 2474294.79 231511.03 4.8 1300 27.25 34 1274.16 2474329.47 231535.17 4.52 ~. 1400 29.50 34 1362.14 2474368.25 231562.63 2.25 1500 29.00 34 1449.39 2474408.12 231590.87 0.5 1600 28.50 35 1537.06 2474447.13 231619 0.69 1653 28.1 35 1583.73 2474467.36 231633.92 0 ~. 1756 28.45 32 1674.44 2474507.42 231661.76 1.42 1785 29.51 29.98 1699.81 2474519.29 231669.26 4.97 1820 29.25 26.3 1730.31 2474534.24 231677.7 5.21 --- r------~-- 1881 29.03 28.85 1783.59 2474560.24 231692.04 2.07 -- 0.19 1979 28.84 28.85 1869.36 2474601.24 231715.87 -- 2074 29.92 24.05 1952.15 2474642.46 231737.53 2.73 2170 31.2 20.98 2034.82 2474687.11 231757.22 2.1 f--- 2267 32.7 14.44 2117.15 2474735.59 231773.86 3.89 -- 2364 33.01 13.12 2198.63 2474786.39 231787.56 0.8 _.._-~ 2458 33.53 10.31 2277.23 2474836.62 231799.17 1.73 2554 34.38 7.75 2356.86 2474889.36 231808.78 1.73 2648 35.72 3.75 2433.82 2474942.91 231815.38 2.83 2745 36.91 359.03 2512 2475000.26 231818.06 3.13 -- 2837 38.29 356.27 2584.89 2475056.37 231817.02 2.37 1-- - 2933 39.57 354.6 2659.57 2475116.58 231813.58 1.72 -- 3027 40.87 351.06 2731.36 2475176.94 231807.36 2.8 r------------~ 3122 43 349.66 2802.03 2475239.75 231798.15 2.45 f---- -~- 3216 46.37 346.21 2868.86 2475304.65 231785.76 4.42 3310 46.09 344.61 2933.89 2475370.7 231770.17 1.26 3409 45.96 345.43 3002.63 2475439.93 231753.34 O~~ 3505 45.82 345.57 3069.45 2475507.04 231737.61 0.18 ~-- _ 3598 __ 46.02 346.34 3134.14 2475572.2 231722.89 0.63 3691 45.52 346.8 3199.01 2475637.35 231708.89 0.64 3787 46.65 346.82 3265.6 2475705.02 231694.66 1.18 3882 48.59 347.27 3329.63 2475773.75 231680.5 2.07 --. 3907 48.58 347.44 3346.17 2475792.13 231676.82 0.51 ~. 0.56 4004 48.05 347.62 3410.68 2475863.2 231662.8 . . MD DEVIATION AZIMUTH TVD NORTH EAST DOGLEG MRKB GR.N. MRKB f f deg/1 OOft 4100 47.71 346.87 3475.06 2475932.99 231648.67 I 0.68 4194 47.57 346.66 3538.4 2476000.95 231634.32 0.22 - 4286 47.15 347.33 3600.72 2476067.22 231620.6 0.7 4381 46.62 346.41 3665.65 2476135.1 231606.4 0.9 4473 46.48 347.59 3728.92 2476200.5 231592.87 0.94 4568 46.19 347.27 3794.51 2476267.9 231579.45 0.39 4663 46.05 347.67 3860.36 2476335.06 231566.13 0.34 -- I---- 4755 45.76 347.4 3924.38 2476399.88 231553.35 0.38 4850 47.56 346.86 3989.58 2476467.57 231539.5 1.94 4947 47.48 347.41 4055.09 2476537.66 231525.17 0.43 5045 47.25 346.05 4121.46 2476608.19 231510.23 1.05 5138 46.35 346.03 4185.13 2476674.33 231495.39 0.97 -- 5235 47.64 347.1 4251.29 2476743.68 231480:5 1.56 5329 48.52 346.39 4314.09 2476812.11 231466.02 1.09 5422 48.54 346.46 4375.67 2476880.2 231451.22 0.06 - 5515 48.29 347.29 4437.4 2476948.29 231436.97 0.72 5610 48.14 347.21 4500.7 2477017.71 231422.92 0.17 5706 48.01 346.06 4564.85 2477087.56 231408.01 0.9 5801 47.46 345.89 4628.74 2477156.14 231392.54 0.59 5898 46.61 345.56 4694.85 2477225.31 231376.61 0.91 5991 46.3 346.49 4758.92 2477291.08 231361.83 0.8 6084 45.7 345.23 4823.53 2477356.3 231346.98 1.17 6180 45.4 345.93 4890.75 2477423.04 231331.44 0.61 6275 45.16 345.43 4957.6 2477488.81 231316.25 0.45 6366 44.66 344.9 5022.05 2477551.28 231301.22 0.69 6459 44.9 346.64 5088.06 2477615.12 231286.58 1.34 6556 45.06 347.57 5156.68 2477682.29 231272.81 0.7 6650 46.44 348.85 5222.27 2477748.49 231260.58 1.76 6742 46.73 349.04 5285.5 2477814.35 231249.27 0.35 6841 46.94 348.62 5353.23 2477885.49 231236.9 0.38 6937 47.36 348.05 5418.51 2477954.73 231224.25 0.62 f----- 7030 47.61 348.89 5481.36 2478022.19 231212.09 0.72 7130 46.18 347.97 5549.69 2478094.03 231199.1 1.58 7224 46.1 347.91 5614.83 2478160.61 231186.46 0.1 7313 45.98 348.68 5676.61 2478223.62 231174.9 0.64 -- 7407 46.22 348.76 5741.79 2478290.33 231163.17 0.26 7502 46.12 347.36 5807.58 2478357.68 231150.53 1.07 7596 46 347.12 5872.81 2478424.02 231137.1 0.22 7687 46.11 347.17 5935.96 2478488.22 231123.98 0.13 -~ c----Z784 45.99 346.93 6003.28 2478556.61 231109.9 0.22 ___ - 7877 46.28 347.57 6067.72 2478622.33 231096.6 0.59 7993 46.55 347.89 6147.7 2478704.82 231080.63 0.31 ~- 8089 46.97 347.65 6213.46 2478773.49 231067.38 0.47 8185 47.4 348.49 6278.71 2478842.7 231054.4 0.78 ._~ 8279 47.58 348.04 6342.23 2478910.85 231041.87 0.4 -- 8372 47.23 347.48 6405.17 2478978.07 231028.89 0.58 -.-- 8466 47.42 347.05 6468.89 2479045.81 231015.2 0.39 --- 8562 47.42 347.03 6533.84 2479115.04 231000.92 0.02 8658 47.5 347.28 6598.75 2479184.34 230986.78 0.21 8753 47 346.48 6663.23 2479252.62 230972.51 0.81 -- 8849 47.31 347.01 6728.52 2479321.48 230957.94 0.52 8946 47.28 346.85 6794.3 2479391.27 230943.41 0.13 9041 47.36 347.43 6858.7 2479459.69 230929.43 0.46 9131 47.68 346.6 6919.48 2479524.69 230916 0.77 f-----. 9234 47.76 346.5 6988.78 2479599.19 230899.98 0.11 f-- 9328 47.8 346.74 7051.94 2479667.26 230885.42 0.19 9425 48.27 348.86 7116.81 2479738.08 230871.8 1.7 . ' . . MD DEVIATION AZIMUTH TVD NORTH EAST DOGLEG MRKB GR.N. MRKB f f qeg/1 09~ 9519 47.66 347.28 7179.75 2479806.7 230858.94 1.41 9706 47.47 347.13 7305.93 2479941.95 230831.46 0.12 9786 46.78 347.8 7360.36 2479999.45 230820.05 1.06 9872 45.46 348.16 7419.97 2480060.36 230808.53 1.56 9931 -~ 44.67 348.16 7461.65 2480101.42 230800.9 1.34 9995 44.58 354.13 7507.22 2480145.94 230795 6.55 10098 45.55 356.59 7579.97 2480218.72 230790.78 1.94 10195 46.17 358.35 7647.52 2480288.31 230789.3 1.45 -- 10284 46.6 358.35 7708.92 2480352.74 230788.92 0.48 10379 46.78 358 7774.08 2480421.87 230788.3 0.33 10473 46.69 358.35 7838.51 2480490.31 230787.69 0.29 10567 46.69 358 7902.99 2480558.71 230787.07 0.27 10661 46.25 356.94 7967.73 2480626.84 230785.62 0.9¡-- 10757 45.99 358 8034.27 2480696.02 230784.15 0.84 10851 45.02 358.35 8100.15 2480763.06 230783.55 1.07 10948 44.76 358.7 8168.87 2480831 .52 230783.35 0.37 ~- 11 049 46.51 357.59 8239.49 2480903.71 230782.65 1.9 ~- 11142 48.54 357.39 8302.29 2480972.29 230781.22 2.19 11236 49.38 356.74 8364.01 2481043.16 230779.2 1.03 11328 48.31 358.64 8424.55 2481112.41 230777.99 1.94 11423 49.26 358.05 8487.15 2481183.87 230777.56 1.1 11520 49.43 0.61 8550.35 2481257.44 230778.38 2.01 11596 49.93 359.5 8599.53 2481315.36 230779.76 1.29 11677 57.97 353.69 8647.18 2481380.7 230777.2 11.49 11774 67.38 349.62 8691.67 2481466.09 230766.53 10.39 11864 74.42 347.1 8721.11 2481549.69 230751.26 8.26 11960 81.23 343.87 8741.35 2481640.97 230729.8 7.82 12027 84.33 344.26 8749.77 2481705.28 230713.03 4.66 12114 87.4 341.8 8756.04 2481788.81 230689.61 4.52 12196 86.64 342.36 8760.3 2481867.28 230666.2 1.15 12292 85.43 345.18 8766.94 2481959.81 230641.54 3.19 12386 83.21 349.13 8776.25 2482051 .43 230622.84 4.8 12484 82.53 346.11 ---- 8788.42 2482146.85 230604.17 3.14 12582 85.1 344.66 8798.98 2482241.65 230581.75 3.01 12675 81.5 348.48 8809.83 2482331 .92 230562.36 5.62 12770 79.9 347.06 8825.18 2482423.97 230544.6 2.24 12863 75.62 352.88 8844.91 2482513.73 230530.8 7.65 12956 75.69 349.62 8867.96 2482603.06 230519.13 3.4 -- 13051 74.69 347.66 8892.24 2482693.49 230503.11 2.26 13122 75.69 350.76 8910.39 2482761.18 230491.81 4.45 13219 77.4 352.3 8932.96 2482854.78 230480.06 2.34 13313 76.8 354.94 8953.95 2482946.03 230471.96 2.81 - -- 13407 78.3 353.65 8974.22 2483037.55 230464.93 2.08 . 1350}t~4.09 350.8 8997.84 2483133.04 230454.13 5.09 -- 13600 73.83 350.36 9023.81 2483222.48 230441.39 0.53 13696 74.04 351.03 9050.38 2483313.83 230428.56 0.71 -- 13794 77.78 2.73 9074.31 2483408.63 230425.64 12.19 13887 77.53 12.33 9094.24 2483498.29 230439.58 10.09 -- 13981 79.44 12.61 9113 2483587.74 230461.52 2.05 14080 78.94 4.16 9131.6 2483683.5 230477.89 8.4 14175 77.5 358.62 9151.01 2483776.35 230482.28 5.91 -. 14271 81.85 359.38 9168.21 2483870.77 230482.8 4.6 14358 87.07 1.02 9176.61 2483957.3 230485.09 6.29 14410 90.19 2 9177.85 2484009.21 . 230487.65 . 6.29 ,/ . . MGS C41-23LN Cook Inlet, Alaska Leg 4, Conductor 28 API No.: 50-733-20163-01 Sidetrack: 1-20-05 Original Spud: 12-17-68 Surf Csg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1 ,350 sx. Intermediate Csg: 7" 29# L80 BTC. Set @ 9,622'. Cmt'd wI 335 sk STG 1 & 392 sk STG 2. DV Tool @ 2,515'. Drilling Liner: 5" 18# L80/P11 0 STL. 1 jt P110 @ liner top. Set @ 12,039'. TaL @ 9,259'. TIW "LX" Liner Top Pkr. Cmt'd wI 220 sk. Production Liner: 3-%" 8.8# L80 STL Slotted. Set@ 14,410'. TOL@ 11,848'. Blank Sections: 11,848 - 12,258' 12,442 - 12,540' 12,664 - 12,730' 13,192 - 13,225' 13,378 - 13,544' 13,672 - 14,097' 14,377 - 14,410' TD: 14,410' MD (9,178' TVD) / . PLF 4-26-05 KB: 35' Water Depth: 73' MSL TBG: 2-7/8" 6.5# L80 8rd EUE to 9,175' 2-3/8" 4.7# L80 8rd EUE 9,176' to 11,681' Set: 4-14-05 GLM MD TVD PORT PSC PSO #1 1975 1894 10 920 958 #2 3566 3112 10 910 937 #3 4874 4006 10 900 923 #4 6027 4783 12 890 923 #5 7211 5606 12 880 906 #6 8143 6251 12 870 892 #7 8947 6794 16 860 894 #8 9617 7246 16 850 879 #9 10195 7648 16 840 864 #10 10686 7985 16 830 851 #11 11123 8289 16 820 835 #12 11591 8597 24 ORIFICE Hanger: 2-7/8" RTS6 Box X 3-%" 8rd Pin @ Surf X-Over 3-%" 8rd Box X 2-7/8" 8rd Pin @ 2' 6' Pup Jt 2-7/8" 6.5# L80 8rd EUE @ 313' 2-7/8" X Nipple (2.313" 10) 9Cr @ 320' 4' Pup Jt 2-7/8" 6.5# L80 8rd EUE @ 321' 2-7/8" 6.5# L80 8rd EUE @ 321 - 9,175' X-over 2-7/8" 8rd Box X 2-3/8" 8rd Pin @ 9,175' 2-3/8" 4.7# L80 8rd EUE @ 9,176' -11,634' 2-3/8" X Nipple (1.875" 10) 8rd 9Cr @ 11,634' 10' Pup Jt 2-3/8" 4.7# 8rd EUE 9Cr @ 11,636' 12.5' Baker Loc (40-26) wI Seals @ 11,646' 5" Baker DB Perm Pkr (32-26) 9Cr @ 11,646'* 10' Baker SBE 13Cr @ 11,649' X-over SBE to 2-3/8" 8rd Pin 9Cr @ 11,658' 10' Pup Jt 2-3/8" 4.7# 8rd EUE 9Cr @ 11,659' 2-3/8" XN Nipple (1.791" 10) 9Cr @ 11,669' 10' Pup Jt 2-3/8" 4.7# 8rd EUE 9Cr @ 11,670' WLREG @ 11,681' *Pkr was set on DP. Tbg was 12.4' deeper than DP measure wI all depths corrected to tbg meas. Liner Across: HR, HN, HK, HI, HE & HC. 10254.7 A22- 4LS Re: BOP Test Schedule C41-23LN Platform C Brad - In situations where operations transition from workover (maximum 7 day BOP test interval) to drilling (maximum 14 day test inteval), the 14 day clock starts with the most recent BOP test conducted during the workover (initial test if workover takes less than 7 days to complete). At no time can there be more than 14 days between BOP tests for continuous operations. Regarding your current well, our records indicate the last BOPE test was 1/23/05; based on that your next test must occur not later than 2/6/05. Jim Regg AOGCC Drilling Foremen wrote: Gentlemen, We were finally successful in plugging and abandoning C41~23 and started drilling nèw well C41-23LN yesterday January 27 2005. As per conversation with Jeff Jones this morning, our next BOP test will be due in two weeks from the start of drilling Yesterday, on February 10 2005. Thanks, Brad Rasch 776-2534 I of I 2/3/2005 9:05 AM uU, L"l ':>~Ileuule C41-23LN Platfonn C Gentlemen, We were finally successful in plugging and abandoning C41-23 and started drilling new well C41-23LN yesterday January 27 2005. As per conversation with Jeff Jones this morning, our next BOP test will be due in two weeks from the start of drilling Yesterday, on February 10 2005. Thanks, Brad Rasch 776-2534 1 of 1 1/28/2005 10:22 AM Re: C41-23 e e Subject: Re: C41-23 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 24 Ian 200508:21 :35 -0900 To: Paul_Figel@xtoenergy.com Paul, Winton mentioned that you had been in contact regarding C41-23. Doesn't look like things improved any. What is the current status?? Looks like this experience might be important when considering when to abandon other old wells. Tom Maunder, PE AOGCC Paul Figel@xtoenergy.com wrote: (See attached file: C41-23 Current Wellbore Status as of 1-18-05.doc) (See attached file: C41-23 Proposed P&A.doc) (See attached file: MGS C41-23LN Summary 1-18-05.pdf) Winton, Attached are the daily well reports, the current wellbore diagram & proposed P&A schematic. As discussed, we have not been able to make progress in fishing this 18 year old injection string. We have only retrieved ±400' in the last 6 days as it easily breaks apart either with the overshot or wash pipe due to the severe corrosion. The TOF is presently @ 2625'. The quality of the tubing did not improve once we got below the 7" sqz job done in '87 between 2123-59'. The well is full of scale and have been unable to pump into the tbg when the overshot is engaged. When attempting to kill the well with coil tbg on 1-4-05, the press was communicating between the 3-1/2" tbg & 7" casing. There was also 200-400 psi on the 10-3/4" annulus. Therefore, with AOGCC approval, a CIBP will be set on top of the tbg fish @ 2615' and a cement plug will be set across to 1950'. The drilling program will continue with cutting the old 7" @ 1950' (300' below the 10-3/4" casing shoe). After the 7" is pulled, a 10-3/4" packer will be used to determine if the 10-3/4" is intact or will require a sqz. An open hole cement kickoff plug will be set from 1950 -1800'. The new 7" intermediate set @ ±9,550' will need to have cement tied back into the 10-3/4" casing. Please contact me with any questions @ 432-620-6743. Thank you, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 1 of 1 1/24/20058:21 AM e e I~ 1~!2 I Well Name: APIIUWI 50-733-20163-01 Daiiy Activity and Cost Summary MGS C41-23LN Ground Elevation (It) Casing Flange Elevation (It) KB-Ground Distance (It) KB-Casing Flange Distance (It) Spud Date Rig Release Date 0.00 105.00 ob Ca egory nmary Job I ype I Secondary Job Type . vvo"IOg mereSt ,,,,¡ Drilling Drilling - re-entry Drilling - re-entry 100.00 Start Date End Date AFE Number Total AFE Amount 12130/2004 "tV"-"-.... Objective Contractor I Rig Number ¡Rig Type Inlet Drilling ! DrillinQ - Triple . f¡¡>ÏNóO @h1T~D..tè· ........ 1.0 12130/2004 1213112004 66,983.00 66,983.00 Unload and RU Coil Tubing Unit. 2.0 12/31/2004 1/1/2005 14,417.00 81,400.00 Finish RU CTU and test. MU wash tool and ~to522'. POH and SD CT operations for night. Build 9.2 ppg kill mud. 3.0 1/1/2005 1/212005 28,243.00 109,643.00 Displace diesel from CT. MU motor and 2-1/2" mill. Wash in hole and miisçale 522' - 4000'. POH w/ coil and SD for night. Bui!d volume and bleed well to flow tank. 4.0 1/212005 1/3/2005 19,435.00 129,078.00 Change out mill to 2.7" OD. Minhard seale 4000' -9763'. Circ bottoms up and pump 30 bbi hi-vis sweep. 5.0 1/3/2005 1/4/2005 41,503.00 170,581.00 Pump sweep, POOH. MU 2.59" jet cutter and RIH. 0tÆ~.@ 8875'. Load CT with 10.2 ppg mud and prep to wash in hole. I 6.0 1/4/2005 1/5/2005 I 67,340.00 [ 237'921.oo[WaSh to tubing cut @ 8875' with coil. Circulate bottoms up and pum¡1..U·.Oþpg kill weight mud. Monitor well - well dead. POOH with coil. RD CTU and back load on boat. 7.0 1/5/2005 1/6/2005 55,663.00 293,584.00 Monitor well - flowing 4~witIl~e increasing. RU CTU, RIH and displace with 12.1 ppg mud. I .11""""- 92, ,~".... fI, cnt"'TI 9.0 1/7/2005 1/8/2005 49,419.00 405,815.00 Test BOP's. RIH with tbg spear and attempt to pull tbg free (unsucessful). RIH with jet cutter and cut1lilg@631'. TOH & LD tbg. IU. - I/§-í .wû" """O,IOO.UV LU I Ô j,,, oJ-l/¿ lUg. RUI. le"l piugéllld le"l BOP'5 - OK. MU & Tin wiii. oJ-l/¿ overshot & jars. Unable to get beloW 402' due to fill - TOH. PU 6" clean out bit & TIH. Wash to 521' - flowline plugged off. Attempt to circulate and unplug flo'yvline. 11.0 1/9/2005 1/10/2005 31,272.00 467,460.00 Work on plugged flowline. Wash & ream to 581', flowline plugged, replace section of flowline. Wash to top of fish @ 632'. TOH. TIH with overshot, work over tbg & pull free. LD tòoIS & 45 Is 3-1/Z' tbg. MU 6" bit & clean out assy to clean out to TOF @ 2060'. 12.0 1/10/2005 1/11/2005 36,539.00 503,999.00 RIH w/6" bit & clean out assyto~. TOH, PU 5-3/4" overshot & TIH. Work over fish, TOH - no recovery. TIH, work over fish, TOH - recover 1 1/2 jts (total 65 1/2 jts LD). 13.0 1/11/2005 1/12/2005 49,682.00 553,681.00 Make 3 fishing runs, recover 4 jts (total recoverý 69 jts, TOF @ 2217.15'. TOH at report time. 14.0 1/1212005 1/13/2005 36,174.00 589,855.00 TOH - no recovery. PU & TIH with shoe and 20 jt 5" wash pipe. Wash over fish to 2283'. TOH, MU new shoe and TIH. 15.0 1/13/2005 1/14/2005 33,477.00 623,332.00 Wash over fish to 2505'. TOH, change shoe, TIH and wash over fish to 2572'. 16.0 1/14/2005 1/15/2005 39,036.00 662,368.00 TOH, LD 300.17 of 3-1/'Z' tbg. TIH with overshot (unable to work over fish). TOH, MU & TIH with concave mill. Mill 257'Z - 2582'. Pump sweep & TOH. 17.0 1/15/2005 1/16/2005 36,006.00 698,374.00 TOH, LD mill. MU overshot, TIH. Work over fish, TOH. Recover 11' of tbg. Make 2 runs with overshot - no recovery. f------ 18.0 1/16/2005 1/17/2005 31,351.00 729,725.00 TOH. Test BOP's - OK. PU mill, TIH and mill 2590' - 2599'. TOH, MU burning shoe and TIH. Wash over fish @ 2599'. . I to burn over fish unable _~:- ., - . , .... .v ."vv " ,~, Work over fish and POH. Recover 22 jts of 3-1/2" tbg. PU mill and mill 2618' - 2625', TOH. PU overshot, TIH and attempt to work over fish. TOH to PU ì' .--,-- - ,.--. .." I I Surface Legal Location Sec. 23, T-8-N, R-13-W Field Name Middle Ground Shoal License No. 204-236 StateJProvince Alaska Well Configuralion Type Deviated II www.peloton.com Page 1/1 Report Printed: 1/1812005 MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 Surf Csg: 103/4",40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1 ,350 sx. Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593'. Cmt w/900 sk. TOC by CBL @ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Deepest Coil Tbg Mill Depth @ 9763' 1-3-05 Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TD: 10,712' e e PLF 1-18-05 KB: 35' Water Depth: 73' MSL Tbg: 31/2", 9.3#, N80 EUE, AB-MOD @ 10160' Set 10-11-87 31/2" Otis "X" Nipple (2.75"ID)@ 324' 3 1/2" Otis "X" Nipple (2.75"'D) @ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly@ 8895' MD (7920' TVD) Baker FB-1 Packer wI Mill Out Ext@ 8898' MD (7920' TVD) 31/2" Cameo KBUG w/Dummy@ 9295' MD (8269' TVD) Baker "G" Locatorw/2 X-Seal Units @ 9579' MD (8529' TVD) Baker FB-1 Packer wI Mill Out Ext@ 9582' MD (8529' TVD) 3112" Otis "X" Nipple (2.75"ID)@ 10123' MD (8994' TVD) Baker "G" Locator w/2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer @ 10157' MD (9023' TVD) 9/12/87 Sqz esg leak 2,123-59' wI 50 sk. TOF @ 2625' 1-18-05 Tbg Cut @ 8875' GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' MGS C41-23 WIW Cook Inlet, Alaska Leg 4, Conductor 28 API No.: Spud: 12-17-68 Surf Csg: 10 3/4", 40.5# J55 BTC. Set @ 1,653'. Cmt'd w/1 ,350 sx. e CIBP @ 2615'w/TOC @ 1950'. Longstring: 7", 26-29 Ib N80 BTC. Set @ 10,593'. Cmt w/900 sk. TOC by CBL @ 7,800'. 26#: Surf - 8,450' 29#: 8,450 -10,593'. Deepest Coil Tbg Mill Depth @ 9763' 1-3-05 Fish: RBP @ 10,509' (9/87) PBTD: 10,535 TD: 10,712' e PLF 1-18-05 KB: 35' Water Depth: 73' MSL Tbg: 31/2",9.3#, N80 EUE, AB-MOD @ 10160' Set 10-11-87 31/2" Otis "X" Nipple (2.75" ID)@ 324' 31/2" Otis "X" Nipple (2.75" ID)@ 8863' MD (7891' TVD) Baker "E" Anchor Seal Assembly @ 8895' MD (7920' TVD) Baker FB-1 Packer wI Mill Out Ext@ 8898' MD (7920' TVD) 31/2" Camco KBUG wI Dummy@ 9295' MD (8269' TVD) Baker "G" Locatorw/2 X-Seal Units@ 9579' MD (8529' TVD) Baker FB-1 Packer wI Mill Out Ext@ 9582' MD (8529' TVD) 31/2" Otis "X" Nipple (2.75" ID)@ 10123' MD (8994' TVD) Baker "G" Locatorw/2 X-Seal Units @ 10155' MD (9023' TVD) Baker FB-1 Packer@ 10157' MD (9023' TVD) 9/12/87 Sqz csg leak 2,123-59' w/ 50 sk. TOF @ 2625' 1-18-05 Tbg Cut @ 8875' GN-GO: 9087'-9108' GR-GS: 9450'-9495' HC-HN: 9706'-10147' (Sqz in 9-87 w/100 sk) HN-HR: 10180'-10235' HR-HZ: 10254'-10316' HR-HZ: 10340'-10480' . ~1f 1fŒ (ITJ~ fÆ~fÆ~~ . AI,ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bobby Smith Drilling/Operations Manager XTO Energy, Inc. 3000 North Garfield, Suite 175 Midland, Texas 79705 Re: Middle Ground Shoal C41-23LN XTO Energy, Inc. Permit No: 204-236 Surface Location: 504' FSL, 1532' FEL, SEC. 23, T8N, R13W, SM Bottomhole Location: 155' FNL, 2832' FEL, SEe. 14, T8N, R13W, SM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. XTO Energy, Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law rrom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ~ iel T. Seamount, Jr. Commissioner DATED this~daYOfDeCember, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · - ;[t2 November 18, 2004 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: C41-23LN Sidetrack Dear Mr. Norman, XTO Energy, Inc. hereby applies for a Permit to Drill an offshore develop~ent well from Platform C in the Middle Ground Shoal Field of Cook Inlet. The well is planned as a sidetrack of the existing C41-23 wellbore in order to penetrate and develop an un-drained· portion of the Hemlock conglomerate in the vicinity of XTO Platform A. Approval of the associated pre-drilling work plan for the existing wellbore has been requested via a Sundry Notice submitted under separate cover. ,<' The anticipated spud date of C41-23LN is approximately December 6, 2004. Approximately 1,900' of 7" production casing will be pulled from the existing well and the sidetrack kicked off below the shoe of the 10-3/4" surface casing. An 8-112" hole will be directionally drilled to the top of the GN Sands at ±IO,800'MD where 7" casing will be set. A 6" hole will then be drilled to the base of the Hemlock HR at + II,950'MD on the West Flank. where a 5" drilling liner will be set and cemented. A 4-1/8" hole will be drilled to TD at the top of the Hemlock HC (reverse penetration) at ±14,476'MD and a 3-. 1/2" slotted liner set. The well will be completed with a 3-1/2" gas lift completion.. .i Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the well's proposed surface and bottomhole locations per 20 AAC 25.050 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of20 AAC 25.050. 5) Diagrams and descriptions of the BOP equipment to be used as required by 20 AAC 25.035 (a)(1) and (b) and a request for waiver of one of the provisions of those regulations have been previously submitted and approved. 6) A complete proposed casing program is attached as per 20 AAC 25.030. 7) The drilling fluid program, in addition to the requirements of 20 AAC 25.033 is attached. XTO Energy Inc. - 200 North Loraine, Suite 800 - Midland, Texas 79701 (432) 682-8873- Fax (432) 687-0862 . . Mr. John Norman Page 2 8) A copy of the proposed drilling program is attached. 9) XTO Energy does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during sidetracking, drilling and completion operations. 10) While this well is considered to be a development well, basic mud logging will be performed while drilling to aid in tracking the location, thickness and quality of the intervals penetrated. 11) A Summary of Drilling Hazards is attached. 12) The following are XTO Energy's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Bill Penrose, Senior Drilling Engineer (907) 258-3446 2) Geologic Data and Logs (20 AAC 25.071) Mike Langeler, Senior Geologist (817) 885-2581 If you have any questions or require additional information, please contact me at (432) 620-6718 or Bill Penrose at (907) 258-3446. Sincerely, XTO ENERGY, INC. fJrltrL ~ Bobby L. Smith Drilling/Operations Manager enclosures cc: Bill Penrose l1a. Type of Work: ) ¡2. Operator Name: I XTO Energy, Inc. 3. Address: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25 005 . Drill LJ Redrill [2] Re-entry 0 . AI/__ ~1 1 b. Current Well Class: Stratigraphic Test 0 5. Bond: Bond No. 6. Proposed Depth: MD: 14,488' 7. Property Designation: Exploratory U Development Oil l.:j Multiple Zone 0 Service 0 Development Gas 0 Single Zone [2] Blanket [2] Single Well 0 11. Well Name and Number: 103652600 C41-23LN , 12. Field/Poo/(s): TVD: 9,235' Middle Ground Shoal 3000 North Garfield, Suite 175 Midland, TX 79705 4a. Location of Well (Governmental Section): Surface: 504' FSL, 1532' FEL, See. 23, T8N, R13W, 8M Top of Productive Horizon: 2700' FSL, 2451" FEL, See 14, T8N, R13W, 8M Total Depth: 155' FNL, 2832' FEL, See 14, T8N, R13W, SM 4b. Locatio~Well (St~ase Plane Coordinates): SUrface:.f1 2474190 &7 231423 Zone- AK-4 16. Deviated wells: Kickoff depth: 1,900 feet Maximum Hole Angle: 78 degrees 18. Casing Program: Size Hole Casing 8.5" 7" 6" 5" 4.125" 3.5" 19. Total Depth MD (ft): 10,712' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Specifications Weight 29# 18# 8.8# Grade Coupling L-80 BTC L-80 STL N-80 STL Length 9,950' 2,500' 2,838' ADL 18756 13. Approximate Spud Date: 12/15/2004 14. Distance to Nearest 5120 Property: 2,580' 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 105 feet ASL Within Pool: 61' from C44-14RD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 5,500 psi Surface: 4,553 psi Setting Depth Quantity of Cement c.f. or sacks 8. Land Use Permit: N/A 9. Acres in Property: Top Bottom MD 0' 9450' 11,650' (including stage data) G: 346 cf lead 195 cf tail 204 cf Class G NI A - slotted liner TVD 0' 7,154' 8,564' MD 9,950' 11,950' 14,488' TVD 7,498' 8,655' 9,235' PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): 9,507' None 10,509' 9,333' Length Size 370' 24" 1,653' 10-314 " 10.593' 7" Junk (measured): RBP @ 10,509' TVD Cement Volume MD 1.350 sx 370' 1653' 370' 1584' 900 sx 10,593' 9404' Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Property Plat 0 Diverter Sketch 0 Seabed Report 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bobby Smith ill i £-7/ I Permit to Drill _ I / ~ / Number: .2¡)'-{ - 2~c.p Conditions of approval: Signature Phone 432-620-6718 Commission Use Only API Number: Permit Approv~1 / / 50-733-20/(:,3-01 Date: /,;:¡// /0(,1 , Time v. Depth Plot U Shallow Hazard Analysis U Drilling Fluid Program [2] 20 AAC 25.050 requirements 0 Date Contact 8í11 Penrose 258-3446 Title DrillinalOperations Manager //~8/ov r Date See cover letter for other requirements. Samples required Yes 0 No gr Mud log required Yes 0 No H Hydrogen sulfide measures Yes 0 No ~ Directional slJrvey requir~d Yes J25f. No 0 Other: sooa f~\ ~~~~<;\- ~~\(:~\,,~~-..:.~\ '=- \t-\ ê~'l~~f" ('\.~~ ~O\~ o.<..\-\~\\"\~C;, 0ftIInI1 SignÌd By BY bRDER OF - I /. Approved by: DAJt~ f""\ 1'"'\ I MJP~ON Date: '~L ¿ /,,1/ Form 10-401 Revised 12/2003 U r\ I \J II ~ f\ L Submit :nDUPhcate · MGS C41-23LN ~~ ß'0V¥ "'~\'\\~S 'I ~\"'C)~~ro~~ ~<)\.)~ w I ~\)~4b~ Þ ~ .L-~~ û ~ h,A-~~ b~\o~ \I.g -11A ^ .L_ F Ii."_~____ XTO Energy, Inc. Sidetrack Procedure ?Q:r-\s ~\\,)~~~ \>(.\ S(JL\-4<O ''S With the rig over C41-23, the BOPE installed and the wellbore plugged with cement: 1. N/D BOP's and tubing spool. 2. Weld slips to 7" casing in casing spool. NIU BOP's and tubing spool. Test BOP's. 3. Rill with a mechanical cutter and cut the 7" casing at 1,950'. 4. Attempt to circulate the 7" x 10-3/4" annulus full of 9.0 ppg water-base drilling mud. Ensure well is dead. 5. MIU a 7" casing spear, engage 7" casing and POB. LID the 7" casing, checking for NORM. 6. RIB wi open-ended drill pipe and set a viscous mud pill ITom 2,100' to 2,000'. ,... 7. Mix and pump a balanced cement plug from 2,000' (50' down inside the 7" casing stub) to 1,800' (150' above the 7" casing stub). POB. 8. WOc. RIB with 8-112" bit and tag cement. Clean out to 1,850' (100' above casing stub). POB. ~ 9. fl<L ~ \)...)c.- \ , 10. J(),-\ - d~Co 11. 12. MIU 8-1/2" bit on directional drilling assembly. Rill and kick off cement plug. Directionally drill 8-112" hole from 1,850' to 9,950' MD. ,. Run and cement 7", 29#, N-80, BTC casing at 9,950' MD. \ ~ fu'1 ~CJ \/ -\-(:~ ~ Pressure test casing to 3,000 psi. Drill out shoe track and raise mud weight to ±13.5ppg. 13. Drill approximately 20' of new hole and conduct leak-off test (not to exceed 15.0 ppg EMW). 14. Directionally drill 6" hole from 9,970' to 11,950' MD. 15. Run and cement 5", 18#, L-80, STL liner with liner-top packer at 11,950' MD with TOL at approximately 9,450' (-500' oflap). . . 16. Pressure test casing to 3,000 psi. Drill out shoe track and reduce mud weight to ±9.0ppg. 17. Directionally drillA-1I8" hole from 11,950' to 14,488'MD, TD. /' 18. Displace open hole with clean diesel. 19. Run and set 3-1/2",8.8#, N-80, STL liner with liner-top packer at 14,488' MD with TOL at approximately 11,650' (~300' oflap). 20. Run 2-7/8",6.5#, L-SO, Srd EVE completion with gas lift design. 21. Pickle inside of tubing with HC1/xylene and circulate inhibited filtered Inlet water into annulus before setting packer. 22. N/D BOPE, N/U tree. Test tree to 5,000 psi. Release rig. XTO Energy C41-23LN -1 000 P&A Old Well bore (9 days) l I I I 1 V 1 i I I I I I i I I I I 1 I i I 1 I I I I ~ III + IlJ I I I I Ii I It I i I i-I I I I I I 1+ fA I I I ,t'T¡t 11 I -2000 I I I ~ I I I I I 1 I I I I I ! I \ 1/ I I I I I -3000 " I \ I I I ~ et w/1i s od:k, \ ~ I 1 ¡ 1 I I I +-r-I--I--+- ! 'ri I Hir dl wl(~ f " I I I I I -4000 I f'JFI I I I I I I I i I I I " I I I I 1 -5000 I I I I I i " I I I I \ I I I I I ~ I b "II - 1 "hdle 129 (j~V\ \) I I -6000 I - r\ I I I .; LL II I I I I l"'l'\..lj I I i I I ci -7000 I I I I Lf- I 1\ I I I ~ I I I I I ~ TÎ i T\ I I I i m -8000 I ~ I--Li I I' I I a:: I I "- I I .c -9000 I I I 1 \ \ I - 1.+ "',,\ H I I Q. I I I \ Q) I N :>E asj g I d¡a}~J \ 0 I -1 0000 I I ¡ I í IIII~I 1/ í I ri,l ¡ " o e (f d y~) + III -j it-I I f-~ I I I l/1 r I I I ~ et 3 1 2' S 01 e -11000 I I I I I ~~ I I I 4 I I Ir r ( d~j1s) I i I I I ! I ,..."", \ I I 1 Ttl -12000 I I I , I i i , I I I; ... 1 1\ 11/1 .. , I I I I I \ I I I \7 I I ~~\ 1 \ I(~ dl:M\1 -13000 ! I I I I I W I, I I , S t /5"lli e ( a S I / I i""o¡o... .i I \ I I , I I I -It I I I I I I r i I I I I , I I l'fr II - 71" 0 e (1 avs r~"" 1\ -14000 I \ I I . I I I I I i""o"" .... ... I I I -15000 : . . 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 47 49 51 53 55 57 59 61 63 65 67 69 71 73 75 77 Day . . XTO Energy, Inc. Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks MGS C41-2LN Sidetrack Drillin2 Fluid Properties: 8-1/2" Hole Section 6" Hole Section 4-1/8" Hole Section (9,950' - (11,950' - (1,850' - 9,950'MD) 11,950'MD) 14,488'MD) (1,758' - (7,498' - (8,655' - 7,498'TVD) 8,655'TVD) 9,235'TVD) Density 10.6 13.5 9 PV 25 - 30 30 - 35 20 - 25 YP :::11 12-15 11 Funnel Vis 85 - 100 1 00 - 11 0 80 - 85 Initial Gel 11-13 12 - 15 10 - 12 10 Minute Gel 27 - 30 30 - 33 25 - 30 Hi.temp. 4-6 4-6 4-6 pH N/A N/A N/A % Solids 14 18 12-14 Drillin2 Fluid System: Two Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifu e De asser Pit Level Indicator Visual and Audio Alarms Tri Tank Fluid Flow Sensor Fluid A itators Maximum Anticipated Surface Pressure: 8-112" Hole Section The maximum anticipated surface pressure (MASP) for the 8-112" hole section in this sidetrack will be the lesser of the formation pore pressure (less a full gas column to the surface) at the 7" casing point or the formation fracture pressure at the 10-3/4" surface casing shoe (less a full gas column to the surface). Based on offset well data, the highest formation pressure expected in this 8-112" hole section is 3,600 psi at the section TD of~ 7,498' TVD (or 0.480 psi/ft). Well-documented fracture gradient data for this area indicates that the fracture gradient at 1,584' TVD (the shoe depth of the 10-3/4" surface casing) is 0.572 psi/ft. Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. . . 8-1/2" hole section MASP (pore pressure) MASP (fin breakdown) '= (7,498 ft)(0.480 - 0.11) '= 2,774 psi (1,584 ft)(0.572 - 0.11) '= 732 psi '= Therefore, MASP in the 8-1/2" open hole section is 732 psi and the 5,000 psi BOPE system to be used will be adequate. 6" Hole Section The maximum anticipated surface pressure (MASP) for the 6" hole section in this sidetrack will be the lesser of the fonnation pore pressure (less a full gas column to the surface) at the 5" liner setting point or the fonnation fracture pressure at the 7" intennediate casing shoe (less a full gas column to the surface). Based on offset well data, the highest fonnation pressure expected in this 6" hole section is 5,500 psi at the section TD of 8,655' TVD (or 0.636 psi/ft). Fracture gradient data for this area indicates that the fracture gradient at 7,498' TVD (the 7" intennediate casing shoe depth) is 0.749 psi/ft. Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. 6" hole section MASP (pore pressure) MASP (fin breakdown) '= (8,655 ft)(0.636 - 0.11) = 4,553 psi (7,498 ft)(0.749 - 0.11) = 4,791 psi Therefore, MASP in the 6" open hole section is 4,553 psi and the 5,000 psi BOPE system to be used will be adequate. 4-118" Hole Section The maximum anticipated surface pressure (MASP) for the 4-1/8" hole section in this sidetrack will be the lesser of the fonnation pore pressure (less a full gas column to the surface) at the 3-1/2" liner setting point or the fonnation fracture pressure at the 5" liner shoe (less a full gas column to the surface). Based on offset well data, the highest fonnation pressure expected in this 4-118" hole section is 3,500 psi at the section TD of 9,235' TVD (or 0.379 psi/ft). Fracture gradient data for this area indicates that the fracture gradient at 8,655' TVD (the 5" liner shoe depth) is 0.759 psi/ft. Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. 6" hole section MASP (pore pressure) MASP (fin breakdown) = (9,235 ft)(0.379 - 0.11) = 2,484 psi (8,655 ft)(0.759 - 0.11) = 5,617 psi = Therefore, MASP in the 4-118" open hole section is 2,484 psi and the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risk: The nearest wellbore to that of C41-23LN is that ofC44-14RD. C41-23LN will pass 61' from the C44-14RD wellbore at a depth of3,277'. . . Drillinf Area Risks: The primary drilling risks in the C41-23LN area are those of stuck pipe in the coals of the Tyonek and Hemlock Fonnations, potential loss of circulation when crossing the Crestal Fault on the Middle Ground Shoal structure and waterflood-elevated pressure in the Hemlock Fonnation. Stuck Pipe The risk of stuck pipe in the Tyonek and Hemlock coals will be countered in two ways: 1.) Drillers experienced at drilling the fonnations of the Cook Inlet Basin will be used. 2.) Bit selection will include those which experience a slower rate of penetration when entering coal beds, thus giving warning of coals being encountered and preventing the BHA from entering them until the coals can be reamed open. Elevated Pore Pressure The 6" hole section below the top of the GN Sands will be in the East Flank of the Middle Ground Shoal structure which contains waterflood-elevated pore pressures of 5,300 to 5,500 psi. These relatively high pore pressures will be controlled by setting 7" casing at the top of the GN Sands and raising the mud weight before entering the East Flank. Lost Circulation The base of the MGS East Flank is marked by the Crestal Fault and the Hemlock HR interval. Both could exhibit sufficient penneability that, when combined with the higher mud weight being carried to control pore pressures while drilling the East Flank, some lost circulation could occur. This will be countered by setting a 5" liner across the Crestal Fault and reducing the mud weight before drilling the Hemlock in the West Flank. Disposal of Muds and Cuttinfs: MGS Platfonn C has a dedicated Class II disposal well. All oil-base or sheening waste wellbore fluids will be injected down the disposal well as will cuttings after they are ground. Non-sheening water-base fluids and cuttings will be discharged overboard. C41-23LN Casinf! Properties and Desif!n Verification Casing Performance Properties Internal Collapse Tensile Strength . Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor* (in.) (lb/ft) Grade Cnxn fuill fuill (l,OOOlbs) (ft RKB) (ft RKB) T B C 7 29 L-80 BTC 8,160 7,020 746 676 7,498 9,950 2.75 1.79 2.54 5 18 L-80 STL 10,140 10,490 319 422 8,655 11,950 9.01 5.30 2.31 3-1/2 8.8 N-80 STL Slotted Slotted 207 207 9,235 14,488 9.55 N/A N/A * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factor for 7" casing is calculated using MASP at surface with no external backup. Burst for the 5" liner is calculated at the depth of the 7" shoe using the expected normal pore pressure at the 7" shoe on the outside and waterflood-elevated East Flank reservoir pressure from deeper in the 6" hole section on the inside. For the 3-112" liner, burst is not calculated since the liner is slotted. . Collapse design safety factor for 7" casing is calculated at the 7" shoe using the expected normal pore pressure at the 7" shoe on the outside and the entire cased hole evacuated except for a gas gradient on the inside. Collapse for the 5" liner is calculated at the 5" shoe using the waterflood-elevated East Flank reservoir pressure on the outside and the entire cased hole evacuated except for a gas gradient on the inside. For the 3-112" liner, collapse is not calculated because the liner is slotted. Casing Setting Depth Rationale 7" 5" 3-1/2" 9,950'MD/7 ,498 'TVD 11,950'MD/8,655'TVD 14,488 'MD/9 ,235 'TVD Intennediate casing to provide hole stability and sufficient fÌacture gradient at the shoe to enable subsequent drilling into the MGS East Flank with its waterflood-elevated pore pressure. Drilling liner to provide hole stability and to isolate the over-pressured MGS East Flank before drilling the nonnally-pressured West Flank. Slotted production liner to stabilize producing interval for production operations. . . . . C41-23LN Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE -J The 6" hole section will be drilled through the MGS East Flank which contains elevated pore pressures resulting from waterflooding. Higher mud weights will be used in this interval to control the well. -J The bottom of the 6" hole section will cross the MGS Crestal Fault and penetrate the Hemlock HR. There is a potential for lost circulation and consequent difficulty in keeping the hole full. A 5" liner will be set and mud weights reduced at this point. -J Pipe sticking tendency is possible in the coals above and in the Hemlock reservoir. -J This well bore is planned to pass approximately 61' from the C44- 14RD well bore at a depth of 3,277' MD. -J There is no H2S risk anticipated for this well. CONSULT THE C41-23LN WELL PLAN FOR ADDITIONAL INFORMATION . Operator Name: Well Name: Job Description: Date: XTO Energy C41-23LN Intermediate Casing November 10, 2004 . ~ Proposal No: 100186755A JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing SizeIWeight : Pump Via Total Mix Water Required Weighted Spacer MCS-4D Density 1st Lead Slurry Lead Cement Density Yield 1st Tail Slurry Tail Cement Density Yield Displacement Drilling Mud Density 7,500 ft 9,950 ft 8.5 in 7 in, 29 Ibs/ft Casing 7" 0.0. (6.184" .1.0) 29 # 2,805 gals 30 bbls 11.0 ppg 166 sacks 12.5 ppg 2.10 cf/sack 169 sacks 15.8 ppg 1.15 cf/sack 367 bbls 9.8 ppg Report Printed on: November 10, 2004 2:53 PM Gr41 09 Page 5 . . Operator Name: Well Name: Job Description: Date: XTO Energy C41-23LN Intermediate Casing November 10, 2004 f£j Proposal No: 100186755A WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) 10.050 CASING 8.500 HOLE D MEASURED 1,653 9,950 SUSPENDED PIPES DIANleTeRti/1) I WEIGHT DEÞTHCftl 0.0. I I.D. I (lb$/ft) MeASURED ··TRU EVERTICAL 7.000 I 6 1 84 I 29 9,950 I 7,500 Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. 9,870 ft 9.80 ppg Oil Based 129 ° F 119°F VOLUME CALCULATIONS 1,950 ft x 0.1268 cf/ft 1,000 ft x 0.1268 cf/ft 80 ft x 0.2086 cf/ft with 40 % excess = with 40 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 346.2 cf 178.0 cf 16.7 cf (inside pipe) 540.9 cf 96 bbls = Report Printed on: November 10. 2004 2:53 PM Page 6 Gr4115 . . Operator Name: Well Name: Job Description: Date: XTO Energy C41-23LN Intermediate Casing November 10, 2004 Wj Proposal No: 100186755A FLUID SPECIFICATIONS Weighted Spacer 30.0 bbls MCS-4D + 119 Ibs/bbl Barite + 6 Ibs/bbl MCS-D + 22.13 Ibs/bbl Bentonite @ 11 ppg FLUID VOLUME CU-FT VOLUME FACTOR AMOUNT AND TYPE OF CEMENT 1 st Lead Slurry 346 I 2.1 = 166 sacks Class G Cement + 1.5% bwoc Sodium Metasilicate + 0.4% bwoc CD-32 + 0.4% bwoc R-3 + 0.6% bwoc FL-52 + 0.15% bwoc ASA-301 + 1 gals/100 sack FP-6L + 105.4% Fresh Water = 169 sacks Class G Cement + 0.3% bwoc CD-32 + 0.1 % bwoc R-3 + 0.6% bwoc FL-63 + 0.05% bwocASA-301 + 1 gals/100 sack FP-6L + 43.7% Fresh Water 1 st Tai! Slurry 195 ! 1.15 Displacement CEMENT PROPERTIES 366.7 bbls Drilling Mud @ 9.8 ppg Slurry Weight (ppg) Slurry Yield (cflsack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) SLURRY NO.1 12.50 2.10 11.88 11.89 SLURRY NO.2 15.80 1.15 4.93 4.94 1. Final additive loadings to be based on PRTC pilot blend data. 2. As requested 40% excess has been included. Report Printed on: November 10, 2004 2:53 PM Page 7 Gr4129 . Operator Name: Well Name: Job Description: Date: XTO Energy C41-23LN Drilling Liner November 10, 2004 . Wj Proposal No: 100186755A JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Liner SizelWeight : Pump Via Total Mix Water Required Weighted Spacer MCS4D Density 1st Tail Slurry Drilling Liner Slurry Density Yield Displacement Drilling Mud Density 8,653 ft 11,950 ft 6in 5in, 18 Ibs/ft Drill Pipe 31/2" 0.0. (2.764" .1.0) 13.3 # Casing 5" 0.0. (4.276" .1.0) 18 # 870 gals 40 bbls 14.0 ppg 177 sacks 15.8 ppg 1 .15 cflsack 115 bbls 12.9 ppg Report Printed on: November 10, 2004 2:53 PM Gr4109 Page 10 . Operator Name: Well Name: Job Description: Date: XTO Energy C41-23LN Drilling Liner November 10, 2004 . Wj Proposal No: 100186755A WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) 6.184 CASING 6.000 HOLE I I I MEASURED 9,950 11 ,950 SUSPENDED PIPES DIAMETER O.D. I 5.000 I DEPTH ft MEASURED 11,950 Drill Pipe 3.5 (in) OD, 2.764 (in) ID, 13.3 (Ibs/ft) set @ Drill Pipe 5.0 (in) OD, 4.276 (in) ID, 18 (Ibs/ft) set @ Depth to Top of Liner Float Collar set @ Mud Density Mud Type Est. Static Temp. Est. Circ. Temp. VOLUME CALCULATIONS 500 ft x 0.0722 cf/ft 2,000 ft x 0.0600 cf/ft 9,450 ft 11 ,950 ft 9,450 ft 11 ,950 ft 12.90 ppg Oil Based 143 0 F 128 0 F with 0 % excess = with 40 % excess = TOTAL SLURRY VOLUME = = t>EPTH(ft) tRUE VERTICAL I 7,500 i 8,653 8,653 36 cf 168 cf 204 cf 36 bbls Report Printed on: November 10, 2004 2:53 PM Page 11 Gr4117 . . Operator Name: Well Name: Job Description: Date: XTO Energy C41-23LN Drilling Liner November 10, 2004 ~ Proposal No: 100186755A FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls MCS-4D + 286 Ibs/bbl Barite + 7 Ibs/bbl MCS-D + 0.31 Ibs/bbl CD-31 + 25.6 Ibs/bbl Bentonite + 14 Ibs/bbl R-3 @ 14 ppg FLUID VOLUME VOLUME CU-FT FACTOR AMOUNT AND TYPE OF CEMENT 1st Tail Slurry 204 1 1.15 = 177 sacks Class G Cement + 0.3% bwoc CD-32 + 0.1 % bwoc R-3 + 0.8% bwoc FL-63 + 0.05% bwoc ASA-30 1 + 1 gals/100 sack FP-6L + 43.6% Fresh Water Displacement CEMENT PROPERTIES 114.5 bbls Drilling Mud @ 12.91 ppg Slurry Weight (ppg) Slurry Yield (cflsack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) SLURRY NO.1 15.80 1.15 4.91 4.92 1. Final additive loadings to be based on PRTC pilot blend data. Report Printed on: November 10, 2004 2:53 PM Page 12 Gr4129 . . Operator Name: XTa Energy Well Name: C41-23LN Date: November 10, 2004 !£j Proposal No: 100186755A PRODUCT DESCRIPTIONS ASA-301 Additive used to reduce or eliminate free water and settling in cement slurries. Barite A naturally occuring mineral (Barium Sulfate). It is widely used as a weighting material in cement spacers and occasionally in cement slurries. It can yield a slurry density in excess of 19 Ibslgal. Bentonite Commonly called gel, it is a clay material used as a cement extender and to control excessive free water. CD-31 A free flowing high molecular weight dispersant used to lower slurry viscosity and help provide turbulent flow properties at reduced pump rates. CD-31 also assists in fluid loss control. CD-32 A patented, free-flowing, water soluble polymer that is an efficient and effective dispersant for primary and remedial cementing. Class G Cement Intended for use as a basic cement from surface to 8000 ft as manufactured, or can be used with accelerators and retarders to cover a wide range of well depths and temperatures. FL-52 A water soluble, high molecular weight fluid loss additive used in medium to low density slurries. It is functional from low to high temperature ranges. FL-63 A non-retarding, non-viscosifying fluid loss additive particularly suited for use with coil tubing andlor close tolerance liner cementing. FL-63 is effective from low to high temperatures. Concentrations of 0.2% to 1.0% BWaC are typical. FP-6L A clear liquid that decreases foaming in slurries during mixing. MCS-4 A turbulent flow spacer system that prevents water and oil-base mud and cement contamination and water-wets the casing to increase bonding. R-3 A low temperature retarder used in a wide range of slurry formulations to extend the slurry thickening time. Sodium Metasilicate An extender used to produce an economical, low density cement slurry. Report Printed 011: November 10, 2004 2:54 PM Page 17 Gr4163 . . XTO Energy, Inc. J1~9 If'iillI BAKER HUGHES INTEQ Cook Inlet, Alaska Middle Ground Shoals Platform C Slot: slot #4-?? Well: C41-23 Wellbore: C41-23LN Ver 3 Location: Field: Installation: Created by : Planner Date plotted: 22.Qct-2004 Plot reference is C41-23LN Ver 3. Refwellpath is C41-23 LN Ver 3. Coordinates are in feet reference slot #4~?? True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Oatum. Rig Datum: Planned Oatum Rig Datum to mean sea level: 105.00 ft. Plot North is aligned to TRUE North. / ~ 0 0 -800 "'" II E 0 -0 Q) ~ rn 800 1800 KOP 31.35 2400 37.15 DLS: 2.50 deg/100ft - - Q) 3200 .! - ..c: - 4000 Q, Q) C ¡¡; 4800 (J :e Q) > 5600 Q) :J ... I- 6400 . V 7200 8000 8800 9600 10400 Sæie 1 an = 400 11:- West (feet): East (feet) -> -2400 -1600 -800 o 800 1600 C41-23LN Ver 3 Target 3 - 3 1/2" Casing PI. Target 2 - End DroplTurn 5" Casing Pt., Begin Drop/Tum Target 1 Begin Build/Turn 7" Casing Pt., r End .T IJU1 Begm rum C41-23 7" Casing Pt." ~ I> Begin Build/Tum 5" Casing Pt. ~ Target 1 DLS: 3.50 deg/100ft --..;; Begin Drop/Turn Target 2 - End DroplTurn C41-23LN Ver 3 -800 -0 800 Scale 1 cm = 400 ft 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 Vertical Section (feet) -> Azimuth 352.52 with reference 0.00 N, 0.00 E from slot #4-?? 10400 9600 2400 11200 10400 9600 8800 8000 7200 6400 ^ 5600 . Z 0 ;:¡ 4800 =r - ~ CD - 4000 - 3200 2400 1600 800 (J) (") Q) CD 0 (") 3 II -800 .¡,. 0 0 ;:: > 11200 . . XTO Energy, Inc.,slot #4-?? Platform C, Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Wellbore: C41-23LN Ver 3 Wellpath: C41-23 LN Ver 3 Date Printed: 22-0ct-2004 '4i. BAKER HUGHES INTEQ Well bore N;:¡me C41-23LN Ver 3 I, I 24-SeD-2004 I 22-0ct-2004 Iwell ~~3 Slot Name -?? Installation Platform C I L9~~~~;~~~ed I Govemment ID North Easl 233063.0833 True 2478929.9820 I=:G~""S_" I~~~ l~grthþJ·,- I n R ERICAN DATUM 1927 datum . True I Eastin~ 34754 5480 I Northi~ 000165290 Created Bv Comments All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 352.52 degrees Bottom hole distance is 9985.85 Feet on azimuth 352.52 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . XTO Energy, Inc.,slot #4-?? Platform C, Middle Ground Shoals, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Well bore: C41-23LN Ver 3 Well path: C41-23 LN Ver 3 Date Printed: 22-0ct-2004 r&i. BAKER HUGHES INTEQ WellDath ReDort MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Station Comment dea/100ftl Sectionrttl 1 qOO 00 ?77F. ~4 00 1 RO? ?F. ":I7&:: "":1"1 271.02E 0.00 337.54 I KOP. Tiø nn ?nnn £1£1 2R~q 2881ì 18qOF.0 411ì1lìN ?qF. !'\1 F 2.50 374.14 2100.00 29.21 23.96 1978.15 459.28N 316.90E 2.50 414.11 ??OO 00 ~o ?O 1q ~~ ?OR!'\ 01 <;,,<; ":1":1"1 335.14E 2.50 457.39 ?<\no £1£1 ~1~!'\ 14.98 21!'\Oq4 <;<;LI ?OtIJ ~!'\O ?OF ?!'\O . 503.88 2400.00 32.63 10.93 2235.76 605.81 N 362.04E 2.50 553.51 ?<;oo on ~404 717 n1q ~1 1ìlì00lìN ~70 R4F 2.50 606.18 ?RnO £1£1 <\<;<;<; 3.67 240144 711ì.84N ~7IìnOF 2!'\0 RR17R 2700.00 37.15 0.43 2481.99 776.05N 378.09E 2.50 720.21 ?AOn on <\A A<\ 3!'\743 2!'\1ì081 837F.8N ~7R q1 F ?!'\O 7R1 ~7 ?qnn no LlO ¡:;Q ~F.4¡:¡F. ?R<\77L1 901.30N 372.47E 2.50 845.13 3000.00 42.41 352.06 2712.64 967.10N 364.78E 2.50 911.36 <\10£1 on LILI ?A <\LlQ R<; 2785.3R 10<\LI ALltIJ 35~R51= 250 q7q9R ~?OO 00 4R ?O <\47 ~Q ?R<;!'\ 7R ..nA AH <\<\Q RQi= 2.50 1050_78 3218.01 46.55 347.00 2868.20 1117.13N 336.80E 2.50 1063.76 End of Build/Tum, End of ~~oo 00 4R !'\F. ~47 00 ?q?4 F.q 117<; 1":1"1 323.41 E 0.00 1123.01 3400.00 46.55 347.00 2993.36 1245.87N 307.08E 0.00 1195.27 ~SOO 00 4R <;<; ~47 00 ~OR? 1<\ 290.75E 0.00 1267_54 360000 4R !'\F. ~4700 ~1~0 QO ?74.42E 0.00 1339.80 3700.00 46.55 347.00 3199.66 1458.08N 258.08E 0.00 1412.06 3ROO 00 4R!'\!'\ ~47 00 ~?RR 4~ 241.75E 0.00 1484.33 ,>ann nn LlR <;<; 34700 ~~~7?0 ??F. 4?F 000 1 F.SR SQ i'o' 4000.00 46.55 347.00 3405.97 1670.30N 209.09E 0.00 1628.85 'Ann nn 4R F.F. <\4700 347474 174104N 1 Q? 7RF 000 1701.12 4 ?OO £1£1 LlR <;<; 347_00 3543.51 1811.78N 171ì431= 000 1773~8 4300.00 46.55 347.00 3612.28 1882.52N 160.10E 0.00 1845.64 LlLIOO on LlR <;<; 347.00 36R10!'\ 1a",> ')"~I 1437RF 000 1917Q1 4S00 on 4R F.<; ~47 00 <\7L1Q R? ?O?4 OOtIJ 127.43E 0_00 1990_17 4600.00 46.55 347.00 3818.59 2094.74N 111.10E 0.00 2062.43 4700 £1£1 LlR F.<; <\47.00 3887_36 2165.47N 94_77E 000 213470 4ROOOO 4R !'\!'\ ~47 00 ~QF.R 1 ~ ?nR ?1N 78.44E 0.00 2206.96 4900.00 46.55 347.00 4024.90 2306.95N 62.11 E 0.00 2279.23 !'\OOO 00 4R F.F. ~47 00 4nQ~ R7 2377.69N 45.78E 0.00 2351.49 510000 4RF.F. 34700 41 R?44 ?LlLlALI<\"1 ?Q 4F.F 0.00 2423.75 5200.00 46.55 347.00 4231.21 2519.17N 13.11 E 0.00 2496.02 !'\300 00 4R !'\F. ~4700 4?QQ QR ?<;Aa a1 "I 3.22W 0.00 2568.28 <;LlOO on 46.55 347.00 431ì875 ?RRO R<;tIJ 1Q5F.W 000 ?R40!'\4 5500.00 46.55 34700 4437.52 2731.39N 35.88W 0.00 2712.81 51ì00 00 4RF.F. ~47 00 4F.OR ?Q ?RO? 1 ~N F.??1W 000 2785.07 <;700 on LlR<;<; 34700 4575.01ì ?A7? A7tIJ 6R!'\4W 000 2R!'\73~ 5800.00 46.55 347.00 4643.83 2943.61N 84.88W 0.00 2929.60 <;aoo on 46!'\F. 34700 471? 1ì0 ":I01L1 ":ILl "I 101 ?1W 000 3001.86 Rnon on LlR <;<; 347.00 47R1~1ì <\OA<; OAtIJ 000 ~0741? 6100.00 46.55 347.00 4850.14 3155.82N 133.87W 0.00 3146.39 620000 4R!'\F. ~4700 4Q1 R QO ":I??R <;&::"1 000 3218.65 R<\no on 46.5!'\ 347.00 49R767 ,>')a7 '>n~1 000 ~?QOQ1 6400.00 46.55 347.00 5056.44 3368.04N 182.86W 0.00 3363.18 R!'\OO 00 4R F.F. ~47.00 F.1?F. ?1 0.00 3435.44 RROO 00 46.!'\!'\ 347.00 51Q3.QR 3509,!'\2N 21!'\!'\3W 0.00 ~!'\07 70 6700.00 46.55 347.00 5262.75 3580.26N 231.86W 0.00 3579.97 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 352.52 degrees Bottom hole distance is 9985.85 Feet on azimuth 352.52 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . XTO Energy, Inc.,slot #4-?? Platform C, Middle Ground Shoals, Cook Inlet, Alaska PROPOSAL LISTING Page 3 Wellbore: C41-23LN Ver 3 Wellpath: C41-23 LN Ver 3 Date Printed: 22-0ct-2004 ..,¡. BAKER HUGHES INTEQ We II path Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Station Comment dea/100ftl Sectionfftl RROO 00 4R !i!i :\4 7 no !i::\::\1 !i? ::\R!i100N ?4R1Ç W 000 ::\R52.2::\ RÇ OOOO 4R55 ::\4700 540029 ::\721.74N ?R4 "?IN 0.00 ':\7?4 4Q 7000.00 46.55 347.00 5469.06 3792.4 7N 280.85W 0.00 3796.76 710000 4R !i!'i :\4 7 00 !'i!'i::\7 R::\ '>.RI':"I ?1'" ?Ç 7 1 RW 000 ::\RR90? 7?00 00 4R!i!'i :\4 700 !'i60RfìO '>.Q,:\'>.Q<;'" ::\1::\.!'i1W 000 ::\941.2R 7300.00 46.55 347.00 5675.37 4004.69N 329.85W 0.00 4013.55 7400 00 4R !'i!'i ::\4700 !'i744 14 407!i.4::\N ::\461RW 000 40R!'iR1 7!'i0000 4R!i!'i ::\4700 !'i81?91 414fì17N '>.R? "11N 000 4158.07 7600.00 46.55 347.00 5881.68 4216.91 N 378.84W 0.00 4230.34 7700 00 46!i!'i :\4 7 00 !'iÇ !'i04!'i 4?R71':<;'" ::\Ç !'i 17W 000 4::\0260 780000 46!'i5 ::\4700 601922 4'1.!iR ':\aN 411 !i('¡W o ('¡(' 4·n4AI': 7900.00 46.55 347.00 6087.99 4429.13N 427.83W 0.00 4447.13 ROOOOO 4R!i!'i ::\4700 fì1!'iR7fì MQQ R7'" 44417W 000 4!'i19.39 8100.00 46.55 347.00 6??!i !i':\ 4!i70 61'" A ~n "mAl 000 4"Q 1 6!i 8200.00 46.55 347.00 6294.30 4641.35N 476.83W 0.00 4663.92 8::\00.00 46.!'i5 ::\47.00 6363.07 471208N 493.16W 0.00 4736.18 A4nn nn 46 !i!i 347.00 64':\ 1 R4 A7R? R?'" "nn AnUI 000 4ROR 4!i 8500.00 46.55 347.00 6500.60 4853.56N 525.82W 0.00 4880.71 8600.00 46.55 347.00 6569.38 Aa?A <lnll.l "A? 1 "'AI 000 4Q!i? 07 R7nn nn 4R "!i 347.00 R6':\R 14 Aaa" nA"1 ""0 AmAl 000 !i0?!'i ?4 8800.00 46.55 347.00 6706.91 5065.78N 574.82W 0.00 5097.50 AQnn nn 4R "!i ':I.i!7 nn 677!i 6R "1::\6."?N "a1 1 "'AI n 00 "16076 anon 00 46!i!'i :\47 00 6R44 4!'i !'i?07 ?RN ~~~ ,~." 000 !'i?42 0::\ \" )y' 9100.00 46.55 347.00 6913.22 5278.00N 623.81W 0.00 5314.29 O?OO 00 4R !i!'i ::\4700 6Ç R 1 0Ç <;"I4R 7 Ll"¡ ~Lln 141A1 000 !'i::\RR!'i!'i Ç ::!OO.OO 46.!'i5 ::\47.00 7050.76 ". on ."., <0,,'" A OU, o nn "4!iA R? 9400.00 46.55 347.00 7119.53 5490.22N 672.81W 0.00 5531.08 Ç SOOOO 4R!'i!'i :\4700 718R::\0 RRQ 141M 0.00 "Rn':\ ':\4 ORnn nn 46 !i!i ':I.i!70O 7?!i7 07 !i6':\1 60N .~~ .~" n no !i67!i 61 9700.00 46.55 347.00 7325.84 5702.43N 721.80W 0.00 5747.87 Beain Tum 3DS Kick off Point 9800.00 46.59 3!'i1.82 7':\04 R1 5773.77N 735.14W ':\!in !iR?n ':I.i! oono nn 46 R? ':\!i6 R? 746::\ ?1 <;RLl~ 1"'" ~ '^ A~'" ::\ !'i0 !'iRo::\n!'i 9914.57 46.87 357.31 7473.17 5856.76N 743.02W 3.50 5903.65 End Tum End of BuildlTum 1 nnnn nn 4R R7 357.31 7!i':\ 1 !i7 000 !iOR!'i 7R 101nn 00 46 R7 ':\!i7 ::\1 7!'iÇ 0 04 <;aa1 aLl'" 000 fì0::\8S1 10200.00 46.87 357.31 7668.30 6064.85N 752.78W 0.00 6111.23 10':\no 00 4R R7 357.31 77::\R 6R 7!iR ?OW 000 R1R::\ Ç 6 1nLlnn nn 4R R7 ::\!i7 ::\1 7ROS O? 000 R?!'ifìfìÇ 10500.00 46.87 357.31 7873.38 6283.56N 763.04W 0.00 6329.42 1 n~nn nn 4R R7 ':\"7 ':\1 70417!i ~"~~ .~. ~~~ A~'" 000 R40? 1!i 1 n7nn nn 46 R7 ::\!i7 ::\1 R010 11 000 fì474R7 10800.00 46.87 357.31 8078.47 6502.27N 773.30W 0.00 6547.60 7" Casina Pt. 7.000in Casina 1 nann nn 46 R7 ::\!i7 ':\1 R146 R::\ 1':"7<; 17'" 000 RR?O ::\::\ 11 000 00 46 R7 ::\!i7 ::\1 R?1S 1Ç 000 fìfìÇ 306 11011.34 46.87 357.31 8222.94 6656.34N 780.53W 0.00 6701.30 Beain BuildlTurn End of Hold 1110000 407R ::\"!i RO R?R1 00 ~~^~ A~. 70. ""UI ::\ !'i0 R7R7::\!'i 11?nn nn !'i::\ 04 ::\!i4 ?4 R:\44.?R 7Ç 13::\W 3!i0 fì845.41 11300.00 56.34 352.81 8402.06 6881.34N 800.54W 3.50 6927.00 11400 00 !'i0 R6 ::\!i1.40 R4S!'i OS ~.,n ..., ::\SO 7011 70 11!'i0000 fì? qO ::\!'i0.?6 RSO::\.03 70!'i19SN 3!'i0 7099.47 11600.00 66.33 349.09 8545.82 7140.84N 842.28W 3.50 7189.72 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 352.52 degrees Bottom hole distance is 9985.85 Feet on azimuth 352.52 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . XTO Energy, Inc.,slot #4-?? Platform C, Middle Ground Shoals, Cook Inlet, Alaska PROPOSAL LISTING Page 4 Well bore: C41-23LN Ver 3 Wellpath: C41-23 LN Ver 3 Date Printed: 22-0ct-2004 r'''. BAKER HUGHES INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Station Comment I fdea/1 OOftl Sectionrttl 11700.00 RqB7 ~47 qR ~ 77:11 "al\.l Hhl II W ~ 'i0 7?R? ?n 7<\ n<\ O:¡4" a? R"1<;.?':; 7O:¡?4 1 RN RR1 ?alM o:¡ <;n 7',7,:;-':;1:: 11900.00 76.38 345.90 8641.63 7417.90N 903.96W 3.50 7472.46 11q'i000 7ROR O:¡4<;4n ¡¡¡:¡;:;? ,:;a 74':;<; 14N o:¡ <;n 7<;?nR7 -¡;;-, (':o<:i';,,- Pt 'i OOOin r.",<:inn "0'" O:¡A 7R4<; <\4<; ?Q R,:;<;<; 1111 747<; RQN riA" "".., <\ <;11 7<;<\1 RQ T:ornpt 1 o:¡nc:: 12000.00 78.45 345.29 8662.74 7512.52N 928.47W 0.01 7569.46 12100.00 7R4<; <\4<; ?Q R,:;R? 77 7,:;n72RN n 1111 7':;':;':;1".<; 1 ??1111 1111 7R4<; <\4<; ?Q R711? 7Q 7702.05N 11 1111 77':;<\ R<; 12300.00 78.45 345.29 8722.82 7796.81 N 1003.12W 0.00 7861.05 1 ?O:¡,:;R ,:;R 7R 4<; ':t4<; ?Q R7O:¡,:; <;R 7R,:;1 anN 1 n?n ?11M n nn 7a?7- R1 IR<>"in - ¡::nrt nf Hnlrt '')Ann nn 7R O:¡O <\4" 7d R7d? ¡:¡a 7¡:¡0' "nil. ,n,)7 ¡:¡ ¡:¡'AI 1 <;0 7Q'iR ?<; . 12500.00 77.85 347.21 8763.54 7986.72N 1050.76W 1.50 8055.55 ,')"nn nn 7741 <\4R ':;7 R7RLl Q7 RI1R? ?4N 11171 17W 1 <;11 R1 <;? Q1 1?7nn nn 7R q7 ~'i0 1 'i ¡:¡¡:¡n714 R17R OQN , n¡:¡a nOlAl 1 'i11 R?<;n ')¡:¡ 12800.00 76.54 351.62 8830.04 8274.20N 1104.51W 1.50 8347.57 ,')ann nn 7':; 1<\ <\'i<\ 111 RR'i<\ ':;7 ¡:¡O:¡7n ",nl\. 11174<\W 1 'i11 RLl44 74 12905.55 76.10 353.19 8855.00 8375.85N 1118.07W 1.50 8450.12 Target 2 - End Drop/Turn, C41-23LN Target 2 Rvsd R_<::<>n_n4 c::/r' l<"i~Lr nff Pnint 1 <\111111 1111 76.10 ~<;o:¡ 1Q ~AA77 ,:;Q R4,:;,:; RaN 11?R aLlIM nnn R<;41 A1 13100.00 76.10 353.19 8901.70 8563.28N 1140.46W 0.00 8638.87 1o:¡?nn nn 7R10 o:¡<;o:¡ 1a ~.¡? ~':;71\.1 11'i1q7W n nn R7O:¡<;0:1 . 1 <\O:¡I1I1 1111 7':; 111 o:¡<;o:¡ 1Q Ra4a 7 Ll R7<;,:; n<;N 11':;O:¡ 4QIM n nn RRO:¡O:¡ n1 ,..·,/13400.00 76.10 353.19 8973.76 8852.44N 1175.01W 0.00 8930.07 1o:¡<;nn nl1 7R10 n.;.<;o:¡ 1a AaC17 7R Ra4R RO:¡I\.I 11R':; <;?IM n nn an?7 ti ,o:¡"nn nn 7':; 111 <\<;<\ 1Q QI1?1 7Q Q114<; ?1 N 1'0¡:¡ nA'AI 11 1111 Q1?4 ?11 13700.00 76.10 353.19 9045.81 9141.60N 1209.55W 0.00 9221.27 ,o:¡¡:¡nn nn 7':; 111 <\<;<\ 1Q Q()f;Q R<\ Q?<\7.99N 1??1 1171M 11 1111 Q<\1R O:¡4 ,o:¡ann nn 7':; 10 <\'i<\ 1Q anao:¡ ¡:¡'" aO:¡O:¡A O:¡¡:¡I\.I ,')o:¡') "'¡:¡'AI 11 1111 041'i 40 14000.00 76.10 353.19 9117.87 9430.76N 1244.10W 0.00 9512.47 1411111 1111 7':; 111 <\<;<\ 1Q Q141 RR Q<;?7.15N ,')"'''' "')'AI 11 1111 Q,:;I1Q <;<\ 14?nn nn 7R 10 ~'i~ 1q a1"<; an ~<;41\.1 1?R7 1~W 000 a7n" "n 14300.00 76.10 353.19 9189.92 9719.93N 1278.65W 0.00 9803.67 144nn nn 7R 10 ~'i~ 1q a?1O:¡ QA aR1R~1N 1?QO 1RW 000 QQOO 7~ 1447R~7 7R10 o:¡<;o:¡ 1a ~R C:IAAQ aO:¡1\.1 1 ?aR a,:;IM 000 OOÚR7 14487.69 76.10 353.19 9235.00 9900.84N 1300.26W 0.00 9985.85 Target 3 - 3 1/2" Casing Pt., 3 1/2in Casing, End of Build/Turn, Il=nrl nf I-Inlr All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 1 05.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 352.52 degrees Bottom hole distance is 9985.85 Feet on azimuth 352.52 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . XTO Energy, Inc.,slot #4-?? Platform C, Middle Ground Shoals, Cook Inlet, Alaska PROPOSAL LISTING Page 5 Wellbore: C41-23LN Ver 3 Wellpath: C41-23 LN Ver 3 Date Printed: 22-0ct-2004 "&i. BAKER HUGHES INTEQ Hole Sections Start MDft 8375.85N N60 47 12.273 W151 19-Jan-2003 9900.84N 1200.26W 9235.00 N60 47 27.290 W151 30 31.397 230449.42 2484115.67 19-Jan-2003 7475.89N 818.95W 8655.00 N60 47 3.411 W151 30 23.711 230775.16 2481682.68 19-Jan-2003 Error Model All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 1 05. Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 352.52 degrees Bottom hole distance is 9985.85 Feet on azimuth 352.52 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . XTO Energy, Inc. r.cia. BAKER HUGHES INTEQ 4200 4000 3800 3600 3400 3200 3000 2800 2600 ,2400 -"".~.. ( ,) ( ,) :t;.. 2200 J: t: ~ 2000 1800 1600 1400 1200 1000 ù C/) 200 ;(TO ~kRGY Location: Field: Installation: Cook Inlet, Alaska Middle Ground Shoals Platform C slot #4-?? C41-23 C41-23LN Ver 3 Slot: Well: Wellbore: 90(10. 4000 ~ " 3800 3600 3400 3200 3000 2800 2600 2400 ^ . Z 0 2200 ª - ø' E3 2000 !. - 09400 ,gooo 1800 ::oofí) 1600 , 820'» . 8000. .3400 7800.03300 76OOr3200 1400 1200 1000 800 en () 600 Q) ëD Scale 1 cm 01>0 ~tftfeet): East (feet) -> -600 -400 -200 0 200 400 0' r;;3 \jj ~9200 6100'. ~9100 6000\ ~= 5900\ ~8800 5800'~ t8700 5700,> t8600 5600\ ::: 5500.. .8300 ,;.8200 5400. t8100 53OO{SOOO 7900 "". 7800 ~ '., 5200 7100 + '.5100 =: ~5000 7400;' :'4900 7300 t .4800 7200 ~ 7100 . 1000 + 6900 . 6500. 6700+ 6800 . 650''; 6400;' 6300. 6200 . 6100+ 6000l 5900 . 5800 . 5700+ 5800 . '.4600 .4200 .4000 .3800 5400. ~3500 5200. 5100 ;. '900 . 4800. 4100. """» <1500. 4400. 4300 ~ 4200. 4100;. .3300 .3200 .3100 .3000 .2900 .2600 4000 , (\\ \Ÿ 3900. .2700 3800;. '2600 3700;. 3600"~ '2500 -2400 3500, '2400 3400. 3300;. 3200. 3100. ·2200 3000 , +2100 2900 . '2000 -600 -400 -200 -0 200 400 Scale 1 cm ~ \1\IàQtf feet) : East (feet) -> 600 4200 () 3 400 II ... o o 200 ;::I! 600 10400 10000 9600 9200 8800 8400 8000 7600 7200 ^ 6800 . - - ( ,) ~ 6400 J: t: 0 6000 Z 5600 5200 Seale 1 em = 20~ast (feet) _> -2000 -1600 -1200 ~oo -400 o A33-11 1-23 9100- 92OO'J'þOO 9200 73OO~~;F~-:---- ~/ 7500 ~ 9400 + 7700, 9500"~ q,..4300 ~ 7900. "'.,,,,,,,, ~::,oo 9100 8000 f.q,~ _'.7""" 7100,' : 8100.:+·'L....:.J ~iaooOO 7200/ :¡ :þ 'B200 7400/ . ~ .... 'Þo'8300 ~;;: 7600>' ~7000 &I> '. ,Gb \8400 J:~OO 81:~+' t;: Iþ,Ws:;l "', 'io./ 90(10 8500\.5300 ~__~..-," 17300 C:::::,l.,."'_ #' !"O"+._"¡Ç "'-iI¡, '''''' !7400 ~ T~· +--5600..., 'b /= '>'io,~:. .':;'00 =/= il 7. ,,'./ as:oo. S:~~f /5100 ¿'/'j':!. . ?5/ iiS.OO!f1 7;:;,oJ. 86001,/5300 l{Joo 7700" :oo~l / f5800 a100¡:#:..#~tS> 8900f ,,;'5400 f5900 ~"""'#'- .' 87~:...__,<-,.__~,\~ 8700 ~oo/' 9100', S 16000 1611)0 9200·, /6200 18300 ¡ËlJ )6100/7500 6000f ,.6800.7700 6100j 69OO,J.~ 6200+ 7OOOf+S100 63Q0!8300·j7100 ~_j:f1200 6500 + t 7300 6600+ ;'7400 6700 .. ~ 7500 6800. )7600 6900 t f 7700 ;7800 ,- J""", i8100 ;'8200 i8300 I""" 56001 5700+ 9300, 5800J ~ 59001 9400;' 9700\ 960'» 9500 '=">08900 .8100 8500. 9500;.' 9700 . 8300+ 8100- M V 7900f moo B .7600 , 'I-'io.,.~'ò'b '-iI¡, ""'. ·"'00 ,g~ ,_. 7300~ .~.' 7200' r8500 ¡J) V 7000 ~ 890'" 6800 ~ 6700 ~ 6600 ¡ .7800 .9.>q,.B 07700 .7600 4800 " .7500 ",,~ 6300 ': .7400 4400 .8900 -8700 '8500 4000 6400. 15600"+8300 6300. +5500'+8100 6200, ':5400·7900 6100. '5300 \-7100 3600 C21-23 .# 6000. .5200 .7500 C21-23 5900. 5000. .7300 ¢:: 5700~ '5000 _7100 0 '4900 .6'300 5500. 0 3200 5400. .6700 N II E ü 2800 OJ ro ü C/) 2400 -2000 -1600 -1200 -800 -400 Seale 1 em = 20c6:ast (feet) -> o 800 ~'2300 , ·2200 \ ¢:: J ~.4800 +2100 0 .4600 0 600 ..... II E ü 400 400 10400 10000 9600 9200 8800 8400 8000 7600 7200 6800 ^ . z 0 6400 ;::¡. :r - ¡¡r 6000 !. - 5600 5200 4800 4400 4000 3600 (/) (") 3200 Q) ëD (") 3 2800 II I\) o o 2400 ;::I! 400 . . Bill BAKER HUGHES INTEQ XTO Energy, Inc. Location: Field: Installation: Cook Inlet, Alaska Middle Ground Shoals Platform C Slot: slot #4-71 Well: C41-23 Wellbore: C41-23LN Ver 3 ;ftÇ? Created by : Planner Date plotted: 22-Oct-2004 Plot reference is C41-23LN Ver 3. Ref wellpath is C41-23 LN Ver 3. Coordinates are in feet reference slot #4- ?? True Vertical Depths are reference Rig Oatum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 105.00 fl Plot North is aligned to TRUE North. TRUE NORTH 350 o 10 340 20 330 30 320 40 50 290 280 80 270 240 90 260 100 250 120 230 fiób 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well . . XTO Energy, Inc. C41-23 LN Ver 3, C41-23LN Ver 3 slot #4-??, Platform C CLEARANCE LISTING Page 1 Date Printed: 22-0ct-2004 Middle Ground Shoals, Cook Inlet, Alaska r&¡. BAKER HUGHES INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Onlv Depth and MaQnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1000ft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/CasinQs are NOT included Hole size/CasinQs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.00standard deviations. ClosinQ Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation I~:~~o:: , IWell Name C41-23 I ~re~ted 4- eo-2004 I ;;~~~~~~~: I Govemment ID I Last Revised 9-Jul-2004 Slot Name _?? East )stallation T~=rm C I Eastina I~mtb;oo I~~~ NorthAJ;ooment I 233063083 2478929982 R ERICAN DATUM 1927 datum True Field Middle Ground Shoals 234754.548 2500016.529 AK-4 on NORTH AMERICAN DATUM 1927 datum True Clearance SUmmary Offset Offset Offset Offset Minimum MD[ft] Diverging Ellipse Ellipse Clearance Clearance WellName Wellbore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] Ilftl Iftl C41-23 C41-23 slot #4-?? Platform C 0.00 1900.0 1900.0 -28.51 1935.7 O.OC 1900.0( C44-14RD C44-14RD slot #4- ?? Platform C 60.9" 3277.1 3277.1 18.6S 3330.0 1.4C 3346.4{ IAWR\ C44-14 C44-14 slot #4-?? Platform C 60.9~ 3277.1 3277.1 18.6S 3330.0 1.4C 3346.4{ IAWR\ C43-14 C43-14 slot #25 Platform C 139.5( 2762.1 ! 2762.1! 109.4~ 2739.5 4.54 3166.0 AWB\ C43-23 C43-23 slot #4-?? Platform C 256.0 1900.0( 1900.0( 240.1 C 1900.0 16.01 1900.0C IAINR\ A34-14 A34-14LW slot #1-05 Platform A 275.7{ 13170.9{ 13170.9 83.1E 13188.9 1.4< 13200.0 IA34-14 A34-14RD !'>Iot #1-05 "'L.". ^ 278.6S 97859: 9785.9: 41.07 9809.7· 1.1 9809.7- C31-23 C31-23 slot #4- ?? Platform C 315.2 4091.3{ 4091.3{ 256.1 4084.6 5.3 4051.8 AWB\ C42-23 C42-23 slot #4-25 Platform C 318.51 1900.0( 1900.0( 299.0 1900.0 16.2~ 1900.0C IAWR\ C13-13LN C13-13LN slot #24 Platform C 333.3 1900.0( 1900.0( 320.6~ 1900.0( 26.3-< 1900.0C I lAWS) All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . XTO Energy, Inc. C41-23 LN Ver 3, C41-23LN Ver 3 slot #4-??, Platform C CLEARANCE LISTING Page 2 Date Printed: 22-0ct-2004 Middle Ground Shoals, Cook Inlet, Alaska '&i. BAKER HUGHES INTEQ Clearance Summarv Offset Offset Offset Offset Minimum MD[ft] Diverging Ellipse Ellipse Clearance Clearance WetlName Wellbore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] fftl fftl C41-26 C41-26 slot #24 Platform C 333.3 1900.0 1900.0 320.6 1900.0( 26.~ 1900.0( I lAWS) I A::I4-11 I A::I4-11I ~ ,:;Int #1-04 A ::I576f ·1 '<RflR II ."O^O 177.1 13861.5! H}iõ 1::1R77 Q! C23-23 C23-23 slot #12 Platform C 483.1C 1900.0 1900.0 465.6 1900.0 27.6f 1900.0C I lAWS) C21-23 C21-23 slot #8 Platform C 485.5! 1900.0 1900.0 471.9 1900.0 35.7 1900.0 'lAWS) A22-14 A22-14 slot #1-06 Platform A 492.41 12391.7 12391.7 315.3f 12368.6 2.7 12335.9 C34-23 C34-23 slot #21 Platform C 492.4! 1900.0! 1900.0 476.5 1900.0 30.8< 1900.0( I lAWS) C31-26 C31-26Rd slot #1-5 Platform C 500.7 1900.0( 1900.0 484.5 1900.0 30.9 1900.01 C::I1-26 C::I1-26 ,:;Int #1-5 IC 5007! 190001 1900.0( llR./l ¡;;¡ 1 QfIfI fI/ 30.9· 1900 Ol A??_1111 !:: 'A??_1111 !:: <oInt it1-06 A <;flR I'll 1?'<R.d. 1. 1?'<R.d. 1, '<?7 Q~ 1?':I¡;;? ':II ? 1'1< A34-14 A34-14 slot #1-05 Platform A 511.6 10298.3 10298.3 254.7 10301.8< 1.9~ 10318.2 C21A-23 C21A-23 slot #4- ?? Platform C 534.2 1900.0 1900.0 521.6f 1900.0 42.5 1900.01 IAWR\ C11-23 C11-23 slot #4- ?? Platform C 534.2 1900.0( 1900.0 521.6 1900.0 42.5 1900.0( I AWR\ C11-23 C11-23 slot #4- ?? Platform C 536.2 1900.0( 1900.0 523.3 1900.0 41.4< 1900.0( (AWS) C32-23LW C32-23LW slot #1-2 Platform C 542.4 1900.0 10793.9 373.8 10793.9 2.61 10826.7 IAWS\ C24-14 C24-14 slot #1-2 Platform C 542.4 1900.0 9700.0 520.11 1900.0( 5.6C 8899.6:; IAWR\ . 732-23 C32-23 slot #1-2 Platform C 542.4 1900.0 1900.0 520.11 1900.0( 23.8f 2493.44 .- lAWS) C21-26 C21-26 slot #9 Platform C 548.3! 1900.0 1900.0 534.8 1900.0! 40.4! 1900.0 IAWS\ C12-23 C12-23 slot #4- ?? Platform C 561.9( 1900.0 1900.0 548.0 1900.0 40.61 1900.0 lAWS) A'<'<_111 A'<'<_1ll o::lnt :/M_'<fI 11 <;R.d. l' .....,0 o· 111?R R ::I1Q ::1< .....,00, ? ::1(; C13A-23LN C13A-23LN slot #4-29 Platform C 594.7 1900.0 1900.0 580.4 1900.0 41.5f 1900.0 ~1 '<A_?'<I J\I 1"'1 ">11_?">1 J\I o::lnt :/M_?Q I r. <;Qll 7~ 1 QflO Of 1 QOO.OI 5ROA' 1 QOO 01 111 <;~ 1QMOI C1 ::IA-?::I C1 ::IA-?::! ',:;Int :/M-?Q C 594 7~ 1900 Of 190001 5R04 190001 41 Sf 1900 or C13-23 C13-23 slot #7 Platform C 614.8 1900.0 1900.0 601.3! 1900.0 45.6~ 1900.0( I AWR\ AW~-1 A::I1-14LW ,:;Int #2-15 I A 627::1: 1'<.ð.R? '<' 13482.::1, A34-11 A34-11 LS2 slot #1-04 Platform A 645.1 14428.7 14428.7 425.4 14428.7 2.94 14428.7 C11-23 C11-23 slot #4- ?? Platform C 646.2 1900.0 1900.0 627.3< 1900.0 34.1:; 1900.0< IAWS\ C11-26 C11-26 slot #4- ?? Platform C 646.2 1900.0 1900.0 634.0< 1900.0 52.6 1900.0< IAWR\ C22-23 C22-23 slot #10 Platform C 682.0 1900.0 1900.0 665.5 1900.0 41.3 1900.0< AWS) C24-26 C24-26 slot #15 Platform C 683.4 1900.0 1900.0 668.8 1900.0 46.7 1900.0< IAWS\ C24-26 C24-26 slot #15 Platform C 683.4 1900.0 1900.0 668.8 1900.0 46.7 1900.0( IAWR\ C24A-14 C24A-14 slot #16 Platform C 683.5 1900.0 1900.0 663.0! 1900.0 33.4 1900.0( (AWS) C22-26RD C22-26RD slot #11 Platform C 699.0 1900.0 1900.0 685.5 1900.0 51.8 1900.0( IAWS\ C22-26 C22-26 slot #11 Platform C 699.0 1900.0 1900.0 685.5< 1900.0 51.8 1900.0( lAWS) All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . XTO Energy, Inc. C41-23 LN Ver 3, C41-23LN Ver 3 slot #4-??, Platform C CLEARANCE LISTING Page 3 Date Printed: 22-0ct-2004 Middle Ground Shoals, Cook Inlet, Alaska r&íi. BAKER HUGHES INTEQ Clearance Summa Offset Offset Offset WellName Wellbore Slot Offset Minimum Structure Distance MD[ft] Diverging From[ft] Ellipse Separation Ellipse MD[ft] Clearance Factor Clearance MD[ft] slot #2-15 Platform C 1900.0 732.5 1900.0 C24-23 slot #2-15 Platform C 1900.0 732.5 1900.0 1900.0 1900.0 ¡Reference Wellbore Survey Tool Proqram ~~~~~Name IMDrftl 14476 3~ ~~~~~:OOI I ~~~d~;:el All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated II MGS C41-23LN - Spacing Exception Needed . . George, Conservation Order ("CO") 44 Rule l(b) allows only two completions open to the pool within any governmental quarter section. It is my understanding that the proposed MGS C41-23LN will be the 4th completion open to the pool within the NW 1/4 of S. 14. A spacing exception is needed. CO 44, Rule 6(d) allows the Commission to authorize drilling and operation of this well without notice or public hearing. Please submit a spacing exception application with supporting documentation for this well as soon as possible. If you have any questions, please call me at 907-793-1224. Thank you, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission 1 of 1 11124/20043:46 PM C41-23LN (204-236) . . Subject: C41-23LN (204-236) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 24 Nov 2004 10:41 :51 -0900 To: Bill Penrose <bill@fairweather.com> CC: Paul Figel <paul_figel@XTOenergy.com>, Bobby Smith <bobby_smith@xtoenergy.com> All, I am sending this to all of you since I believe Bill is out of Alaska at present and I don't know if he is checking his email. I am reviewing the PTD for this well and have a couple of questions/observations. 1. What ram size will be employed when the 7" casing is pulled?? 2. It is not stated that appropriate sized DP rams will be reinstalled once the 7" has been pulled. If VBRs are being employed that cover the DP and casing, then a change would not be necessary. 3. With regard to the casing stub, the plug length inside the casing needs to be increased to a minimum of 100'. My references here are 20 AAC 25.112 (b) (1) [segregating cased and uncased hole] and 20 AAC 25.112 (c) (2) (A) [plugging of cased portions] . 4. Recently the 14 day BOP test interval regulation formally became applicable and for that interval is applicable to the drilling operations XTO is conducting. please note that the 14 day interval is applicable to drilling operations. For the decompletion and deep plugging operations approved under sundry 304-463 and the further plugging/pulling operations covered by steps 1 - 8 of the procedure submitted with the PTD application, a 7 day test interval applies. As in prior years, the 7 day interval may be extended at the request of the Drilling Supervisor and in consideration of the ongoing operations when necessary. I look forward to your replies. Please call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 11124/2004 10:42 AM MGS C41-23LN Proposed 1-011 UGH Oil Pool 2042360 SFD 11/23/2004 Slotted · TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /l?(;S Ct//-¿3LA1 PTD# 2DL( <-.. 230 ,J Development Service . CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) . Exploration Stratigraphic "CLUE". The permit is for a new wen bore segment of existing weD . Permit No, API No. . Production.sbould continue to be reponed as a function ·of tbe original API number. stated above. BOLE ]n accordance with· 20 AAC 25.005(f), aU records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION ¡ DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25..0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation orde~proving a spacing . excep1ion. '>< I ('..J t.~~ (Company Name) assumes tbe Jiability of a y protest t~ ¡fbe spacjng .e.y:eptipp ~at, ~ay occur. {,Æ-/pL-. :.1rf<-~L.-1#. ~ All dry ditch sample sets submitted to tbe Commission must be in no greater 1ban 30' sample interYals from below tbe permafrost or from where sßmples are first caugbt and ] 0' sample h:Îter:va)s tbrougb target ZODes. Field & Pool MIDDLE GROUND SHOAL, E,F,G OIL - 524114 Well Name: MGS C41-23LN Program DEV Well bore seg NERGYINC Initial ClasslType DEV / PEND GeoArea 820 Unit On/Off Shore Off Annular Disposal 0 - Administration Permit fee attache.d. - - - - - - - - - - - - - - Yes · . . . . Sidetrack of .existing welJ. 2 leas.e.numberappropriat.e. . . . . . _ - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - 3 .U.nlque weltn.ame.and (lumber. . . . . . . . . . . . . . . . . . . . . . . . . ........ Yes - - - . - - - - - - - ~ - - - - - - - - - .. . - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well JQcated lna d.efioe9pool. - - - - - - - - - - - - Yes · _ . MI.DDLEGRQUN.DSHQAL, E,F.G OILe 5241"14 _ - - - - - - 5 WelUQcated pmper .dlstance from driJling unitb.ouod.a(y . . . . _ Yes · . . . . Governed by CO M. . - - - - - - 6 WeUJQcated proper distance from otber welJS. . . . . . . .Yes · . . f'IIeaJest offset weJI is. 3.35'away, whlcb CQnfoJms with CO M. _ . - - - - - ,7 .S.ufficieot acreag.e.aYailable in.dJilJiog. unit. . . - - - - - - Yes capable of.producting from the same pooJ ..." Nearest well is about 35.0' away. 1:0 Jfdeviated, is weJlbQfE1 platincJu.ded . - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - .Operator only affected party. . . . - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - .Operator bé!s.apprppriate. bond lnJorce . . . . . . . . . . . . . . . . . . . . ...__...Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - 11 Peonit c.an be issued witlJQut conserva.tioo order. Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Permit can be issued witbQut ad.ministratilœappr.ovaJ . - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - SFD 11/23/2004 ,13 Can permit be approved before 15-day wait Yes . 14 WellJQcated within area and strata .authorized by.lnjecti.oo Order # (puUO# in.c.o01ments). (For NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 AJlwel!s.within.1l4.ruite.area.ofreyiewideolified(Forservjce.w.eUooly)............... NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ 4 . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ - - - - - - . - - - - - -- 16 Pre-produced injector; duratiQn.of pre-pr09l.1ctipn less than 3 mootbs (For.service well QnJy) . NA - - - - - - - - - - - - - - - - - - - - - -- 117 ACMPF:indjng .of Consistency has bee.n.issued forthis project . - - - - - - NA - - - - - - - - - - - - - - - - - - - - - Engineering 18 Condu.ctor stringpJQvided . - - - - - - - - - - - - - - - - - - ... .NA · . . . Sidetrack of.existing welJ.. CQnduc.tQr sel.in Jl.32-1.4.(165~035)~ . - - - - - - - 19 .SurfacecasingpJQtec.ts all known USDWs . . . . . - - - - NA · . . . . Surface casing sel.inJl.32~14, AU aquifers exempted by EPA40 CFEU47'.102(b)(2). . 120 .CMT vol adequ.ateto circulate. on conductor. 8. surf csg . . NA · Surface casing set in A32-14, - - - - - - - - - - - - - - 21 .CMT vol adequate. to tie-ill JQng .string to surf csg. . - - - - - - No. intermediate.8. liner eruent planned aboye aIVany.hydrocarb.oos. . . - - - - - - 22 CMT wil! CoyeraJl known .pro.ductiYe bQri;i:on.s. - - - - - No. · . . . Slotted .liner planned, . - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 Casiog designs adequate f.or C,T, B.& permé!fr.ost - - - - .Yes - - - - - - 24 .Mequat.e.tankageoJ reserve pit. . . . . - - - - - - - - - - - Yes · . . . Rig is equippe.dwith steel pits. . NQ rese.rIlepitpossjbJe. PJatfprm ba.s a Class JldisPQsal weJ.. 25 Rare-drilL has.a. 1.0-403 fQr abandonme.nt beeo apPJQved . - - - - - - . . . . Yes · .30.4:4.63,.verbally.apprPlled1"1/23/D4.. - - - - - - 26 Adequatewellbore.separ¡;¡tio.n.proposed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes · __ . . . Close. appr9aches igeotified.. "(raveling .cylinder plot includ.ed.. Ç3yrps PQssible.. . . . . . . . . . - - - - - - - - - - - 27 Jf.divecter Jeq.uiJed, dQes it meet reguJations. - - - - - - - - . NA · . BOt=> stack aJready.in place. . . . - - - - -- - - - - - - - - - - - - Appr Date 28 .DJilIiog fluid. program sc.hematic& eq.uip Jistadequate. . . - - - -.. - - Yes · . Bl:lt=> expected in 6" hoJe seçtjon 12.2EMW.. t=>lanned MW 13.5. ppg, . - - - - - - - - - - - - TE~4/2004 129 .s.o.PEs, do they meet reguJation . . - - - - - - - - - - - - - - - - - - - - - Yes · Stack is composed.oJ "lSR, 1. PR aod annl.ll¡;¡r, .EQl.lipment limited due to.ayailable headspaGe, YBRs in.use. . ~ ""i 30 SOPEpress ratiog appropriate; test to.(pul psig tn .comments). Yes · . . M.c>.SP in 6" hole caJc.ulate.d.at 4553 psi.. 5QOOpsitesl p ¡;lIJned. - - - - - - - J 31 Choke. manifold cQmpJies w/.c>.PIRf-53 (May 64). . Yes - - - - - - - - - - - - - - - - - - - - - - - 32 WQrk will occur without.operation .shutdown. . . - - - - - - - - Y.es - - - - - - - - - - - - - - - - - - - - - - -- 133 .15 presence Qf H2S gas proQ.able. . . . . . . . . - - - - - - - . . . . .No. · J-I2S is not.expected,. mud should preclud.e H2S .on Jig. Rig js equipped.with sensPrJ> and alarm.s.. !34 MecbClnicalcoodjtion.o{ wells within Jl.OR yerifieel (For service welJ only). . . NA. - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 35 Pß(l1)it. c.an be issued wlo. hydrogen. s.ulfide meas.ures . - - - - - - - - - - Yes · . . . . 1:12S not expected, bl.ltwe!l will be rn.udlogg.ed aoell:l2S monitpringeç uipment wiJlbe instalJed 36 D.ata.PJeseoted on pote.ntiC!1 .oveJpres.sure .zooes. . - - - - - - Yes andJunctiQningof the rig ataJl times dUJing sidetracking&. c.ornpletiQnoperatiQns. Appr Date 37 .Seis01icanalysis. Qf sbaJlow gas.zpoes NA · Expected œservojr pre.ssuJe is.7 ,3ppg EMW; will be drilled with 9.0 ppg muel. - - - - - - SFD 11/23/2004138 Seabed .conditipo survey.(if off-sh.ore) . NA. - - - - - - - 39 CQnta.ct narn.elphoneforweelsly prpgressreRorts [explorato(y .only] . . . NA - - - - - - - - - - - Geologic Date: Engineering Date ~?Ii~ r Date. Sidetrack of existing wel Commissioner: Commissioner: Ürs .2..41+ JOh~~':a~Y '2/ 10 i
